bluuebunny/crossref_metadata_2025_split huggingface dataset:
RESQML Version 2 Uses New Technologies to Improve Data Exchange for Subsurface Modeling Processes
Authors: Verney Philippe , Gautreau Christian , Rainaud Jean-François , Deny Laurent , Magsipok Joey , Marcotte Donna 
Published: June 2014

Abstract
Subsurface modeling workflows are complex, data intensive, and iterative, requiring many different software packages to repeatedly exchange data. Improving the speed and accuracy of data exchange in model development can improve the speed, accuracy, and reliability of analyzing these models, ultimately supporting better decisions for asset development and economics over the life of a field.
RESQML is an XML/HDF5-based, data-exchange specification that allows data to be transferred efficiently between the many different software packages used in subsurface modeling workflows. Key Version 2 enhancements include: a richer, more detailed RESQML data model with more domain data-objects (e.g., wells), and the ability to group related data-objects (e.g., faults, horizons, grids, etc.) and exchange them as a complete model. While these enhancements support more accurate and reliable models, they also presented challenges that were solved using new technological approaches new to RESQML.
To design the richer yet more complex data model, the RESQML Special Interest Group (SIG) has moved from a hierarchical view of the data model to an entity-relationship view. The SIG is now using UML modeling tools to visualize the data model and produce both class and instance diagrams. The class diagrams are then used to generate XML schema definitions in a more automated and consistent manner.
The Open Packaging Conventions_a container-file technology that stores a combination of files and their relationships to form a single entity for transfer in one compressed (ZIP) document format_are being used to group together independent data-objects (files) as a complete model.
This paper presents an overview of RESQML Version 2 enhancements and capabilities, and explains how these new technology solutions are being used and their impact on subsurface modeling, the design process, future maintenance, and in helping software developers integrate RESQML into their own products.
Data Security Promotes Improved Intelligent Drilling
Authors: Cavazos Catherine 
Published: June 2014

Abstract
As drilling becomes more intelligent, barriers associated with data security are increasingly encountered. Such data security barriers often proliferate many times faster than the drilling technology itself. The drilling industry needs to be able to efficiently and effectively adapt and expand to address these barriers, protect their assets, and continue to meet the needs of both operators and contractors.
Rig assets, in this case, data, are extremely valuable, and any loss, corruption, or theft can translate into potential safety hazards, significant monetary damages, and negative impacts to their business. Today’s climate brings to the forefront hacktivists and nation state hackers who infringe on these assets. As technology improves, the accuracy, rapidity, and remote accessibility of data must be capitalized on to ensure data security. Furthermore, education, training, and utilizing the "right" standards according to the needs of the rigsite are critical to the safety and production of the well and its data. There is a great need to eliminate security obscurity. Educating users at the rig and knowing how to operate under a particular set of standards or security measures can make all the difference in having a compromised or protected rig. Understanding the type of monitoring and security needed for 10,000 users/employees is different than for 100 users. The collaboration between the management and groups working to secure the assets must adapt adequately to address and prepare for the potential obstacles that may occur down the road.
This paper addresses the issues organizations must be recognizing to avoid this obscurity. Implementing the right training, education, and security practices will enable real--time security of data management and monitoring to be more sound and robust, permitting the intelligent decision--making required to ensure that the rigsite’s needs are met and the information required for analysis continues to be acquired uninterruptedly and securely.
Fiber Optic Sensing: Evolution to Value
Authors: Kamal S. Zafar 
Published: June 2014

Abstract
Harsh environments and access limitations continually challenge well surveillance in oil and gas production. Knowledge of subsurface characteristics, such as fluid flow, helps mitigate safety and operational risk while enhancing economic viability. As operators pursue technically challenging reservoirs, the development and use of advanced sensor technology has become crucial to exploring, developing and producing hydrocarbon reserves - while maintaining system integrity from the producing zone to transportation. Research and technical commercialization in fiber optic sensing has the potential to enhance many aspects of flow integrity and assurance, including barrier monitoring, reservoir and flow characterization, leading to increased safety, production protection, and production enhancement.
Fiber optic sensing has evolved over time at BP. This is with respect to diversity of applications and realization of benefits, while increasing our learning from implementation challenges. We will use this context to highlight the research, commercial ecosystem and business aspects of fiber optic sensing– particularly to provide a perspective on future uses of this technology. Using an integrated approach, the goal of this paper is to increase awareness and promote adoption. We do this by making a case for accelerating integration, collaboration and standardization among the operators, service providers, equipment manufacturers and systems integrators to stimulate and to drive efficiencies and value.
Continuous Improvement of Assets Through Existing and New Digital Oilfield Technology
Authors: Kamal S. Z. , Williams J. , Liddle J. 
Published: June 2014

Abstract
Over the past decade, upstream exploration and development companies have deployed "digital oilfield" concepts as a means to integrate and effectively utilize real-time data to influence and support operational decision making. These deployments have, in general, resulted in enhanced safety management, reduced operational risk and cost as well as increased production.
At BP, we are maturing and deploying a new generation of real-time capabilities that combine domain knowledge with technical expertise to sense, gather, analyze and synthesize information to enhance decision making to efficiently utilize technology and standard real-time work processes at our assets. In this paper, we will share our experience of taking BP’s inventory of current deployments to benchmark and assess the state of real-time instrumentation, data acquisition, transmission and staff ability as a means to identify, quantify and prioritize opportunities. This assessment includes an evaluation of each asset’s ability to sustain and adopt new capabilities in a holistic manner, resulting in prioritized implementation plans to realize potential improvements.
The scope of our assessment spans upstream processes from reservoir management all the way through export. We are specifically interested in key interfaces between the reservoir, well, facility and export lines to identify system optimization opportunities to improve functional integration and real-time decision making.
A Center of Excellence for Electrical Submersible Pumps
Authors: Spagnolo S. , Pilone S. , Corti L. , Astorino G. , Dellabianca A. , Di Renzo D. , Ogidi M. 
Published: June 2014

1
Abstract
The center of excellence concept is worldwide associated to new software, tools and technologies that help the team to pursue excellence in a particular area.
The increasing use of sensors and gauges in the Oil and Gas field drove eni to develop internally the Center of Excellence for Electrical Submersible Pumps, to monitor and interact directly with the worldwide Business Units and to address the ESP issues.
The tool and all the technologies behind had been developed by the Artificial Lift team, under the Completion Department, thanks to the strong effort of the IT Department in San Donato Milanese, Italy.
The Center of Excellence (from now CoE) gives mainly the following information for each well: Pump details and operative parametersWell surface dataKey Performance Indicators
All the data are collected in real time and the team can visualize any variables to perform a detailed analysis.
The CoE system is a web-based tool that is available on the eni intranet, and provide the possibility to store well-related documentation.
The most important advantage given by the CoE is the possibility to navigate through the KPIs, easily adaptable based on the field experience.
One of the analyses possible in the CoE consists of comparison of the real-time pump intake and discharge pressures and the relevant simulated values retrieved from the Prosper model stored in the CoE system.
In case of mismatch, a notification will be generated and will be sent to the technicians (via mail).
Once the wells that are producing with KPIs out of the desired range have been identified, the Artificial Lift team can immediately take corrective actions.
Presently the tool is fully operative for 20 wells in Alaska, and for 1 well in Italy and for 20 wells in Iraq and the process is ongoing to have other eni BUs online.
Definitely the CoE could be helpful to optimize the operation and to analyze the wells in a smarter way than in the past.
Solving Deepwater GoM Pore Pressure Puzzle: Multiple Activation Reamer Eliminates Trip Prior to Running Coring Bottomhole Assembly
Authors: Yi Xianjie , Corbin Kevin , Davis Jefferson , Davis Patrick , Mujumdar Hrishikesh , Nagaraj Mahavir , Yalcin Oguz 
Published: June 2014

Abstract
The nature of pore pressure profile on deepwater Gulf of Mexico wells dictates the need for hole enlargement while drilling (HEWD) on several intervals. HEWD is a well-established practice in deepwater GoM and allows casing programs with smaller ID clearance between consecutive casing strings.
Although the reservoir section is typically drilled as a single diameter, HEWD is required for many of the larger upper hole sections. However, in some cases drilling conditions require the operator to deviate the casing program from plan. On a recent deepwater Gulf of Mexico Lower Tertiary well, pore pressure anomalies, high mud weight and associated equivalent circulating density (ECD) required the operator to raise formation integrity test (FIT) to the maximum limit while drilling the 14½" x 16½" section. To solve the problem it required premature setting of a 14" casing string.
The subsequent12¼" section was initially planned as a single diameter drilling interval. However, to account for pore pressure variations experienced on the previous section and to avoid narrowing of the producing casing size the plan was modified to incorporate a contingency liner. The 12¼" section would have to be enlarged to 13½" in case a contingency 11-7/8" liner was needed. Adding to operational complexity, the original drilling program included a plan to core the 12¼" section. To stabilize the coring BHA would necessitate a minimum of 250ft of 12¼" rathole. To achieve all 12¼" objectives, it would require an extra unplanned trip.
To solve application intricacies, the operator elected to use a new-type ream-on-demand (RoD) system in the 12¼" section and eliminate multiple trips to change out BHAs. RoD technology is equipped with an innovative hydraulic mechanism that can be opened and closed multiple times as required while drilling.
After risk assessment and pre-job planning, the 12¼" section was successfully underreamed to 13½" diameter with the RoD tool. The pressure regime was carefully monitored and it was determined the 11-7/8" contingency liner was not required. The reamer was then closed at the top of the coring section and a 12¼" borehole was drilled an additional 250ft offering the required stabilization for the subsequent coring run. Utilization of the RoD technology eliminated a round trip prior to using the coring BHA and significantly increased operational efficiency while enhancing project economics.
Innovative Heavy Landing System for Ultradeep Offshore: Extended Slip Crush Resistant Tube, Enhanced Slip Design and Heavy Weight Carrier
Authors: Franchi Jonathan , Granger Scott , Flores Vincent , Vierke Andre , Grotherr Joern 
Published: June 2014

Abstract
The offshore industry's current trend is driving towards ultra deepwater wells, combined with deeper total depths. In order to be able to set and run larger and heavier casing strings with hook loads approaching or exceeding 2.5 million lbs, an innovative heavy duty landing system has been developed and put on the market.
Such systems must be capable of landing heavy loads while ensuring slip crush resistance. It includes an extended slip with enhanced design (coupled with a new greasing system), a 2.5 million lbs landing carrier and a pipe with a thick walled high strength material section, a light weight tube, and a rotary shouldered connection.
One of the current operational challenges with existing heavy duty landing strings is linked to the positioning of the slips, in particular when using extended slip designs. The limited length of the slips area requires additional time for proper positioning and set up. To address these issues, a new slip proof section design has been developed: the combination of an extended crush proof section and the absence of a heat affected zone in that particular area decreases running time while completely eliminating the risk of setting the slips on a weak point.
The "Spiri-Reinhold pipe crushing" formula has been used to design this system. However, considering the approximation of this model's results, crushing performance has been assessed using the Finite Element Analysis, as well as physical tests performed with a specifically designed pulling unit. These full scale test results have been compared to the ones obtained with both the Finite Element Analysis and the standard "Spiri-Reinhold pipe crushing" formula.
Unified Team Approach: Leveraging Real-Time Capabilities Reduces NPT while Enhancing HSE Effectiveness
Authors: Ibrahim Hani , Gidh Yash 
Published: June 2014

Abstract
Significant improvements in remote drilling operations have been made in recent years. With proper positioning, these advances could help mitigate the challenge of replacing a retiring workforce. Another concern when transitioning from a tenured employee to one with less experience is work efficiency. While data from the USA Federal Bureau of Labor Statistics has shown the trend for injury accidents has been steadily declining, incidents of Non Productive Time (NPT) have gone up significantly. It appears the traditional approach of passing knowledge to the next generation of engineers has been broken negatively impacting the drilling industry.
To address the disturbing trend, a Middle East operator has been investigating various technologies to facilitate improvement and reduce NPT. The provider has applied a strategic combination of services and modeling systems to achieve the objective including a real-time ANN drilling parameter optimization system that provides information to ensure maximum run length from all bits and downhole tools at the highest possible ROP. Benefits of the system include extended tool life, fewer trips and the ability to manage the bit's dull condition.
The provider's mud logging managed the operation locally at the well site, while their drilling and measurement personnel monitored the processes at the operations service center in the Middle East. In Houston, the bit company offered technical assistance effectively covering the drilling operation continuously.
The unified team approach involved getting the operator engaged as a key member in the planning and execution stage. The process yielded higher data visibility, making it easier to identify and reduce NPT. It also aided in improving workflow and furnished optimized drilling parameters at the rig-site to ensure improvement in drilling efficiency and higher ROP. By leveraging real-time data, operators can optimize drilling efficiency to help bridge the experience gap until the next generation of drilling engineers are fully trained.
Development of Well Complexity Index to Improve Risk and Cost Assessments of Oil and Gas Wells
Authors: Nzeda Blaise G. , Schamp Juergen H. , Schmitt Thomas 
Published: June 2014

Abstract
The Well Complexity Index (WCI) is composed of Drilling Complexity Index (DCI) and Planning Complexity Index (PCI). The DCI addresses mainly subsurface challenges encountered during drilling operations (including those related to drilling rigs, equipment, weather, etc.). The PCI addresses surface challenges such as logistics, geopolitics, environments, and climate. Wintershall has developed a Drilling Complexity Index and a Planning Complexity Index, which are simple systems used to rate the complexity of well planning and operations during the project evaluation and gated planning phases; from the conceptual or pre-screening phase through the detailed design phase to the execution phase.
The development & evaluation of Wintershall's Well Complexity involved the following tasks:
Definition and ranking of factors that influence a well's complexity, splitting them in surface and sub-surface factors. Development of a simple method(s) to measure the planning complexity of a well; also called planning complexity index. The planning complexity index is a single value that represents the complexity of planning the well. Development of simple method(s) to measure the drilling complexity of a well; also called drilling complexity index. The drilling complexity index is a single value that represents the complexity for drilling the well. Testing and calibrating of both numbers for different well types (exploration, appraisal and development) in various project phases and countries and comparison of the results. Comparison of Wintershall well complexity to other publicly available complexity indices and verification of the validity via an independent outside contractor. Using Wintershall well complexity tool to compare wells independently of the trajectory, type, geographical location, pressure, geology, etc. Comparing Wintershall Drilling Complexity Index tool to Rushmore's RDI and Dodson's MRI.
Both numbers represent early warning indicators that are often based on limited information. They can be used in the risk management process to identify potential risks and areas of concerns. Human and financial resources can also be allocated accordingly; based on the complexity of the drilling project.
Alternative Drilling Fluid Weighting Agents: A Comprehensive Study on Ilmenite and Hematite
Authors: Tehrani Ahmadi , Cliffe Angelika , Hodder Michael H. , Young Steven , Lee John , Stark James , Seale Suzanne 
Published: June 2014

Abstract
For many years, barite has been the standard weighting agent in the drilling fluid industry. Its high specific gravity has helped produce mud weights in excess of 19 lb/gal. Its hardness has rendered it easily millable to a particle size that reduces settling and minimizes losses on shaker screens and its adequate inertness has enabled it to be used in a wide range of drilling fluids containing different chemical components. Recently, however, dwindling supplies and increased consumption of premium barite have led to significant price increases across the world and a reduction in specific gravity in most commercial grades. This has led to renewed interest in alternative weight materials.
Ilmenite and hematite are two minerals that have been used sporadically in the field. Compared to barite, their higher density impacts both the rheology of the fluids and the settling rate of the weight material. A known issue with these materials is their relatively high hardness, which can give rise to abrasion/erosion in the tubular and surface equipment. Another effect that has not been addressed sufficiently is the magnetic characteristic of these iron oxide-containing minerals which has the potential to affect the operation of direction drilling and some other downhole tools.
There have been many studies on the use of ilmenite and hematite as weight agents for drilling fluids. These have dealt with the above issues individually or in a scattered manner. In this paper, we report the results of a comprehensive laboratory study on the application of ilmenite and hematite as weight materials for both water- and oil-based drilling fluids. The study includes the effects of different size grades of the materials on rheology and fluid loss, as well as dynamic and static sag.
The paper will present relative abrasiveness of the materials compared to barite as measured by two different methods, and recommend size grades that can minimize the abrasion effects. The paper will also report the results of magnetic property measurements which impact operation of several downhole tools, and compares these with that of barite and several other minerals. To complete the comparative testing of these minerals, the results of heavy metal analysis will also be reported for each test mineral.
New Generation of High Strength Sour Service Drill Pipe: A Breakthrough Innovation to Address Ultradeep and Extended-Reach Drilling Challenges Combined with H2S Environments
Authors: Rodrigues Ricardo , Flores Vincent , Godeke Kenneth , Thomazic Aurelie , Thebault Florian 
Published: June 2014

Abstract
"Sour Service" refers to a well environment containing Hydrogen Sulfide (H2S), which is naturally associated with acid conditions. It is well known that H2S is hazardous to human health, living organisms, and more generally to the environment. It is for this reason that wells found with Sour Gas were often carefully plugged and abandoned in the past. H2S can also lead to catastrophic brittle failure of drillstring components: the physical phenomenon associated with Sour Service Environments and affecting steel based products under applied or residual stress is known as H2S embrittlement or more specifically as Sulfide Stress Cracking (SSC).
With the increasing demand of gas worldwide, some highly sour oil and gas reservoirs are being explored, mainly in Russia, the Middle East, China and North America, and are now more and more associated with complex well profiles – such as deep reservoirs or extended reach wells. The use of high strength drill pipe is essential to achieve such drilling objectives; however it does represents significant technical challenges in terms of drill pipe integrity and operational safety with the current high strength grades available on the market, such as S-135 drill pipe. Because higher strength is generally detrimental to Sulfide Stress Cracking, innovative chemistries and new heat treatment processes are needed to push Sour Service material limits even further.
A new high strength drill pipe family has been developed to specifically address those challenges: these new grades exhibit a minimum Yield Strength (120 ksi) higher than the current Sour Service grades available on the market as described by the current industry standards (95ksi or 105 ksi Specified Minimum Yield Strength). In order to guarantee the SSC resistance of these high strength materials, pipes and tool joints are tested as per the NACE standards. A first string of this high strength material is already being commercialized and used for the first time in offshore wells in the North Sea.