bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enabling Real-Time Distributed Sensor Data for Broader Use by the Big Data Infrastructures
Authors: Yang Don , Denney Tommy , Bello Oladele , Lazarus Sony , Vettical Celestine 
Published: August 2016

Abstract
Petroleum exploration and production processes typically generate enormous amounts of petro-technical data using sub-surface and surface sensors. The acquisition, transferring, managing, and interpreting of these huge sensor data, as well as the decision making based on it has led to the advent of the digital oilfield phenomenon in the petroleum industry. To achieve improved efficiency, accuracy, and performance, many E & P operators are aiming to apply fiber optics distributed temperature sensing data management technologies to add volume. Currently, high volume distributed sensing data transfer, storage, processing, archiving, retrieval and exchange system in the petroleum industry still face big challenges such as high cost of hardware and software, complicated implementation and deployment framework that is difficult to sustain such as scale and upgrade, as well as compatibility for data provided by different vendors. An efficient online real-time elastically scalable system that enables fast retrieval from big data infrastructures is therefore essential.
This paper describes a scalable web based enterprisefiber optic infrastructure for data exchange, management and visualization. This platform applies multi-tier client-server architecture, scalable distributed databases, PRODML (Production Markup Language), and web services technologies to provide a reliable mechanism to bring fiber optic data from the field site to the corporate network in real-time and enable user to visualize the data anywhere, any time. The support of PRODML industry standard make it vendor neutral and allow data exchanging from different systems and sharing data among users and different applications. The distributed Cassandra database enables the scalability to handle the fiber optic big data in a high performance and efficient way. Finally, the global inventory management system allows keeping track of changes to the asset and the instrumentation configuration over the life of the distributed sensor systems, as well as the ability to correlate the measurement data to the proper asset configuration. A case study is presented that demonstrates successful field testing to verify the functionalities of the newly developed system for high data volume distributed sensors. Specific attention is given to many advantages being offered by this new framework over existing ones.
Efficient Optimization Strategies for Developing Intelligent Well Business Cases
Authors: Vasper Adam , Mjos Jon Endre , Duong Tran Thi 
Published: August 2016

Abstract
In this paper, we evaluate optimization techniques to develop, or support, business cases for Intelligent or Smart Wells. A commercial reservoir simulation platform and two reservoir models based on published work are used. Recommendations are made on which methods are most appropriate for large or small numbers of flow control valves (FCVs), available computing power and other parameters.
Optimization techniques are categorized as either Closed Loop or Model Based. Closed Loop or Reactive methods respond to specific, measured properties such as water-cut or gas-oil ratio, by opening or closing downhole flow control valves. Model-Based methods use reservoir models to determine the optimal set of flow control valve positions versus time. They can, therefore, behave in a defensive or proactive manner to delay the production of unwanted fluids, as well as a reactive manner, to choke back sections of the well producing unwanted fluids. In this paper, Closed-Loop and Model-Based methods are compared in terms of computational cost. A simple procedure for defining the constraints used in the optimization process is proposed. The procedure is shown to increase the efficiency of the optimization process significantly.
Real-Time Interactive Remote Display of DTS and DAS Data for Well Treatment Optimization
Authors: Dickenson Paul , Brants-Menard Sacha , Telsey Mike , Stanbridge Adam , Wilson Colin , Akin Josiah , Roman Nathan , Anifowoshe Olatunbosun , Yates Malcolm E. , Carney B. J. , Costello Ian , Hewitt Jay , Warner Ryan 
Published: August 2016

Abstract
The value of data can be greatly enhanced if the data are available at the right location and in a timely fashion. This can be a particular challenge for the often considerable volume of data collected using distributed measurements such as Distributed Temperature Sensing (DTS) and Distributed Acoustic Sensing (DAS). In this paper we describe a novel solution using multiple levels of data reduction yielding data of different sizes and fidelity. These are then transmitted for viewing at the wellsite, in real time at a remote location, or subsequently for post-job evaluation. This approach is demonstrated using a case study of a well stimulation operation from the United States.
Risk Based Management of Wells Safety-Related Software Systems
Authors: Reed D. , Turnbull J. 
Published: August 2016

Abstract
The Operator has long recognized the risks associated with specialist well engineering and wells services software and how insufficient management could have consequences to both safety and the environment. Sawaryn et al. (2003) laid out a set of principles for improving the management and use of Safety-Critical drilling engineering and well services software.
Through a series of initiatives, the Operator has developed these principles into a risk based management practice aligned to international standards; IEC 61508 (2010). This has enabled better understanding by global wells and IT on the influence software systems have on group loss of well control risk barriers. It has also enabled the creation of a more robust management framework.
A significant development has been to simplify the classification and differentiation between Safety-Critical and Safety-Related systems. It was recognized that applying a broad brush definition of "Safety-Critical" to wells applications created a high burden of responsibility and weakened the definition of Safety-Criticality. For example a system with no human interaction before an action occurs should be managed more rigorously than one whose output can be validated and corroborated. When applying these criteria to wells software it was found that none were Safety-Critical, therefore the scope of this paper is confined to Safety-Related software.
A risk based approach has been used to enable easier classification of software, removing some of the ambiguity prevalent in the past. This has reduced the risk for project delivery and IT support operations. Using risk based approach has also allowed a more objective approach to management, enabling better measurement for the controls discussed in this paper.
Work in this area is still relatively immature and there remain many challenges. For example, data integrity can be difficult to manage and can weaken controls such as algorithm validation. Additionally complex systems used by wells but owned by other upstream functions can be difficult to manage unless those functions follow the same methodology.
This paper outlines the initiatives the Operator has taken to reduce the risk presented by Safety-Related software, highlighting the benefits, challenges and opportunities.
Surface Management of Gas Breakthrough in Thin Oil Rim Waxy Reservoir: A Case Study
Authors: Agrawal A. , Leeuwen P. V. , Demirbas B. , Hajj J. 
Published: August 2016

Abstract
With technological advancements, new and improved techniques have progressively been deployed to maximize recovery from a thin oil rim development. While some of them have a lasting influence on the well behavior such as placement of the well bore in the oil column, others such as zonal control using Sliding Side Doors (SSDs), Interval Control Valves (ICVs) or Interval Control Devices (ICDs) provide flexibility for altering well performance during operating life of the well. However, any intervention be it the subsurface zone manipulation or surface choke manipulation or ICV control needs to be justified in view of the anticipated gains against the risk incurred and resources required for the intervention on the basis of well performance (test data) and subsurface interpretation.
The field for this case study is a thin oil rim with a large gas cap and a high wax content facing twin challenges – gassing out of wells and waxing of tubulars and flowlines – both of which require an optimization of preventive interventions to minimize deferment and corrective interventions. The required interventions such as choke and gas lift changes, zone changes, scraping, hot-oiling, steaming and pigging consume significant man-hours for surveillance, planning, execution and monitoring of the impact of the job on well performance. The desire to follow each intervention by a well test for system optimization overwhelms an already stretched routine well testing schedule. The resultant deferment due to sub-optimal production was estimated to be 10-15%. The solution was in breaking down the problem into mini-challenges and addressing them by deploying robust technologies and adopting smarter ways of working.
In this paper a simple surface technology that helps managing gas breakthrough is presented. This technology when combined with smart surveillance techniques enables efficient Well, Reservoir and Facility Management (WRFM) for thin oil rims with added wax challenge. Following impacts have been seen: An average increase in production by 10% was realized. The project payback was less than 2 months.Up to 80 man-hours per week were freed allowing team to focus on additional barrel generating opportunities.Reduced Health, Safety, Security and Environment (HSSE) risk corresponding to reduced well intervention besides stabilized production.Reduced deferment by optimal timing of preventive intervention and reduced risk of incurring cost and deferment from a corrective or reactive intervention.Improved team productivity and fresh energy from use of smart ways of working.
The novelty of this surface technology for managing gas breakthrough is in its ability to optimize, accelerate and thereby squeeze production from a thin oil rim development in the license period. The resulting production stability then provides a basis for deploying smart surveillance techniques for sustainable increased efficiency.
Robust Derivative Estimation for Decline Analysis from Noisy Production Data
Authors: Subrahmanya Niranjan , de Waele Stijn , Liu Wei , Tewari Ashutosh , El-Bakry Amr , Pais Darren 
Published: August 2016

Abstract
Efficient reservoir management requires regular analysis of large amounts of data to provide insights for decision making in a timely fashion. Well testing provides a key source of data for production surveillance and optimization by estimating oil, water and gas rates at irregularly sampled testing times. Although a significant amount of effort is spent on ensuring the quality of these well tests, the acquired data is still likely to have large uncertainties due to the complexity of flow dynamics, and challenges in multiphase flow separation and measurement. The resulting production history measurement for a well is therefore a noisy, unevenly sampled time series with potential significant outliers. A key point of interest is to perform decline analysis, which involves monitoring production trends (the derivative of the production time series) to ensure optimal well and reservoir performance. In addition to noise, the estimation of production trends is complicated by the effect of improved/enhanced recovery mechanisms (such as water flooding, steam injection etc.), well stimulation, and communication between wells, all of which may cause the production to deviate from expected parametric decline curves. As a result of this complexity, decline analysis typically requires significant manual effort in cleaning and segmenting the data and then fitting parametric curves to the extracted segments; this is challenging to do on a regular basis for all the wells. A robust and automated method to estimate production trends will enable continuous production surveillance and optimization in fields with hundreds to thousands of wells. In this paper, we report an effective method to address this challenge using a non-parametric approach based on robust regression for joint time series modeling and derivative estimation. Some key advantages of this approach over a conventional approach are a) it does not require manual data segmentation b) it is tolerant to a high amount of noise including some bad outliers c) it does not require manual choice of parametric decline curves. We compare results with conventional approaches and demonstrate benefits on synthetic production data.
Leveraging Change Agent Networks to Enable Successful Transformation
Authors: Mortman Michelle , Zeringue Amy 
Published: August 2016

Abstract
It has been said, "Change is difficult. Not changing can be fatal." In today's ever-changing business environment, we are required to change and adapt quickly. If we then add additional factors such as complex, transformational projects across distance and function, change becomes even more difficult. Finding ways to effectively manage change within your organization by leveraging Change Agent Networks can be a means to facilitate an organization's ability to evolve and change for the future.
In intelligent energy projects where people, process, and technology must come together to enable true transformation, implementing meaningful and sustainable change can be challenging. Building collaborative partners from key stakeholder groups is necessary to bridge gaps that often exist in complex project environments where distance and function serve as additional barriers to project success.
Change Agent Networks are groups of individuals representing the target audience of a project. When identified early on, they can provide critical input and support to a project throughout design and development activities to ensure the solution satisfies the needs of the business and ultimately delivers business value. Further participation in implementation and beyond can help to ensure the project is received positively by the business and that business results are reported.
A New Communications Protocol for Real-Time Decision Making
Authors: McKenzie William , Schave Robert , Farnan Mark , Deny Laurent , Morrison Pete , Hollingsworth Jay 
Published: August 2016

Abstract
The current standard infrastructure for delivery of wellsite data uses SOAP Web services over the HTTP protocol. More than a decade of experience in this environment has revealed significant challenges for timely delivery of wellsite data. At the same time, data volumes are increasing exponentially in an ever more connected world. To address these issues, an entirely new protocol stack, based on the latest available Web standards, has been developed.
The Energistics Transfer Protocol, or ETP (Energistics 2016), is a new communications protocol specification that enables efficient transfer of data between rig site, office, and applications. The initial use case is for real-time data; however, it is anticipated that ETP will be expanded to include functionality for historical data queries.
ETP has been specifically envisioned and designed to meet the unique needs of the upstream oil and gas industry and specially to facilitate the exchange of data in the Energistics family of data standards, which includes WITSML™, PRODML™ and RESQML™.
One of the initial goals of ETP is to support everything from WITS-style devices through to html5-enabled mobile devices with a single, simple-to-implement protocol. Some of the main use cases are to move real-time data between applications, including: Device to wellsite provider (acquisition system)Transfer from a wellsite provider to a WITSML store (aggregation server)Transfer of data from WITSML store to WITSML store (server replication)Transfer of data from WITSML store to client applications
ETP defines a notification mechanism so data receivers do not have to poll for data and can receive new data as soon as they are available from a data provider.
This paper presents the challenges faced by the industry, a description of the alternatives and technology choices that have been made, and an analysis of performance improvements based on laboratory and field trials for both WITSML (drilling) and RESQML (earth modeling/reservoir).
Operations Excellence Maximizes the Value of the Digital Oilfield Implementations
Authors: Coffin Guillaume , Florez Fabian , Salim Muzahidin Muhamed 
Published: August 2016

Abstract
In a competitive environment and uncertain economic conditions, running flawless operations is becoming an even more acute concern. This is true for any operator and for service companies providing production optimization services. To this end, a digital oilfield program was implemented across several assets as part of an operations excellence program.
The operations excellence program was designed as a vehicle to maximize the performance of operations and implement a common culture in the assets. This comprehensive program covers all main operational processes of the asset. Each of the domains is addressed from the point of view of processes, people, and management systems, to implement best practices and achieve a common culture. A well-defined methodology enforces the change.
The digital oilfield program was designed from the beginning as an essential element of the operations excellence program, one with impact on the work processes and value generated by the assets. It comprises a standard that defines the minimum requirements, an implementation methodology, a technical guidance, and audits. When combined, these programs provide efficient integrated management of the assets.
If the digital oilfield is usually seen as a technical project focusing on infrastructure, its implementation as part of the operations excellence program enables achieving three major objectives: modifying operational practices to take the technology into account, framing the digital oilfield to optimize its value, and feeding operations excellence with reliable data to maximize decision quality.
Real-Time Surveillance, Analysis and Control Via Secured Digital Intelligent Technology in Joint Operations – Wafra Field
Authors: Bahbahani Baqer , Jagannathan Rajaperumal , Heshmat Kareem , Mohamed Assem 
Published: August 2016

Abstract
Applying Smart techniques and latest digital intelligent technology in oil field created a new vision of well surveillance. Communication is considered the backbone of any digital oil field project. The challenges faced while establishing field-wide communication from well-site to office. Monitoring and optimization software was rolled out over 900 artificially lifted wells in WAFRA field. The deployment depended upon certain factors such as hardware; including field instrumentation, data communication and integration of multiple data sources.
The deployment of static, dynamic, real-time data integration and remote well control were established via regular meetings and creation of user groups with common interest in daily operations to setup software solution that communicates with existing field level infrastructure located at each sub center. Intelligent setup allowed different teams to access real time data simultaneously, were decisions are taken on fully awareness of well behavior, creating a massive database for further analysis capabilities. The presence of historical, real time data and instant alarm detection in one screen gave the opportunity to track and evaluate well performance based on changes noticed.
Establishing communication involved opening a limited number of ports between field and office with the help of IT. However steady communication took a while to stabilize addressing different factors related to field network and security. Challenges faced included:
Firewall between field and office. Mapping between the down-hole gauges, variable speed drives and remote terminal units. Parallel scanning between an existing field level systems. Sub center level communication issues. Data security.
A data validation effort related to communication was made at one sub center between field instruments and subsequent relay to office. This established a standard that was set over the rest of field. A Management of change (MOC) was setup to address all high level issues related to the communication network. Due to parallel scan, the data transmission to user desktop was restricted to every two hours for most wells. The result of the collaborative effort between different teams build a strong, smart and reliable surveillance system creating a new way for real time analysis and powerful diagnostics engine.
Successfully deployment of the Life of Well Information Software for 900 artificially lifted wells in a partitioned neutral zone between Kuwait and Saudi Arabia, allowing all JO-engineers accessing LOWIS form different location (Saudi Arabia Chevron, Kuwait Gulf Oil Company and Admin building camp in Wafra) created a portfolio that enabled the engineers to maximize the performance of artificial lifted wells, adapt to changing well conditions and continuously monitor their assets.
Standardized D&C Rig IT Solutions Using a Software-Defined Data Center Approach
Authors: Milliet Christopher 
Published: August 2016

Abstract
Using virtualization and other pioneering technologies to develop a hybrid platform of servers, storage, and networking that can support a variety of rig based systems such as Real-Time Data Collection & Aggregation, Data Analytics, Collaboration, and other core IT services (email, file sharing, etc.) all of which are being hosted locally at the rig. In addition to the infrastructure components we have also adopted new application technology solutions in support of Geological & Geophysical Operations Wellsite Services, business partner connectivity and collaboration, and introducing tools to enhance telecommunications/network security at the rig. All of the activities have resulted in increased standardization, innovation and reliability of Information Technology systems supporting D&C and G&G Well Operations. The paper will highlight a variety of use cases where we have utilized variations of converged and software defined data center solutions based on uniform blueprint configurations at our rig sites. In particular, within our Deepwater Gulf of Mexico operations and Frontier exploration drilling programs in very remote locations. We will describe the cost savings benefits of moving to a standardized platform utilizing off the shelf IT technology solutions vs. oilfield specific IT technology tools. This paper will highlight our successes and lessons learned within this emerging area of focus and provide insight on where we believe the industry will be heading in the future and preparing for more data and technology issues such as Cybersecurity.