bluuebunny/crossref_metadata_2025_split huggingface dataset:
Investigation of a New Simulator for Surfactant Floods in Low Permeability Reservoirs and Its Application in Chao-522 Field, 2010 Update
Authors: Yin D. , Gao P. , Pu H. , Zhao X. 
Published: July 2010

Abstract
In this research, the modeling and application of a new three-dimensional, two-phase, three-component surfactant simulator are presented. The simulator is based on the non-Darcy flow characteristics of surfactant flooding in the low permeability formations. The change of threshold pressure and influences of surfactant on convection, diffusion, adsorption, and retention, are all considered. A new equation for the calculation of surfactant adsorption is employed, which can significantly promote the matching degree between the mathematical model and field practice. This mathematical model was adopted to conduct a field scale simulation modeling for a surfactant flooding pilot of the Chao-522 field, Daqing.
Base on the predictions of several injection cases, the injection process was fixed and injection parameters were optimized. The practical injection has received significant feedbacks, like pressure reduction, injection rate increase, and oil recovery increase. The average incremental oil production rate for the individuals was up to 30%. The pilot testing showed a favorable industrial potential in the Chao-522 field.
Advanced Collaborative Environments - The Growth of a Capability Transformation Programme
Authors: Goodwin Stephen , Ford Alan , Griffiths Peter , Moore-Cernoch Kerry , Williams Paul 
Published: July 2010

Abstract
Advanced Collaborative Environments (ACE) have been shown to generate improvements to BP's business performance. To deliver efficient collaborative practices, asset teams have altered their ways of working, their organisational structures and business environments. These ACEs are designed to ensure that offshore production facilities can have immediate access to shore-based specialist support teams via visual, audio and data connectivity to improve the quality of decision making and the problem-solving processes.
BP has several ACE programmes in operation around the world, supporting application of the Field of the Future concept and driving better decisions faster. This paper describes the performance benefits (in terms of increased production, lower costs, improved safety and operational integrity) that the creation and usage of these ACEs have brought to the organisation, as well as highlighting the need to see collaborative environments not as purely process or technology driven initiatives, but more as a capability transformation programme. The authors explain the necessity of genuine engagement and ownership by the end-users so they can search for and leverage advantage themselves. ACE programmes require significant operating expenditure, and it has proved of vital importance to put efforts into maintaining the programme profile, sustaining senior management endorsement and encouragement of the programme, both in funding and leadership behaviour.
This paper also describes the need to develop relationships centered on trust and respect between the onshore and offshore communities so that jointly made decisions can be consistently implemented with confidence.
The personal characteristics and behavioural traits and etiquettes which individuals need to have to work effectively within these environments are also discussed. Offshore personnel need to know when to ask for advice and in turn onshore users can become "respected brokers" to either deal with the issue themselves or seek further input from specific functional teams.
The similarities and differences between the Gulf of Mexico (GoM) and North Sea programmes illuminate the forces which are at work when shaping an ACE programme, and along with the successes, areas for further improvement and plans for the future of both programmes are analysed.
Asset-Wide Reconciled Production Monitoring—A Key Enabler to Successful Real-Time Field Management
Authors: Ibrahim Kolin , Narayasamy Devarajan , Jaberi Md-Yussof , Briers Jan , Goh Keat-Choon , Boer Frank de 
Published: July 2010

Abstract
This paper describes how Brunei Shell Petroleum Co Sdn Bhd (BSP) uses cross validated and reconciled real time production data across large offshore and onshore production networks to support more proactive day-to-day oil and gas production surveillance and management. Examples are presented of the gathering network surveillance systems for the extensive BSP East and Darat Production Assets.
In modern oil fields, there is an abundance of instrumentation distributed over often large geographical areas. The production network ranges from the individual wellheads, to production manifolds, test and bulk separators, past surge vessels and export pumps, to crude dehydration tanks at a central crude terminal or to the gas compressors and gas export points. At least the initial parts of the production gathering network at the wells will have multiphase flow with uncertain and variable oil, water and gas proportions. Normally the most downstream flow meters are well calibrated with good calibration records, but the actual accuracy of the majority of the flow meters upstream will be uncertain, and they will not be nominally designed to handle multiphase fluids or mixtures of fluids with varying densities. Conventionally, it is regarded to be problematic to track production variations in real time across the network back to the source wells. This is due to issues with metering multiphase flows and assumed uncertain transport delays.
It is shown here that it is now practical to track in real time production rates across large production networks, working back from the most downstream, well metered, points to the individual bulk separator units or production platforms or the wells themselves. Indeed, it is possible to obtain a consistent, real-time reconciled view of the current production rates across these larger production networks. This allows more accurate surveillance of production from the wells, early detection of measurement issues and quicker responses to system upsets. Various common blockers to real time network wide production flow surveillance are addressed, including noisy meters, storage tanks, on-off pumps and hard-to-measure multiphase flows from the wells. The work reported may be seen as a "top-down" approach that complements the existing metering systems, integrating the data to "make the best of" all available metering and instrumentation. An example shows how better metering and instrumentation, virtual metering and real time data analysis are combined to detect and correct significant discrepancies.
I-Field Data Acquisition and Delivery Infrastructure: Khursaniyah Field Best in Class Practices: Case Study
Authors: Almadi S. M. , Al Dhubaib T. A. , AhmadHusain H. A. , Al Walaie S. A. , Al Khabbaz F. M. , Alaidarous O. A. , Al Temyatt S. F. 
Published: July 2010

Abstract
Khursaniyah Upstream Facilities development program has successfully implemented the latest systems and applications that support I-Field Data Acquisition and Delivery Infrastructure (I-Field DA&DI); providing better monitoring and early intervention capabilities. Such an implementation relies on a robust real time field to desktop data acquisition and delivery system. I-Field DA&DI integrated together different advanced intelligent surface and subsurface gauges and subsystems; forming data collection for reservoirs vital signs such as temperature, pressure, water cut, etc. The system is based on scalable, adaptive bandwidth, and with embedded resiliency that meets I-Field data acquisition and delivery requirements (data type, frequency, resolution, security, integrity, quality, reliability, etc.).
Saudi Aramco's earliest I-Field implementation projects were at Qatif and Haradh III. These projects were instrumental in developing I-Field data acquisition and delivery requirements for real-time reservoir management and production engineering. The projects assessment revealed limitations and challenges in the data acquisition and delivery infrastructure. Lesson learned from these implementations were adopted in the Khursaniyah Upstream Facilities Program. Furthermore, the Khursaniyah experience has resulted in new findings and lesson learned that will help in improving future implementations to increase systems capabilities and optimize cost.
This paper presents the experience and lesson learned from the latest implementation of Khursaniyah I-Field. The paper highlights examples of some of the inherited challenges in previous implementations and the newly adopted data acquisition and delivery architecture. The adopted architecture, methodology, and subsequent experience gained in overcoming these challenges now serve as a guide in future implementation.
Safety Presentation in Large Screen Displays—A New Approach
Authors: Weyer U. , Braseth A. O. , Eikås M. , Hurlen L. , Kristiansen P. 
Published: July 2010

Abstract
During the last decades, computerized operator stations and soft controls have replaced hardwired wall panels in the offshore petroleum industry. Aspects such as maintenance problems, increasing cost, and lack of flexibility motivate this move towards a computerized interface design. There is, however, a general consensus that there is a great potential for improvement with regards to how information is being presented in computerized systems.
IFE (Institute for Energy Technology) in Halden, Norway has developed and patented graphical symbols using a new design scheme called IRD (Information Rich Design). The displays based on this design scheme are not like traditional Piping and Instrumentation Diagram (P&ID) inspired design, but are based on pattern recognition in addition to use of a new dull color principle where only abnormal situations are highlighted. The new design scheme was initially designed for process interaction, but has become a state of the art standard for Large Screen Displays (LSD) in the Norwegian petroleum industry. Starting with process information, the concept has been further developed during the last years to also include safety information. The aim is to give the operators an overview of the safety state of the plant, and to provide the information needed when an emergency situation occurs. The information content of these safety displays has been specified in cooperation with operator crews through different projects for the Norwegian petroleum industry. The displays are developed using a rapid prototyping method.
This paper addresses, describes and discusses this new Information Rich safety display concept, using the dull color scheme. The motivation behind the information content of the displays is also explained. At the end of the paper some specific design examples and symbol explanations are provided.
Virtual Flowrate Metering in Subsea Producers and Injectors Enables Integrated Field and Reservoir Management: Don Development Case Study
Authors: Loseto Michele , Chacon-Fonseca Joel , Bagci A. Suat , Gilbert Russ 
Published: July 2010

Abstract
Continuous surveillance of production and injection well flow rates throughout field life is essential for well performance monitoring, reservoir management and to meet operational targets. Ideally, surveillance would be achieved using multiphase flow meters on each well, but frequently this is not economically feasible. As an alternative to providing continuous flow rate surveillance, several real-time rate estimation methods can be implemented using existing surface/subsea & sub-surface measured variables, and obtain Best Real Time Estimations (BRTEs) based on the confidence in each method. BRTEs at well level can be added to provide Aggregated Real Time Estimations (ARTEs) at both field and facility levels. Where physical meters exist, a direct comparison and cross validation can be made with the relevant ARTEs, ensuring accuracy and confidence in ongoing well and field surveillance.
The above BRTEs/ARTEs approach has been deployed on a well performance monitoring system in the Petrofac operated Don Fields Development (North Sea UKCS), centred on real-time surveillance and advanced data processing & visualisation. Estimations were implemented based on first principle equations validated with integrated models of reservoir, well and subsea/surface networks, providing Liquid Rate, Oil Rate/Water Rate, Gas Rate and Gas Lift Rate estimations on the production wells, and Water Injection Rate estimations on injection wells. Deployment included user interfaces to allow BRTEs configuration and updating, as well as Aggregate Tables to compare ARTEs with physical field and facility flow meters.
In summary, BRTEs/ARTEs successfully achieved the concept of virtual flow metering on the Don Development, providing the means for continuous well, field and facility surveillance. This enhanced surveillance experience is enabling unique optimization opportunities, allowing engineers to determine optimum settings for maximizing asset production and associated revenue.
We Have Built the Rooms, Our Work Processes are in Place – But Now What – Where is the Value?
Authors: Haugland Ketil 
Published: July 2010

Abstract
This paper addresses an unfortunate observation, that all too often, even the best intended integrated drilling operations get stranded. When this happens, advanced collaborative environments are reduced to function as little more than ordinary meeting rooms. What remain advanced are the fancy screens, the impressive communication technology and the latest in room design and furniture.
Why is this happening and how may it be resolved?
In trying to answer the above question, the paper look at the way knowledge management in the drilling industry appear to be concentrated about data - and information management; about ICT systems and software.
The paper addresses the actual collaboration that takes place inside the collaboration room, the role of people and human expertise. It discusses organizing principles and the role team-work and decision making.
Rather than subscribing to the view that decisions can be handled by automata the paper discuss the full complexity of oil well drilling and how decision making is actually happening in real-time under dynamic conditions. While computers crave rational decision processes, people make decisions from interpretation of less than perfect knowledge, based on experience and expertise.
The paper discuss naturalistic decision making (NDM) models such as recognition-primed decision making; how they apply in real-time and how engineers use them to make sense of the data available in collaboration rooms and Operation Support Centers when assessing real-time occurrences.
In offering solutions to the initial questions, the paper looks outside the drilling industry to other high-reliability organizations working in real-time. The final recommendations include experience from aviation, military and fire brigades etc. and how these organizations have defined the role of human expertise.
Use of Real-Time Data in Well Integrity Management
Authors: Chitale Ashish A , Blosser William R , Arias Brian J 
Published: July 2010

Abstract
Real time data provides key information that can be used to monitor oil and gas wells to maintain well integrity and avoid costly failures. Integrity management is at the heart of BP's operating philosophy. The company uses new technologies enabled by real time data to allow continuous improvement in well integrity management.
The use of real time rate calculations has provided technical assurance to maximize production within BP's deepwater subsea field development. Production has been increased by 10,000 stb/D while maintaining well integrity and process safety assurance within safe engineering operating limits. Similarly, the Na Kika fields apply advanced flux based tools and sand alarming capabilities to protect wells from sand completion failure. Additional fields are currently using BP proprietary technology to monitor and proactively alarm on wellhead annulus pressures, successfully mitigating the well integrity risk of collapsed tubing.
Well integrity management is critical for any operating company. In deep water environments where subsea well costs can exceed 100 million dollars, loss of well integrity can have serious consequences associated with production capability, loss of containment, reputational damage, and regulatory license to operate. Application of new technologies is transforming simplistic past practices into highly sophisticated automated monitoring and advanced control mechanisms enabled by real time data. These technologies have a vital role in delivering advanced capabilities so that engineers can make better decisions, faster, to help retain long term value.
This paper, through case studies, will demonstrate the ability to use innovative workflows and technologies, enabled by real time data, to identify and mitigate well integrity risks. Key risks such as annulus leaks, sand control failures, and mechanical failures are monitored using Field of the Future technologies. These examples from different operating areas of BP will demonstrate continuous improvement, showing how engineers use these technologies to maintain well integrity.
Semantic Web Technologies for Event Modeling and Analysis: A Well Surveillance Use Case
Authors: Zhu Tao , Bakshi Amol , Prasanna Viktor K. , Cutler Roger , Fanty Scott 
Published: July 2010

Abstract
The ability to identify events of interest at the surface and sub-surface, and use event information for various workflows and analyses is a key enabler for a variety of surveillance, monitoring, and optimization workflows. The scalability, extensibility, and maintainability of an event management system is directly related to the conceptual model used to represent events, the ease with which relationships between events can be encoded in the form of rules, and the type of rule engine that performs the analysis necessary to extract useful, actionable information from the frequently updated event database. This paper summarizes our experience with building a well surveillance application using semantic web technologies. Events are modeled using the web ontology language (OWL) and relationships between events expressed as rules in the semantic web rule language SWRL. An off- the-shelf rule engine aggregates the values of lower level attributes related to well performance and not only infers the well status ("alert" or "no-alert") but also provides the entire chain of reasoning that led to the particular well status. Although more work needs to be done to translate the reasoning into a form that is comprehensible to the domain experts, even the raw information is a valuable aid in understanding and validating the rule base. We discuss the advantages of using semweb technologies for event management: the relatively low code complexity, the ability to remove existing rules or add new rules of arbitrary complexity at run time, and the ease of encoding domain knowledge into events and rules. Evaluation of time performance of our application for different number of wells is presented. The broader significance of this work is in the context of understanding the right technology (or combination of technologies) to build logical, extensible, and maintainable systems for processing field events.
Field and Installation Monitoring Using On Line Data Validation and Reconciliation— Application to Offshore Fields in Middle East and West Africa
Authors: Couput Jean-Paul , Caulier Renaud , Wising Ulrika 
Published: July 2010

Abstract
In oil & gas operations, optimisation opportunities of the field production efficiency and performance can be developed and guaranteed by combining monitoring and control elements in so-called "value loops". Such an approach is possible when reliable and consistent data and information from the complete production system are provided to the right users at the right time.
This paper presents existing field applications of advanced data validation and reconciliation (DVR) techniques which use all available information and measurements in order to provide reliable and consistent data from reservoir to oil and gas delivery.
Implementation and application of advanced DVR to offshore production installations located in Middle East and West Africa are described in detail with specific focus on well production determination and gas balancing and measurements.
Specific highlights are given to advanced DVR models development, field implementations and on results obtained in continuous well flow rate calculations, in equipment monitoring and topside measurements.
By combining sensors, flow measurements and modelling, advanced DVR has permitted to question and validate measurements but also multiphase metering information, equipment operation and flow models parameters.
Operational field experience gained by TOTAL demonstrates that online use of advanced DVR techniques allows to: Improve continuous monitoring of well productionReduce inaccuracy of gas flow measurements and balancesDetect instrumentation failureMonitor field equipment behaviour
This gives the user the possibility to improve well production figures and environmental reporting and also the opportunity to optimize equipment operation and instrumentation maintenance.
Business As Usual Or Silos Of Excellence: Operationalising Intelligent Energy Through All Production Functions
Authors: Morris Carl , Taylor Dominic 
Published: July 2010

Abstract
Few would disagree that the philosophy of intelligent energy permeates through a large proportion of Upstream operators and service companies. Programmes of work to realise this philosophy are now mature. Collaboration, information visualisation, integration of information to aid decision making all feature as commonplace activities. However, the philosophy is largely siloed within parts of the subsurface community and a general intelligent energy culture does not exist throughout the E&P community. This is especially pronounced when we examine the changes, or lack of changes, that have taken place within operational surface teams over the last ten years.
This paper investigates the extent to which day to day decision making, aimed at optimising production at an acceptable cost, is fully integrated between sub-surface, drilling and surface operations and examines the value that can be generated through this level of integration. Taking surface equipment as an example, it goes on to examine the pre-requisites and integration points required to make a composite picture that means decisions are made taking into account all production constraints. It contends that reliance on automated data is insufficient and that everyone concerned with production activities, even down to operator and maintenance technicians, need to see themselves as key information providers into the production decisions that constantly need to be taken. Citing specific examples of where this has happened, positive cultural side effects can be seen. The paper concludes by looking at the pros and cons of transparency of information between sub surface, drilling and surface operations, effectively making all personnel information consumers and allowing them to input into optimisation decisions.