bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Integrated Collaboration Environment as a Platform for New Ways of Working: Lesson Learned From Recent Projects
Authors: Vindasius Julia 
Published: February 2008

Abstract
Upstream oil and gas organizations continue to face challenges to prove that the digital oilfield will improve decision-making, achieve higher quality analysis, and effectively use smaller pools of skilled resources. Both corporate and business unit champions recognize that an Integrated Collaboration Environment (ICE) can be the integration platform to support various digital oilfield and performance improvement initiatives. Initially, some companies took a "Field of Dreams" approach, expecting that once video-conferencing and visualization workspaces are built, their professional staff "will come." Increasingly, even these companies now recognize that successful projects must develop a plan to integrate people, process, technology, and facilities to enable new ways of working.
This paper proposes a framework to realistically diagnose performance requirements against a company's digital oilfield or integrated operations strategy, and to chart an ICE development path to match. In addition, we share some lessons learned from recent ICE implementations projects for drilling, production operations, and/or optimization. Whether for new or legacy assets, we are learning that success depends on (a) engaging objective, third-party consultation to help the management team articulate a shared vision for collaboration, integration, and real-time support; (b) investing time and resources in a participatory conceptual design phase that focuses on the user experience; and (c) a design/implementation methodology that addresses all the dimensions of change—process, organization, people, technology, and facilities, inclusive of a professional project management with experience leading joint internal/external teams to deliver complex system integration projects.
By clarifying the performance vision framework and applying some of the lessons learned from early adopters, we see that a well-designed and professionally implemented ICE can resolve inefficiencies, "handoff" disconnects, and communications gaps between the field and the office. Better yet, the ICE will generate a step-change improvement in "real-time" surveillance, interpretation, decision-making, and quality execution, embedding it as the new and "natural" way of working.
Human Factor Principles in Remote Operation Centers
Authors: Brannigan James , Veeningen Daan , Williamson Mark , Gang Zhao 
Published: February 2008

Abstract
The uptake of operation support centers for monitoring and remotely controlling wellsite operations in real time is accelerating in the industry. This paper identifies and discusses the human factors involved with the successful design and operation of these centers.
The introduction of remote operation centers is having a significant impact on the physical and cognitive abilities of engineers working within the centers. Human Factors is a discipline that focuses on how people interact with tasks, machines, and the environment with the consideration that humans have limitations and capabilities. Human Factors must be considered in the planning, design and operation of any remote operation center to ensure productive and safe operation of the center. Locating operators remote from the tasks they are controlling or monitoring will affect not only the direct control and decision making processes, but will also affect their cognitive abilities and ongoing knowledge management and training.
In order to maximize the productivity of any system it is essential to design the workflow to take account of the new operational methods rather than trying to duplicate the existing workflows in a remote environment.
Intelligent Wells to Intelligent Fields: Remotely Operated Smart Well Completions in Haradh-III
Authors: Al-Arnaout Ibrahim H. , Al-Driweesh Saad M. , Al-Zahrani Rashad M. , Rahman Zuhed Abdul , Jacob Suresh 
Published: February 2008

Abstract
Haradh-III, Saudi Aramco's latest developed field within Giant Ghawar Field, is regarded as one of the industry firsts in terms of its application of advanced drilling techniques, multilateral wells, smart well completions and permanent monitoring systems. This recently commissioned field, on February 2006, integrated all of the above mentioned technologies with an advanced SCADA system that enable the real time monitoring and control of the downhole and surface equipment remotely from the control room.
The design and installation of the automated surface control system to remotely monitor and control the smart completions is a multidisciplinary project integrating subject experts and tools from well completions, production engineering, facilities, instrumentation, and communication engineers. The system enables the operator in the control room to remotely operate the downhole valves in all the multilateral smart wells through the SCADA system.
The paper will present the design, installation and commissioning of the surface control system and remote monitoring capabilities and cite a field case of remote operation to flow test a well with three zones smart well completion, permanent downhole gauge and surface multiphase flow meter. The system has enabled the operator to remotely perform flow testing of the individual laterals of the multilateral wells through different settings of the downhole valves. The remote control capabilities enabled these tests to be done from the control room without the engineer spending extended periods in the well site.
The learning discussed in this paper will provide an insight into how the implementation of such control system was systematically handled to achieve a successful conclusion.
Integrated Operations–A Key Enabler to Operational Excellence in Maintenance Management of FPSO’s
Authors: Stenvaag Sverre , Lindrupsen Terje , Bye Roar , Østerås Trond 
Published: February 2008

Abstract
Teekay Petrojarl Production (TKP), the largest operator of Floating Production, Storage and Offtake (FPSO) vessels in the North Sea, has an ambition to retain its leading position as FPSO contractor in harsh environments while also expanding its business into benign waters worldwide. One of the important measures to attain this is by establishing and implementing best practice within E&P operations business worldwide. Several projects have been started to support TKP's effort to reach operational excellence. This paper is concerned with one of the projects, "Integrated Operations – A Key Enabler to Operational Excellence in maintenance Management of FPSOs". The main objective of this project is to enable TKP to take a step further into operational excellence by implementing more effective work processes, and developing new theory, methods and tools for maintenance optimization. TKP regards Integrated Operations (IO) as an important instrument to reach this objective. The research project focuses on three activities; 1) Describe and analyse future work processes for strategic and tactical analyses, 2) develop tools and methods to support strategic and tactical maintenance decisions, and 3) implement and verify work processes, tools and methods. Cases are used to develop, test and verify work processes, tools and methods prior to implementation, and have proven essential to create consensus. Recent experience shows that challenges with IO are more related to organisation and competence than technology itself. The Man, Technology and Organisation (MTO) focus is chosen when developing new work processes to meet the challenges related to competence and organisation. Close cooperation with onshore and offshore staff is critical when developing the new work processes. The main challenge for the development of tools and methods is related to balancing simplicity and theoretical basis. It is seen that many of the new tools and methods may be feasible just because the IO setting enables the use of onshore centralised expertise. The project has clearly seen that a successful implementation of IO, to reach operational excellence in maintenance management, requires full attention to balancing personnel competence, technology complexity and organisation (MTO), and ensuring management ownership (visions, maintenance strategy, measurable goals).
Remote Intelligence—The Future of Drilling is here
Authors: Gorgone Ignacio , Gomez Juan , Uddenberg Gary 
Published: February 2008

Abstract
It is well recognized that oil and gas companies have increased the implementation of collaborative centers to improve real-time decision making. This reduces nonproductive time (NPT) and improves efficiency in oilfield operations. Emerging technologies now enable end users to receive and send intelligent commands while tools operate under downhole conditions. This not only provides the advantage of fewer trips in and out of the hole, but also the ability to control operations from an office-based environment.
In the last few years, Schlumberger has increased the number of collaborative centers, known as Operation Support Centers (OSC™), to work closely with operators throughout the world. Surface and downhole data are currently transmitted to these centers in real-time as part of the execution phase in the drilling optimization process. While the focus of this paper is on drilling, real-time data is clearly not limited to the drilling phase and in many cases has been used for completion monitoring and control.
As the implementation of these centers has continued, drilling activity increased more quickly than experts could be developed in all areas of operation and support, despite aggressive recruiting and intense training and development. As a result, experts gathering in one room to advise jointly on several simultaneous rig operations became the norm and operators who experienced it quickly embraced the OSC™ concept.
Real-time centers, therefore, have become the chief venue for collaboration, data capture, sharing and training, in a way that better meets the needs of fast-growing operations. Interestingly, they have also become a focal point for better coordination of operational changes, as improved communication with tools downhole and with service personnel have facilitated reduced crew and support requirements.
This paper describes the challenges faced in implementing remote drilling operations, the work processes that allow one directional driller (DD) and one measurement while drilling (MWD) engineer to oversee several rigs simultaneously, and details the necessary infrastructure, communication systems and operating results.
Gas Coning Control for Smart Wells Using a Dynamic Coupled Well-Reservoir Simulator
Authors: Leemhuis A. P. , Nennie E. D. , Belfroid S. P. C. , Alberts G. J. N. , Peters E. , Joosten G. J.P. 
Published: February 2008

Abstract
A strong increase in gas inflow due to gas coning and the resulting bean-back because of Gas to Oil Ratio (GOR) constraints can severely limit oil production and reservoir drive energy. In this paper we will use a coupled reservoir-well model to demonstrate that oil production can be increased by using controlled inflow from a gas cone as a natural lift. This model was developed in the knowledge centre Integrated System Approach Petroleum Production (ISAPP) of TNO, TU Delft and Shell, and is based on a commercially available dynamic multiphase well simulation tool (OLGA) and a dynamic multi-phase reservoir simulator (MoReS).
In order to give a proof of principle we have implemented a PID feedback controller, which controls the gas fraction in a well by changing its wellhead choke or inflow control valve (ICV) settings, on a realistic test case. We introduce a strategy to find an optimal production set point for this controller and the benefits of using downhole ICVs in comparison to the wellhead choke are investigated.
Simulation experiments show that a PID controller is an effective means to prevent a full gas breakthrough and, moreover, can be used to increase the produced oil rate by tuning ICV settings to achieve an optimal well gas fraction. Results show that the coupled simulations could be significantly more accurate in comparison to stand-alone well or reservoir simulations.
In current operations ICVs are mostly used to completely shut down well segments that experience gas coning. We show that by keeping these ICVs open in a controlled way the - otherwise undesirable - phenomenon of gas coning can be used to increase oil production.
Short-Term Production Optimization by Automated Adaptive Modeling and Control
Authors: Awasthi Ankur , Sankaran Sathish , Nikolaou Michael , Saputelli Luigi , Mijares Gerardo 
Published: February 2008

Abstract
Short-term production optimization relying on model-based predictions over a short period (weeks to months) requires the use a near-borehole reservoir model. Such a model is usually developed and validated through standard well testing. Standard well testing has to be repeated periodically, with related loss of production. Production losses may be reduced by prolonging the interval between tests, but that may compromise the quality of information about reservoir properties, such as skin (or productivity index), which would ultimately compromise production as well. Therefore, a need exists for a methodology that maximizes both reservoir information and production simultaneously. Because these two tasks are inherently contradictory, a compromise has to be found. In this work we propose a methodology that combines well testing and production in an optimal way, resulting in overall production optimization. This methodology relies on a short-term moving-horizon optimization of an objective function that includes terms referring both to the quality of reservoir information and to production net present value. Reservoir information is captured by empirical (proxy) models that are built adaptively on-line as a result of optimal perturbations of production rates and recording of dynamic responses of related bottomhole pressures. Besides, the entire workflow can be automated. Simulations are presented that illustrate the mechanics and value of the proposed methodology.
From Intelligent Injectors to Smart Flood Management: Realizing the Value of Intelligent Completion Technology in the Moderate Production Rate Industry Segment
Authors: MacPhail Warren F. , Konopczynski Michael 
Published: February 2008

Abstract
This paper is a case history which examines the successful application of Intelligent Completion (IC) technology in a cost sensitive, mature, onshore North American environment where an existing hydrocarbon miscible flood (HCMF) horizontal injection well was retrofitted to manage the injection support of two geologically distinct reservoir regions covering two well patterns. The value of IC technology is explored in this early deployment which saw a relatively low cost application targeted towards a mature asset. The beneficial results of this application of IC technology were measured in terms of well intervention cost savings and affected oil production. This paper presents a relative comparison of those benefits. Though this application of IC technology was originally justified by the avoidance of certain future well interventions to modify the injection profile, an analysis of the affected pattern production in the post-installation period showed that the benefit to the operator was appreciably more from enhanced reservoir management than from the cost savings which were associated with workover avoidance.
Based on the success described in this case history, and reflecting upon the trends of intelligent well and smart field technology, the authors explore reasons for its relatively slow uptake in moderate production rate, brownfield applications. Large scale reservoir management of miscible flood projects using intelligent well and smart field technologies should provide significant value in terms of improved solvent/oil ratio through more efficient monitoring and management of the flood. This is probably the most compelling value proposition for IC technology application in moderate production rate land applications. This case history is intended to provide credible evidence of the benefit of IC technology in an application with cost challenges analogous to those faced by operators who are responsible for cost sensitive, moderate production assets. Secondly, it is intended to encourage the IC technology providers to develop more solutions for the brownfield segment of the industry, where profitability and value definition can be challenging.
Enhanced Awareness for Offshore Teleoperation
Authors: Skourup C. , Pretlove J. , Stembridge N. , Svenes M. 
Published: February 2008

Abstract
The major challenges for future oil & gas installations are to create and increase business value in addition to improve HSE (Health, Safety and the Environment). The Oil & Gas industry has recognised the potential of operating with ‘normally unmanned areas' where access to the entire process is based on utilisation of new technologies from remote onshore locations. During maintenance, personnel have only got restricted access when the process is shut-down, but this is primarily handled remotely. This paper concerns teleoperation and telepresence of oil & gas installations. The challenges involve more than the technology of transferring data and performing operations. A teleoperator or a telerobot is a "machine" which extends a human operator's sensing and manipulation capability to a remote environment. An essential issue of telepresence is to keep the human operators in the control loop to enable them to use their high levels of skill to complement the power of remote manipulators. Teleoperation within oil & gas differs from other known applications as offshore installations represent large, complex and dynamic processes located hundreds of miles away in very harsh environments where failures may result in major consequences for the environment and process equipment.
The challenges of offshore teleoperation are to enhance the operator's perception of the current situation so that the operator has a complete understanding of state of the process and operates the process as if he was offshore without hundreds of miles and complex technology in between. Safe and efficient teleoperation is critical for operation of unmanned platforms to secure added value and optimal production within a distant environment.
Successful Interaction Between People, Technology and Organisation—A Prerequisite for Harvesting the Full Potentials From Integrated Operations
Authors: Roland Steinar , Yttredal Olav , Moldskred Ivan O. 
Published: February 2008

Abstract
The full value potential of implementing Integrated Operations on the NCS is estimated to $42 billion. In order to harvest this full potential we argue that a balanced integration of people, technology and organization (PTO) is necessary. Our focus is on the people and organisation aspects; what characterizes teamwork and collaboration in the new IO arenas; and, composition of teams and team performance.
IO represents a set of new work forms, and we argue that collaboration and team work are fundamental aspects in this new reality. Hence, we have used Dr. M. Belbin and his theories on roles and team composition to show how to design and develop good teams.
Our observations and findings indicates that it is important with continuously focus on the people and organizational aspects in order to harvest the full potentials from Integrated Operations. However, this focus must be balanced with technology in order achieve the most optimal work processes, which will give all parties safer and better decisions faster, and contribute to added value.
Industrial Wireless Technology for Oil Fields Connectivity "Wireless I-Field"
Authors: Al-Walaie Soliman A. , Almadi Soliman M. , Al-Shammari Saud F. 
Published: February 2008

Abstract
Wireless Technology is a potential cost-effective and efficient connectivity solution for several oil and gas explorations and producing applications. Remote oil wells, water injection plants, pump stations, pipelines operations can benefit from the first mile wireless access to connect to the corporate Process Automation Network (PAN). This would result in improving productivity, providing faster and more accurate data collection and reducing capital and operating expenditures.
In this paper, authors will provide an overview of industrial wireless technology for Oil Field Connectivity as well as the discussing key requirements and challenges for reliable and secure industrial wireless solution. Furthermore, emphasis will be on the use of industrial Fixed Broadband Wireless (BFW) for first mile field access. The successful field trial implementation of industrial BFW solution for microseismic field connectivity will be presented in this paper.
Efficient Well Placement Optimization with Gradient-based Algorithms and Adjoint Models
Authors: Sarma Pallav , Chen Wen H. 
Published: February 2008

Abstract
A key reservoir management decision taken throughout the life of a reservoir is the determination of optimal well locations that maximizes asset value (such as Net Present Value, NPV). Because this well placement optimization problem is a discrete-parameter problem (well locations are discrete parameters in the simulation model), gradients of the objective function (NPV) with respect to these parameters are not defined. Thus, gradient-based methods have not found much applicability to this problem, and most existing algorithms applied to this problem are stochastic in nature, such as genetic algorithms, simulated annealing, and stochastic perturbation methods. These methods are usually quite inefficient requiring hundreds of simulations and thus may have limited application to large-scale simulation models with many wells.
We propose a novel, continuous approximation to the original discrete-parameter well placement problem such that gradients can be calculated on the approximate problem, and gradient-based algorithms can then be employed for efficiently determining the optimal well locations. The basic idea is to first replace the discrete parameters (i, j well location indices) with their continuous counterparts in the spatial domain (x, y well locations) and then obtain a continuous functional relationship between the objective function and these continuous parameters. Such a functional relationship is obtained by replacing the discontinuous Dirac-delta functions (defining wells as point sources) in the underlying governing PDE with continuous functions (which in the limit tends to the Dirac-delta function, such as the bivariate Gaussian function). Numerical discretization of the modified PDE leads to well terms in the mass balance equations that are continuous functions of the continuous well location variables. As a result of this continuous functional relationship, adjoints and gradient-based optimizations algorithms can now be applied to obtain the optimal well locations. The efficiency and practical applicability of the approach is demonstrated on a few synthetic waterflood optimization problems.