bluuebunny/crossref_metadata_2025_split huggingface dataset:
Digital Platform for the Next Generation IO: A Prerequisite for the High North
Authors: Verhelst F. , Myren F. , Rylandsholm P. , Svensson I. , Waaler A. , Skramstad T. , Ornæs J. I. , Tvedt B. H. , Høydal J. 
Published: July 2010

Abstract
The Arctic region holds vast amounts of extractive energy resources. Most of the arctic resources lie offshore beneath thick ice and deep water in environmentally very sensitive areas. Weather and distance from existing infrastructure and centers of population add additional operational and logistic challenges.
Oil and gas operations in the high north are likely to entail the remote and distributed control of assets – leading to heavy demands on the communication links and information flow. Connecting and integrating business processes and information sources across disciplines, geographical locations and organizational boundaries add to the complexity. Further, operations in the high north require particular sensitivity to environmental aspects.
In order to meet all the requirements and at the same time maintain profitable operations, the industry has to create new field development and operation concepts that include heavily instrumented facilities. There must also be put a significant focus on the transfer of real time data between fields and operation centers located elsewhere, and on automated key work processes to handle the large volumes of data. A prerequisite for this development is a robust digital infrastructure and a platform for effective and efficient information exchange. This is what the Norwegian Oil Industry Association has called Integrated Operations Generation 2. Central to this vision is a much higher degree of functionalities being distributed geographically and organizationally based upon a digital platform that is distributed to a higher extent than what is common today. The platform defines interfaces and employs data transfer and distributed intelligence based on open standards, allowing for a much higher degree of interoperability across applications, disciplines, geographic locations and organizations than is common today.
The main aim for the "Integrated Operations in the High North" project is to build and demonstrate a digital platform for Integrated Operations Generation 2. The project is a unique collaboration between the ICT, defense and oil and gas industries, as well as university research groups. During a four year period starting May 2008, the 26 participants in the project are working together to develop a demonstrated platform for Integrated Operations Generation 2. Pilots defined for drilling, production and operations and maintenance, are used as a basis to generate the requirements early in the project, and at later stages in the project to demonstrate the value of the platform.
The project is also relevant for gaining experience with where and how cutting edge ICT technologies, like semantic and agent technologies that target the "Internet of things", may generate value within the oil & gas industry.
Bridging the Gap between Deploying Collaborative Applications and Generating Value
Authors: Burress Charlotte , Paylow Kevin 
Published: July 2010

Abstract
Increasing numbers of collaborative tools and environments are becoming commercially available, and many of these applications are used or have been tried within the oil industry. But simply having the tools doesn’t mean they provide value or are embraced by employees. The perceived need for change management or lack of resources dedicated to change management seems to be pervasive across the industry. So this leads to the question: "How can we bridge the gap between deploying IT applications and generating value to users and the organization?"
This case study looks at different low-cost approaches employed to prototype uses and builds user familiarity with several collaborative applications within our organization. These applications include webinars, wikis, collaborative discussions, amateur video and Microsoft SharePoint® software functions.
Some simple approaches to deploying these tools have driven greater uptake and collaboration in the organization. Others became viral messaging. Other methods just didn’t "stick" with users. While not all approaches have been successful, we view this as part of our innovation and learning process.
Collaboration is important to organizations and participants as it enables efficiency, effectiveness, knowledge transfer and innovation. The ability to bring people and information together from around the globe is increasingly critical as we watch resources diminish due to the economic climate, the demographics of the industry’s workforce change significantly and the technical and commercial challenges to find, drill, and produce hydrocarbons grow more complex. Collaboration between users doesn’t happen simply because tools are available. Organizations must find a way to make collaborative tools valuable, wanted and used.
Realizing Value from Implementing i-field™ in a Deepwater Greenfield, Offshore Nigeria
Authors: Sankaran Sathish , Olise Moses , Meinert David , Awasthi Ankur 
Published: July 2010

Abstract
Digital oil field (DOF) in the upstream industry has gained momentum in the last few years and has transformed from being solely a vision to actual projects that have measurable value. The ultimate goal in DOF projects is an integrated approach towards decision making and control of asset management in relevant time. This paper describes the successful methodology adopted for implementing i-field™ in Agbami—namely, identification, prioritization, and implementation of relevant workflows.
The Agbami field, located in deepwater offshore Nigeria, is a subsea development that incorporates crestal gas and peripheral water injection. It is located in ~1,500 m of water depth and consists of a 38 well-development program to be implemented in three phases. The well completion incorporates intelligent well completions (IWC)—downhole flow meters, pressure and temperature gauges, and interval control valves. These downhole accessories are managed using electric and hydraulic controls/instrumentation with subsurface, subsea, and topsides data acquired and transmitted to a central-data historian on the FPSO in relevant time. The implementation of a robust architecture for a data and information management system involving acquisition, processing, storage, and replication (from offshore to onshore) is conceived to be the foundation upon which asset management workflows are implemented.
The expected benefits from implementing i-field™ in Agbami include reduction in lost production opportunity (LPO) through proactive asset management, better long-term reservoir management through timeline management of injection and production-rate balancing, increased efficiency and reliability through guided workflows, improved ultimate recovery, and better overall performance from standardization of base business work processes. The real value of implementing i-field™ initiatives in Agbami is not only justified by the return on investment but also by providing a benchmark for capturing the value by other assets. Based on field experience, this paper discusses the approach towards value realization of the i-field™ system, including change-management strategy for end-user acceptance. Critical success factors and lessons learned during deployment are also presented.
The Future of Integrated Operations
Authors: Crompton Jim , Gilman Helen 
Published: July 2010

Abstract
The concept of Integrated Operations (IO) has matured significantly over the past eight years since the landmark study by CERA in 2002. Many companies, including Chevron, now have established programs with demonstrated results delivered in multiple assets. With that track record, companies are now asking what’s next and how can they build on this foundation for the future.
Given what we’ve learned to date, how can we accelerate results and where can IO add the most value? What business and technology trends will emerge both to help and hinder integrated workflow solutions over the next 5-10 years? This paper will address these questions by looking at the history of the Chevron i-field program to understand what has been accomplished, the promises realized and the challenges uncovered in the journey. We will examine trends in the industry, to understand future opportunities and challenges more clearly.
The paper will look at how different elements of Integrated Operations can be deployed more effectively, and how to address the challenges of delivering and sustaining the change within the current and future workforce. Delivering solutions is usually difficult, but sustaining and supporting them provide new levels of challenge. How do we ensure that Integrated Operations becomes the way we work in the future instead of a passing technology fashion fad?
Experimental and Numerical Modeling of Three-Phase Flow Under High-Pressure Air Injection (HPAI)
Authors: Niz-Velâsquez E. , Moore R. G. , van Fraassen K. C. , Mehta S. A. , Ursenbach M. G. 
Published: July 2010

Abstract
In this paper, an improved characterization of three-phase flow under HPAI conditions was achieved based on experimental results and numerical reservoir simulation.
A three-phase coreflood experiment was conducted at reservoir conditions, using 37°API stock tank oil, 84% nitrogen – 16% carbon dioxide flue gas mixture, and 3% KCl brine. The aim of the test was to evaluate the effects that the highly liquid-saturated front produced by the thermal reactions has on the mobility of each phase. Departing from connate water saturation and reservoir pressure and temperature, sequential injection of water, gas and oil was carried out, followed by a final gas flood to residual liquid saturation. Other two-and three-phase tests performed on this rock specimen were published elsewhere. Numerical history matching was employed to determine oil-water and liquid-gas relative permeability (kr) curves for both imbibition and drainage cases. A Combustion Tube (CT) test was simulated using both conventional kr curves and a set including hysteresis. The degree of hysteresis observed during the coreflood test was maintained for the CT simulation.
History matching of the coreflood showed that kr to the gas phase is much smaller during liquid re-imbibition than during drainage. The use of gas phase hysteresis for the CT test allows for a better matching of liquid volumes and pressure drop. Analysis of the simulated data suggests that the reduction in gas phase mobility encourages an early increase in the oil rate, which is more consistent with experimental data than that predicted by a model with conventional kr. It also reveals that water distilled below the saturated steam temperature plays an important role on the increase of liquid saturation and oil mobilization.
The improved characterization on relative permeability considering gas phase hysteresis for simulating HPAI enhances the predictive capability of the available commercial simulators, providing a more certain method to evaluate the technical and economical feasibility of a project. The ability to predict an early increase in oil rate, consistent with experimental observations, results in improved economics for the project.
Enabling an Intelligent Energy Strategy through Industrialization of IT
Authors: Hill Craig 
Published: July 2010

Abstract
In the industry today IT has become "business critical" in wellsite and field operations, moving beyond the traditional back office role. As a result, there are significant implications for the IT organization, where rig site and producing-asset interaction, both in terms of people and technology, has been infrequent, ad hoc or confined to the witnessing and delivery of data. It is now critical to align the strategies and plans of IT and Operations both at HQ and local level, to achieve the efficiency, performance, and technology objectives set. Key focus areas are
Staffing—Assign experienced staff to real-time–related IT management. Process—Define clear processes for all "touch points" between IT and Operations. Infrastructure—Design, build, and operate a highly resilient infrastructure from end to end. Service Quality—Benchmark, measure performance, and plan to continually improve.
This paper describes a "model real-time framework" and the standards defined for compliance by target geographical areas over a 12-month period. The aggressive targets were achieved through a high level of HQ support, key personnel moves, and monthly reviews tracking progress against action plans.
With the application of a well-structured program, support and confidence was gained across the company, united through the understanding of the clear business benefits brought about by advances in IT. Complacency in the existing level of infrastructure resiliency was apparent and compelling arguments to justify investment were required and provided.
Probabilistic Modeling for Decision Support in Integrated Operations
Authors: Giese Martin , Bratvold Reidar B. 
Published: July 2010

Abstract
We report work carried out within the CODIO project on COllaborative Decision support for Integrated Operations. As one part of this project, we have designed a system to provide assistance in operational decisions based on real-time sensor readings in a typical scenario: while drilling close to the transition to a high-pressure formation, a gas influx is observed. The drilling team needs to decide whether to circulate, increase the mud weight, plug back, set a casing, etc.
After a brief description of the technology we used to model decision problems (Bayesian Networks, Influence Diagrams), we describe our case study and go on to apply the method of decision analysis to it. We discuss how the resulting influence diagram was tested using a simulation, and discuss challenges in applying the technology, as well as lessons learnt underway. We also give a list of desiderata to establish better decision making practices in the petroleum industry.
Surface Facilities for a CO2-EOR Project in Abu Dhabi
Authors: Saadawi Hisham 
Published: July 2010

Abstract
The Government of the UAE aspires to reduce green gas emission by capturing carbon dioxide (CO2) from industrial emitters and transporting the CO2 to oilfields for Enhanced Oil Recovery (EOR).
In order to demonstrate and test this concept, Abu Dhabi Company for Onshore Oil Operations (ADCO) recently implemented a pilot-scale CO2 Enhanced Oil Recovery in one of its onshore oil fields. This is the first ever CO2-EOR flood to be implemented in the Middle East.
This paper gives the background to this unique project and describes the pilot facilities and project execution plan.
Combining Distributed Temperature Sensing with Inflow Control Devices – Provides Improved Injection Profile with Real-Time Measurement in Power Water Injector Wells
Authors: Hembling Drew , Berberian Garo , Watson Mark , Simonian Sam , Naldrett Garth 
Published: July 2010

Abstract
Passive ICDs (Inflow Control Devices) have been used in the past to enhance performance of producing horizontal wells in unfavorable environments such as non-uniform permeability and/or pressure variations along horizontal sections. This is the first ever attempt, to the best of our knowledge, at using ICDs combined with a fiber-optic DTS (Distributed Temperature Sensor) to manage the water injection profile across a horizontal reservoir horizon.
The cost of the permanent monitoring installation is comparable to a single coiled tubing deployed PLT intervention. This paper addresses how a passive ICD completion, utilizing DTS technology, was used to optimize and monitor well performance. In addition, the operational aspects of permanent vs. intervention monitoring are addressed while highlighting the opportunity for additional value creation using real-time monitoring combined with ICD technology.
This field trial demonstrates the effectiveness of the ICD system when used in an injection well for injection profiling and fluid diversion during acid stimulation. In addition, the DTS proved to be an effective alternative to production logging in this horizontal water injection well.
The key factor in the success of this project was the use of the 3-1/2" ICD completion along with a DTS system to monitor and passively control the injection sweep across the entire reservoir section. DTS data were also obtained during pre-injection and acid stimulation operations. This was the first occasion in which an operator was able to evaluate stimulation efficiency of an ICD completion using permanent real-time monitoring methods.
Coupled Reservoir Geomechanical Modeling of a Thermal Gas-Oil-Gravity-Drainage Project
Authors: Hussein Assef Mohamad , Minton James , Rawnsley Keith , Qiuguo Li , Zhang Xing , Koutsabeloulis Nick 
Published: July 2010

Abstract
Steam injection into a shallow fractured and faulted reservoir has the potential to change the stress profile of the subsurface in such a way as to induce microseismic events that could eventually reactivate faults and fractures, especially if steam injection temperature is significantly high and fracture spacing is small. A 3D mechanical earth model (MEM) of a thermal gas/oil gravity recovery process illustrates the potential for steam to facilitate drainage by reducing viscosity of the heated matrix oil, leading to compaction that might be offset by upward movement of the surface in response to high steam temperatures. In our extreme case, the upward movement at ground level could be as high as ∼26 cm over 35 years. High levels of vertical deformation are increasingly likely where faults extend to the surface. Understanding these processes is important to ensuring the safety of the facilities over extended production times in environments of this kind.
Perdido: The First Smart Field® in the Western Hemisphere
Authors: Perrons Robert K. 
Published: July 2010

Abstract
Located in the Gulf of Mexico in nearly 8,000 feet of water, the Perdido development is the world’s deepest spar and Shell’s first Smart Field®1 in the Western hemisphere. Jointly developed by Shell, BP, and Chevron, the spar and the subsea equipment connected to it will eventually capture approximately an order of magnitude more data than is collected from any other Shell-designed and managed development currently operating in the Gulf of Mexico. This paper will describe Shell’s Smart Fields design philosophy, briefly explain the five design elements that underpin "smartness" in Shell’s North and South American operations—specifically, remote assisted operations, exception-based surveillance, collaborative work environments, hydrocarbon development tools and workflows, and Smart Fields Foundation IT infrastructure—and shed light on the process by which a highly customized Smart Fields development and management plan was put together for Perdido.
Exception Based Surveillance
Authors: Yero Jorge , Moroney Thomas A. 
Published: July 2010

Abstract
With ever increasing amounts of data available to surveillance engineers Shell Exploration and Production in the Western hemisphere has used Lean concepts to eliminate waste in a surveillance engineers day, allowing them to concentrate on the highest value tasks and removing unnecessary analysis. This paper illustrates the design and use of the Exception Based Surveillance tool as well as the integration of the tool in a collaborative work environment. This overall process improvement to reservoir and facility surveillance has had a significant financial impact and has lead to efficiencies in procedures, engineering performance and production for the offshore and onshore assets in the Americas.
Intelligent Pipeline Design and Construction
Authors: Burke R. N. , Ody T. 
Published: July 2010

Abstract
The composite pipe system known as X200™ is a steel strip laminate technology which uses high-performance adhesives to manufacture a metallic composite pipe. It offers a new method of low-cost pipeline construction suitable for onshore gas and oil pipelines in a variety of configurations. The pipe is based on a thin wall liner that provides the fluid containment, the material of which will vary according to service requirements. The grade of steel, stainless steel, special alloy, or even reinforced thermoplastic can be user-defined to suit a given fluid application; the current design is based on 316L stainless steel.
Fusion bonded epoxy (FBE) coated ultra-high strength steel strips are pre-formed and helically wound around the liner to form a laminated high strength reinforcing layer providing the pipe’s hoop strength. These components are bonded together to form a rigid pipe, using an adhesive. The complete structure is then coated with one or more layers of a suitable pipeline external coating material, as required by conditions. The resulting pipe is considerably thinner and lighter than the equivalent rated conventional line pipe products because of the beneficial strength-to-weight ratio of the materials utilized.
Unlike conventional line pipe that is manufactured in a plate mill, and then transported from the mill to the construction site; X200 pipe can be produced at the job site using a portable manufacturing line – greatly reducing the logistics burden for projects and reducing the time to first hydrocarbon production. All units in the manufacturing process fit within standard ISO containers, each weighing between 5 and 20 tonnes. This allows for economic transportation and handling.
Benefits From Implementing an Integrated Asset Operations Modelling System
Authors: Amro A.A. Bin , Sakaria D. , Lestariono Y. , McAlonan N. , Shere A.J. 
Published: July 2010

Abstract
Abu Dhabi Company for Onshore Oil Operations (ADCO) chose the North East Bab (NEB) field complex and asset to pioneer intelligent field technologies and work-practices within the company from development, to production start-up in 2006 and in subsequent enhancement projects. This paper describes implementation and operational experience from the online production optimisation and monitoring software now used as part of the asset team’s work-flows.
Offline modelling of the NEB complex started in 2006 to demonstrate the feasibility of the concept. In what is now becoming standard practice, an offline integrated model of the reservoir performance, production, gas-lift, water and WAG injection wells and surface facilities was set up. Experience from using this model and workshop sessions with all disciplines within the NEB Asset team were then used to specify and commission a commercially available web-based system.
The online system is being used by the team to help optimise reservoir, well and plant performance. Common access to up-todate information throughout the organisation has encouraged faster decision making and prioritisation of measurements with resulting optimal improvement implementations in the field. The system monitors performance against reservoir management targets for production/injection and facilitates diagnosis of any deviations from plan by highlighting flow-assurance issues from the reservoir to well to process plant to export pump. The methodology used is transparent to any user and so confidence can be established in the continuously updated results for well and network flow assurance, reservoir pressure estimation and voidage monitoring. The increasing focus on information, rather than raw data, is improving operational efficiency and the team plan regular enhancement of the system features.
The paper illustrates, using field examples, the benefits being realised from the online performance monitoring and full loop optimisation of both production and injection wells.