bluuebunny/crossref_metadata_2025 huggingface dataset:
Decomposing the mid‐Holocene Tsuga decline in eastern North America
Authors: Booth Robert K. , Brewer Simon , Blaauw Maarten , Minckley Thomas A. , Jackson Stephen T.
Published: March 2012

The mid‐Holocene decline of Tsuga canadensis (hereafter Tsuga) populations across eastern North America is widely perceived as a synchronous event, driven by pests/pathogens, rapid climate change, or both. Pattern identification and causal attribution are hampered by low stratigraphic density of pollen‐sampling and radiometric dates at most sites, and by absence of highly resolved, paired pollen and paleoclimate records from single sediment cores, where chronological order of climatic and vegetational changes can be assessed. We present an intensely sampled (contiguous 1‐cm intervals) record of pollen and water table depth (inferred from testate amoebae) from a single core spanning the Tsuga decline at Irwin Smith Bog in Lower Michigan, with high‐precision chronology. We also present an intensively sampled pollen record from Tower Lake in Upper Michigan. Both sites show high‐magnitude fluctuations in Tsuga pollen percentages during the pre‐decline maximum. The terminal decline is dated at both sites ca. 5000 cal yr BP, some 400 years later than estimates from other sites and data compilations. The terminal Tsuga decline was evidently heterochronous across its range. A transient decline ca. 5350 cal yr BP at both sites may correspond to the terminal decline at other sites in eastern North America. At Irwin Smith Bog, the terminal Tsuga decline preceded an abrupt and persistent decline in water table depths by ∼200 years, suggesting the decline was not directly driven by abrupt climate change. The Tsuga decline may best be viewed as comprising at least three phases: a long‐duration pre‐decline maximum with high‐magnitude and high‐frequency fluctuations, followed by a terminal decline at individual sites, followed in turn by two millennia of persistently low Tsuga populations. These phases may not be causally linked, and may represent dynamics taking place at multiple temporal and spatial scales. Further progress toward understanding the phenomenon requires an expanded network of high‐resolution pollen and paleoclimate chronologies.
Fooled by local robustness: an applied ecology perspective
Authors: Sniedovich Moshe
Published: March 2012

In this short discussion, we point out that it is apparently as easy to be fooled by robustness as it is to be fooled by randomness. Our objective is to bring to the attention of applied ecologists that radius‐of‐stability robustness models are models of local robustness. As such, these models are utterly unsuitable for the treatment/management of a severe uncertainty characterized by a vast uncertainty space and a likelihood‐free quantification of the uncertainty. This observation is particularly pertinent to applications of info‐gap decision theory in ecology, conservation biology, and environmental management, where the objective is to identify decisions that are robust against a severe uncertainty of this type.
Are We Poor at Explaining Things?
Authors: Karl Jeffery
Published: March 2012

5 men on an offshore rig.

They are making a decision about whether it is safe to remove drilling mud from a well.

They are discussing the results of a test.

The test results show that it might not be safe.

This means that when the drilling mud is removed, there could be enormous flows of oil and gas up to the platform, causing a big loss of live and massive uncontrollable pollution.

But one of the men says that the test results are showing what they do because of the ‘bladder effect’, and tries to explain it.

The other men do not understand.

What do the men do next?

Do the other men say, "We're not going to risk our lives, and let our children grow up without a father, and massive amounts of pollution, because of something we don't understand? We need to do more testing."

Or do they say "fine, we can remove the drilling mud".
Protection of Petroleum Industry from Hackers by Monitoring and Controlling SCADA System
Authors: Vijay Anne , Unni Vaisakh S
Published: March 2012

A control system refers to a computer based facility - system and equipment which is used to remotely monitor and control sensitive processes and physical functions. It collects and processes measured values and operational data in the field of facilities and conveys control commands to local or remote equipment. These control systems play the role of a central nervous system for energy-based facilities. If a control system were to undergo cyber attack from the outside, there could be negative consequences for public health and safety. These control systems have been regarded as safe from external threats of cyber attack up to now, but remote systems in the wrong hands could be utilized to cripple or shut down infrastructure systems through insertion of a virus or other malicious software which seriously damage other systems in the network, or associated networks in the industry (SQL injection attacks, DNS poisoning, Dos attacks). Data theft and hacking process control terminals that are left un-monitored are the major problems in oil and gas industry. Continuous monitoring regular scanning and updates of the software that are being used can leave us in safe zone. However, considering the cases of attacks recently reported abroad and the trend of openness and standardization of SCADA facilities, we cannot be sure about their safety from such cyber threats as hacking and cyber terror because of the potential threats posed by specific groups.

This paper explores the recent evolution of SCADA and its environment, it further explains the need for improved security in these systems, and describes some of the emerging research areas in SCADA security, especially for oil & gas industries, that offer promise for the future.
Distributed Acoustic Sensing - A New Way of Listening to Your Well/Reservoir
Authors: Johannessen Kjetil , Drakeley Brian , Farhadiroushan Mahmoud
Published: March 2012

There is a new generation of in-well monitoring technologies that are being characterized under the Acoustic Energy sensing banner. Some are essentially disturbance or vibration event monitoring techniques but this paper describes a Distributed Acoustic Sensing (DAS) technology [1]. The subject sensing system uniquely allows the user to listen to the acoustic field at every point along many kilometers of fiber optic cable deployed in the well. With a spatial resolution of 1 meter, for example, there will be 10,000 synchronized sensors along a 10,000 meter fiber. The system uses a novel digital optical detection technique to precisely capture the true full acoustic field (amplitude, frequency and phase over a wide dynamic range) at every point simultaneously. A number of signal processing techniques have been developed to process a large array of acoustic signals to quantify the coherent temporal and spatial characteristics of the acoustic waves. Potential in-well monitoring applications have been identified, and significant benefits are predicted for optimizing and maximizing production in many types of oil and gas fields by facilitating informed decisions.

The system can be retrofitted to existing installations of permanent in-well fiber optics based monitoring systems with the addition of surface instrumentation. New installations are also planned.

The paper also describes the background technology with focus on full reconstruction of the acoustic signal along the well bore, sensing system capabilities and the results of field trial surveys, with first generation instrumentation in seven offshore Norwegian Continental Shelf wells. These seven offshore wells already contained in-well fiber optics sensing systems, and comprised of two water injectors, one gas injector, three producers with gas lift valves, and one high rate Gas Oil Ratio producer. Installed sensing included Bragg grating based Pressure and Temperature gauges and fiber based flow meters. DAS measurements were recorded on fibers with both types of sensors installed on the same fibers. An acoustic signal for flowing wells was obtained in all cases and for most of the wells it was possible to also extract qualitative information on the flow regime, speed of sound and an estimate for flow velocity in at least parts of the wells.
Digital Oil Field Implementation in High-Pressure, High-Temperature Sour Environments: Kuwait Oil Company Challenges and Guidelines
Authors: Dashti Q. , Al Jasmi A. , Al Qaoud B. , Ali Zaki , Bonilla J. C.
Published: March 2012

In 2009, Kuwait Oil Company (KOC) launched the Kuwait Integrated Digital Field Jurassic (KwIDF-Jurassic) Project as a cross-domain solution consisting of a fully integrated infrastructure supporting field instrumentation, automated workflows, and ergonomic collaboration. The Jurassic gas field is a challenging environment consisting of heterogeneous carbonate reservoirs with natural fractures that can contribute significantly to productivity. Parts of the Jurassic reservoir consist of a tight matrix with a high density of connected fractures, but in other areas fractures are sparse and have limited connectivity. The high-pressure, high-temperature (HPHT) environment, the near-critical nature of the reservoir fluids, and the presence of H2S and CO2 are additional challenges for the development of the Jurassic complex.

This project is the first in Kuwait to instrument gas wells with pressure and temperature gauges; H2S, gas, and corrosion sensors, and safety and control devices as a first step toward delivering on KOC's vision for integrated operations. The application of intelligent automation at the wellhead and advanced instrumentation minimizes the health, safety, and environmental (HSE) exposure of field personnel. Interventions at the wellsite can be supported by handheld portable devices embedded with work orders. New digital field work processes, supported by collaboration rooms, enable proactive, real-time decisions in accordance to the exploitation strategy defined for the field. One outcome is to use technology to leverage the competence of disciplines, such as the subsurface team, to contribute in real time to production operations as opposed to the traditional nonoperational role of studies and reviews.

This paper presents a case study demonstrating the methodology and tools KOC has used to achieve timely and reliable data delivery for the Jurassic asset as part of the KwIDF-Jurassic Project.
The Missing Pieces of the Intelligent Energy Puzzle – The People Effect
Authors: Dickson Mark
Published: March 2012

The value of "intelligent" (i.e., digital, automated) energy solutions is now undisputed. Across the industry, these solutions are known by different names, such as: I-Field, Digital Oilfield, Asset of the Future, Field of the Future, Integrated Operations, and Integrated Oilfield Solutions. But regardless of what name is used, the expectation remains the same: technical staff are now expected to work in new ways––with new or automated processes, with new people, with new technologies, in new office operational facilities, and with new responsibilities––and meet expectations of new levels of performance and effectiveness in their jobs.

However, in the author's experience, there is widespread uncertainty among staff using the new technology. Specifically, there is confusion about job roles and responsibilities in the constantly changing technical work environment. While uncertainty eats away at staff morale, confusion poses a larger risk of failure, both at an individual and project level. Moreover, the success of hard-won Integrated Oilfield Solution project mandates comes under jeopardy––but this can be rectified if due care and attention is given to all stakeholders and end users who have an influence on the acceptance and use of the technology.

This paper examines some of the most recent cases of Integrated Oilfield technology implementations, either individual projects or technology campaigns in terms of "the people aspects". The author proposes as a hypothesis, a model for Change Management and tests its completeness and exhaustiveness against these technology implementation cases.

The paper concludes that if an all-inclusive Change Management Framework is adopted and therefore those issues relating to the engagement of people are addressed as a concerted effort at the beginning of an Integrated Oilfield Project, and these efforts are continued throughout the life of the project and into post implementation support, that projects will have a greater chance of success and sustainability.
A Measure of The Digital Oil Field Status – Is It The End of The Beginning?
Authors: Cramer R. , Göbel D. , Mueller K. , Tulalian R.
Published: March 2012

The so-called Digital Oil Field (DOF) is a somewhat ill-defined, misunderstood and abstract concept. The associated functional content, scope of work and terminology is variable from company to company and vague within companies. Consequently it is unclear how to gauge DOF degree of success, business benefit and effective organizational penetration. It is also sometimes unclear what the ultimate goals and associated road-maps are. With clear objectives, clarity of purpose and sufficient business justification there is a reasonable chance of meeting these goals, without clarity all is shrouded in mystique and uncertainty.

Hence the purposes of this paper are to:

Define precisely what is meant by the DOF; Describe the current operational status quo and compare and contrast with the ideal DOF; Define metrics that can be used to gauge the success of DOF initiatives.

This will be achieved by illustrating what the DOF is, and what it is not, in terms of oil and gas field infrastructure, applications and experiences. Application of the metrics defined will allow users to determine whether it is "the beginning of the end, or the end of the beginning for their DOF."
Establishing a Digital Oil Field Data Architecture Suitable for Current and Foreseeable Business Requirements
Authors: Cramer R. , Krebbers J. , van Oort Eric , Lanson Tony , Palermo Bob , Murthy Ajith , Duncan Peter , Sowell Tim
Published: March 2012

The Digital Oil Field (DOF) real time data structure as applied to drilling, reservoirs, wells surface production facilities, pipelines and downstream systems has evolved as bit of a muddle with little overall design and structure and little thought given to the underlying data foundational requirements. This has lead to disintegrated systems and inefficiency in attempts to integrate the multi-various systems and components.

Current real time data standards are based on a combination of downstream and upstream proprietary vendor standards that are growing more and more higgledy-piggeldy as more systems are deployed. Aggravating the problem is the ever growing volumes of data which needs to be transformed into useful information to facilitate better and more timely decision-making.

Hence the purpose of this paper is fourfold to:

– Define the problem in terms of the current over-abundance of data systems and standards; – Document current and foreseeable data business requirements; – Define the required integrated data foundation capable of handling the ever growing data volumes and providing appropriate, timely and accurate information to those that need to know; – Identify the business value that can be attained with this more structured and standardized approach.

The ultimate aim is to provide a solid foundation upon which the Digital Oil/Gas field can grow and flourish and a corresponding business justification.
The Psychology of Adopting Intelligent Energy: Lessons and Insights from Unexpected Places
Authors: Davidson John W. , Lochmann Mark J.
Published: March 2012

Intelligent Energy (IE) is a broad initiative to improve asset performance and boost corporate value. IE includes the following major concepts, all of which require new work processes, workforce adoption, and, ultimately, changes in behavior:

Fully-integrated operations Task and process automation Digitally-enabled technology Increased recovery Improved HSE Innovative and efficient methods to maximize production

The concept of Intelligent Energy was formally introduced to the oil and gas industry in 2003 with the release of Cambridge Energy Research Associates' multi-client study on the digital oilfield. Although the technology exists for this initiative to succeed, the industry has not seen the expected level of uptake or success. This lack of implantation is attributed in part to organizational transformation, which must accompany the adoption of these new work processes if the IE initiative is to succeed. Transformation includes convincing employees to embrace new ways of working, commiting themselves to learning, and ideally to mastering the application of the new operating principles. Unfortunately, corporate objectives and individual motivators are often misaligned, causing delays and resistance to the changes necessary for widespread adoption.

Lessons and insights extracted from seemingly unrelated disciplines can be applied to the oil and gas industry to great advantage. For example, several concepts from the field of psychology, dealing with organization and human behavior, may prove to be beneficial to the adoption of Intelligent-Energy initiatives and the transformation of production operations. These concepts include Maslow's Hierarchy of Needs, the "10,000-Hour Rule," and "The Magical Number Seven" (also known as Miller's Law).
Testing Methodology for Smart Wells Completion toward Attaining Optimal Production Rate Setting for Maximum Hydrocarbon Recovery
Authors: Alsyed Samih , Yateem Karam
Published: March 2012

Every oil company strives to produce its fields smartly, effectively and efficiently to ensure maximum recovery and minimize any unrecovered reserves. Being the largest integrated oil company with the most reserves, Saudi Aramco is in the forefront of such efforts by utilizing real time data and controls, also referred in our industry as smart or intelligent wells and controls. Some of these efforts are evident from the recent development of Haradh III increment (2006); part of Ghawar field, which is considered to be the world's first fully intelligent field1. Even prior to that, individual intelligent field ventures started in many fields and Safaniya, the world's largest offshore oil field, is not new to that. Safaniya holds a wide range of intelligent field equipment and is expected to be fully automated in the near future. Completing wells with smart completion jewelry is one such effort. With an increasing number of smart well completions in Safaniya, the need is to ensure the maximum benefit is gained from them and the completion design is optimized early on.

This paper is an effort to detail the procedure adopted to conduct the first test on smart well completions in one of Saudi Arabia's offshore fields. The paper details the processes and practices of testing smart well completions for inflow performance and capacity of all laterals and the operation of the downhole valves. To evaluate the completion practices in horizontal multilateral wells followed by simulation runs with various completion configurations, the test was run for two different wells with two different completion configurations. This practice helped optimize design completion (tubing size, number of multilaterals) of dual lateral wells with inflow control valves (ICVs) to maximize production.
Collaboration as a Cornerstone of Intelligent Energy: How Collaboration is Fundamental to Accelerate and Support IE Success
Authors: Gilman Helen , Kuhn Michael
Published: March 2012

This paper explains why collaboration is a cornerstone of so many successful Intelligent Energy (IE) programs, and how organisations can use what has been learnt about collaboration to support their IE activities, whether they have a mature program or are just starting on their journey.

The paper will look at evidence for the importance of collaboration and why it is so frequently seen as a key element of transformational IE programs. The results from 24 IE assessments across different companies and assets point to collaboration as the most commonly-recommended opportunity area for inclusion within IE initiatives. We will review the current state of collaboration to identify value that has been delivered, and common principles and lessons that can be extracted from multiple implementations.

We will then consider future directions for collaboration. A Collaboration Maturity Model and Roadmap will be introduced to explain the current state and potential future developments of collaboration across the industry. Although there has been much success delivered from collaboration to date, we believe that there is significantly more that could be achieved through further technical, visualisation, process and organisational innovation. The model will be used to help illustrate and explain potential future developments, and consider how organisations at all stages of maturity can increase the effectiveness of their collaboration activities.

Collaboration has been one of the key successes of Intelligent Energy; however, as an industry we are still in the early stages on the journey of where collaboration and IE could take us. This paper charts our progress on that journey and sets out how we can use today's knowledge to accelerate and direct further developments to transform our business in the future.
Real World Remote Operations: A Spectrum
Authors: Brannigan James C. , Luppens J. C.
Published: March 2012

Starting in 2004, a major service company began investigations into moving tasks normally performed on the rig to an office environment (an operations support center1). These "remote operations" have evolved into a spectrum: from splitting the day and night shifts between the rig and the operations support center to complete remote decision making by the project management team for well construction.

Common factors were observed and documented in the process of implementing remote operations. This led to standards and processes to support broader adoption of remote operations when they are operationally warranted. Standards and processes have been developed for change management, communications, IT infrastructure, and other issues.

Case studies illustrate the spectrum of remote operations, including work from the North Sea and land operations in North America, Central America, and Russia. Two perspectives on remote operations are given. One is from the point of view of a drilling service company responsible for directional drilling and logging-while-drilling services. The second is from the perspective of a project management team contracted for the entire well construction process.
Intelligent Field Infrastructure Adoption: Approach and Best Practices
Authors: Almadi Soloman , AL-Dhubaib Tofig
Published: March 2012

The drive to implement the latest and optimal Intelligent Field Infrastructure (IFI) is a continuous aim for Oil & Gas operators. This requires the right balance between technology, business drivers, and evolving implementation requirements. A successful Intelligent Field implementation relies on a robust real time field to desktop data acquisition and delivery system designed with clearly defined data acquisition requirements. The data acquisition requirements definition should include data type, acquisition frequency, resolution, integrity, quality and reliability. The data acquisition and delivery system requires built in dynamics from design, technology selection, and deployment to operational maintainability. The challenge in achieving such an objective exuberates by the different variables that must be considered when addressing IFI integrated solution. The variables to be considered in the solution shall include network coverage, hardware selection, software solutions, and feature functionalities. The solution shall be able to integrate different technologies: surface and subsurface gauges and subsystems; forming data collection, for real-time reservoir management and production operation, such as temperature, pressure, flow characteristic, etc.

This paper presents Saudi Aramco's experience and methodology of developing IFI, field-to-desktop data acquisition and delivery infrastructure, for new fields. It highlights critical components for the IFI building blocks and the most optimal approach in addressing them. Reflection on previous case studies is used to illustrate concepts and to outline best practices and lesson learned.
Real-Time Drilling Engineering: Hydraulics and T&D Modeling for Predictive Interpretation While Drilling
Authors: Borjas Ricardo , Martinez Leopoldo , Perez Carlos , Rodriguez Reginaldo
Published: March 2012

In the early stages of real-time data transmission from the rigsite, real-time monitoring engineers focused on viewing data as it was presented on the rigsite. While this setup was ideal for service quality and event mitigation, it fell short of providing predictions of wellbore condition. As remote real-time monitoring matures in its use of "while drilling" data, remote engineers need to identify issues before they affect drilling operations and are evident to rigsite personnel.

Using a combination of data analysis, engineering models, algorithms for data reduction, historic behavior, and experience, a remote monitoring engineer is able to see the data in the context of the drilling environment and to identify developing incidents.

However, as data volume increases, remote engineers must focus their analysis on the tools by which they can have the biggest impact and effectiveness. Real-time hydraulics and torque and drag (T&D) analysis are such tools, and by using engineering models, engineers can judge the condition of a wellbore before it impacts operations.

Two examples show how effective monitoring of "while drilling" models of hydraulics and T&D identified events, allowing them to be prevented before they were evident on the rigsite and caused nonproductive time.
The Future of Surveillance
Authors: Lochmann Mark J.
Published: March 2012

Surveillance in one form or another has been around the oil and gas industry for many years. The scope was initially limited to a manual process using individual engineering and business applications to evaluate a limited number of wells based either on their value or their trouble status. At one time, a hardcopy report, monthly target, production number, downtime, and operating expenses were adequate for our needs. Data was gathered by hand and manually manipulated before presenting them to operations managers. If a problem was identified, engineers performed an analysis based on their experience and judgment using the tools at hand. Because resources were limited, only the most important wells, or those with serious problems, could be studied, and even this examination often lacked depth. Many opportunities for better performance and risk reduction were missed or bypassed (Nikolaou et al. 2006).

More recently, major improvements in surveillance, including more engineering and operations content, were introduced to oil and gas production. Mature fields, such as Elk Hills in California, have implemented sophisticated monitoring centers that feed data into real-time displays, enabling operations staff to see the status of key measurements. Green fields, such as Agbami (offshore Nigeria), have deployed many model-based, integrated workflows to automate and facilitate operational excellence (Sankaran et al. 2011).

The improvements have led to a new role and definition for surveillance. When most people speak of surveillance today, they no longer assume that it is a passive information delivery system. The addition of advanced analytics, expert systems, and process automation (all of which routinely leverage real-time information) have taken surveillance to a new level, combining business or operational intelligence with automated technical calculations. The result of these advances is a new generation of hybrid solutions incorporating elements of "data-driven" methods, including management by exception (MBE), business intelligence (BI), and situational awareness (SA) with "model-driven" techniques, such as model-based decision support (MBDS), advanced process control (APC), and consequential analysis (CA). State-of-the-art information technology tools are used to enable more efficient traditional processes, build single-purpose workflow applications, and deploy fully-automated intelligent systems using the latest automation, models, and control systems.

The goal of future surveillance systems should be to replace monitoring wells against a target with managing production assets against their potential in a safe, environmentally-responsible way.
Managing Fields Using Intelligent Surveillance, Production Optimisation and Collaboration
Authors: Van den Berg Frans G. , Mabian Andrew , Knoppe Ronald , Van Donkelaar Edwin , Terlaan Frans , Koldunov Valentin , Lameda Rufina
Published: March 2012

In Shell, asset professionals use advanced technologies and processes for field management and optimising production performance. Real time monitoring of wells and compressors has become the norm, delivering higher uptime and increased production. Asset teams use visual information on hundreds of wells and their facilities using a web-based portal. The wells and facilities with events or deviations, i.e. exceptions, are highlighted, enabling the staff to focus on fixing the critical wells and facilities. The information is brought together in Collaborative Work Environments with video connection to streamline the communication between field and office and speed up decision making.

Shell has implemented these capabilities in a number of assets around the world, for example in Oman, Russia, Brunei, UK and Gulf of Mexico. The people side is a large part of the attention, during the implementation and for sustainability of the solutions. Awareness sessions, training, local ownership, feedback sessions, coaching and regular reviews are part of the embedding activities.

The paper describes the capabilities and the benefits, and illustrates this with a field case from Salym in Russia. This includes the approach to change management and learning from both the project and the embedding phase. The benefits include HSE improvements (less travel exposure), increased production and reduced operating cost.
Transforming IT to Innovate and Support Real-Time Operations Globally
Authors: Patterson Joel , Lehnherr Sebastien , Mead Terry , Goy Kevin , Schmid Brad , Harris Robin
Published: March 2012

In 2009, Schlumberger implemented a technology-driven strategy to make real-time operations globally sustainable within 3 years. The 3-year plan included the alignment of opportunities for business segments with the drivers of client businesses, and the creation of robust information technology (IT) operations, scaled for global, 24/7 support of real-time programs.

Schlumberger's business strategy for real-time operations combines market insight with technology, and includes investments in initiatives for performance assurance, improved service quality, and delivery of certain value-added workflows. Organizational alignment and accountability for real-time operations within the business segments required clearly defined responsibilities for headquarters, support functions, and field operations teams.

Over the past 24 months, the company has implemented several key elements of the strategy on a global scale, including a real-time IT readiness program, wellsite connectivity, operation support center standardization, real-time data delivery platforms, proactive 24/7 monitoring, and a service management model. Integration of people, processes, and technology has been key. Driven by strong commitment from executive management, these initiatives have provided the robust foundation required to make the intelligent energy vision sustainable.
Evolution and Adoption of a Corporate Strategy For Digital Oil Field Products and Services Within a Service Company
Authors: Denney Tommy , Haapanen Brian
Published: March 2012

This paper will outline the corporate culture and environment that affected how a service company engaged the digital oil field (DOF) concept and continues to embrace it moving forward. We will discuss how the company continues to address the need for a digital energy/digital oil field initiative not only for its customers, but for its own use as well.

Discussion will cover topics from early individualized products to meet exploration and production (E&P) customers' needs through maturation of those products. We'll describe the bundling and eventual integration of those products into a system—integrated with human resources—to address the needs of a modern exploration, drilling, completion and production scenario.

The response to the myriad issues with hardware to produce data, software to manage data, and ultimately the workflow and culture around using information is an evolutionary process. Missteps and successes brought on by that evolution should be noted as lessons learned, which can be applied by others to move forward with their own DOF technology.
4 Years of Eye-to-Eye Connectivity – the Success of Azerbaijan's Advanced Collaboration
Authors: Ibrahim-zade Orhan , Moore-Cernoch Kerry , Overton David
Published: March 2012

Video conferencing (VC) for multiple site collaboration is one of the key drivers to improve cross-functional collaboration and ensure that geographically dispersed teams communicate effectively.

Over the last four years BP has deployed a system with close to 300 endpoints for video and application sharing across Azerbaijan, Georgia, Turkey and the UK. This system links eight offshore facilities, a major terminal, three offices in Baku, offices in the UK, and pump stations across Azerbaijan, Georgia and Turkey. This is the largest integrated collaboration deployment within BP.

One of the key success factors which has evolved over the deployment has been the transition from a dedicated petrotechnical user base to an integrated deployment across all elements of the business. Many users familiar with the PC based tools then become "power users" to support team members with the same tools in a room environment. Peer to peer, platform to platform use of the system offshore has developed into a useful knowledge sharing tool outside office hours.

This changes the perception about VC technology from highly sophisticated and technical concept to a commodity IT enabler.

We identify and discuss 10 major use case scenarios, each of them having a unique blend of technology and business process: Executive Meetings and Inter Office communications, Site to Site collaboration, Multi-site Mixed Audio/VC call, Multi-site VC conferencing with third-parties outside of BP network, Incident Management, Diagnostic Support, Staff Townhalls, Enhancing Interactions with employees, Turnaround, ACE to ACE and ACE to Advisor collaboration.

Lessons learned on delivering ease of use to the end user, and in moving from a petrotechnical tool to a cross business tool with horizontal and vertical business integration, will be discussed.

Some of the business value can not be quantified - e.g. improvement of daily/weekly planning process; helping deliver the nationalization plan; ability to rapidly diagnose an issue and get to the root cause; facilitating the development of an intrinsic knowledge base on 3rd party supplied equipment.

However, there are some real monetary benefits that we were able to capture during the last 4 years - e.g. 0.5-1.0% increase of operating efficiency; 15% acceleration in the execution of planned work by enabling the completion of 7 quarters work in 6 quarters; 10% increase in operational offshore bed utilization; preventing several days loss of production.
Implementing New Technology Securing Availability And Quality Real-time Drilling Data Onshore
Authors: Halland Thomas , Steinsbø Lie Stian , Hoff Lene , Solnørdal Dag
Published: March 2012

In 2009 Statoil rolled out a performance incentive business model ensuring high quality real-time drilling data deliverables [SPE 127799]. But how do you measure performance? And how do you create a system automatically monitoring quality all the way from the rig and into target systems onshore?

Talking to operators and service companies, Statoil concluded that our industry seemed to be at a starting point when it comes to deploying automated monitoring systems targeting both availability and data content.

A technology development project was established in parallel with the performance incentive business model [SPE 127799], with the following goals:

Ability to monitor real-time drilling data streams from Statoil's drilling operations into all target systems Automated alarms triggered by data content automatically notifying operators on e-mail/SMS Automatically monitoring service company performance, including KPI's

The idea was simple: Implement a proactive monitoring system tailor-made for the drilling domain which automatically alerts user whenever there are problems. Instead of having 15 resources on a continuous 24/7 rotation manually monitoring the data streams, the system shall automatically monitor and alert on SMS/E-mail whenever a problem needs attention.

We will present our initial thoughts, what we learned, and the final results:

Use cases for a real-time drilling data monitoring system Design, specification and algorithms Implementation and deployment Experiences and challenges along the way

We will present our observations and conclusions on developing this technology, the main conclusion being that a proactive alarm system has drastically improved the quality of real-time data deliverables to Statoil's drilling assets, and also reduced the number of people needed to maintain quality data streams.
Innovative Intelligent Technologies used for Production Optimization and Infrastructure Integrity Surveillance
Authors: Roberts Ian , Albert Alexander , El Hares Layla , Rossi Marcus
Published: March 2012

In the oil & gas industry sporadic studies are developed to analyse the flow conditions and operations procedures through the life of the field. The objective of those studies is to understand the environment, boundary conditions and properties changes along the fluid journey. For characterization of the production behavior, engineers use model-based multiphase flow simulation via various applications available on the market.

A constant understanding of the fluid flow conditions is valuable for the decision process on the execution of operational procedures. A robust flow assurance strategy is dependent on the level of awareness of the real production conditions prior to a fluid flow interruption event. Fiber optics distributed sensor system has been recently used mainly for integrity monitoring purposes; the proposed methodology unlocks the additional values for interfacing disciplines as flow assurance by the provided simultaneous distributed measurements of temperature, strain, and vibration.

The model-based multiphase flow simulations represent flowlines and production networks and as output of those simulations operating profiles are used to evaluate the risk of solids precipitation and deposition along the flow path. A regular update of simulation models by real-time data from field sensor results in a more reliable representation of the production system operating profile that can support the flow assurance strategy by the detection, monitoring, and location of events.

This paper proposes the use of real-time data acquisition from an optical-fiber distributed sensor for the assurance of fluid flow along the production system. It outlines a methodology to perform flow assurance automated surveillance based on multiphase flow simulation models constantly fed with real-time field measurements to estimate fluid flow conditions throughout the system to avoid potential problems, such as flow restrictions due to solids deposition.
Temperature Transient Analysis in a Horizontal, Multi-zone, Intelligent Well
Authors: Muradov K. M. , Davies D. R.
Published: March 2012

Intelligent, or I-wells, are a core element in the delivery of the "digital oil field". Numerous publications have described how their control and monitoring capabilities can lead to an increase in reserves. Such monitoring systems provide the data which, when analysed with the appropriate algorithms, is turned into real-time information; viz. the quantitative values of the multiphase flow rate distribution across the multiple completion intervals. This transformation of data into information is the first step in a real-time, selective, zonal production management methodology. A second use of this information is the updating of the reservoir model, providing improvements in the reservoir description, the production performance prediction and the reservoir depletion strategy.

Temperature data plays an important role in downhole monitoring. It may be the sole source of downhole data or it may complement downhole, pressure gauge data. However, temperature data analysis workflows are less well developed than their pressure equivalent. Further, the installation of distributed temperature sensors is not always possible across the lower completion of many multi-zone, I-wells.

To fill this gap we have set ourselves the target of developing transient temperature analysis techniques based on the use of data from discrete, relatively accurate, temperature gauges installed across each production zone. We recently reported our first step in this process, the mathematical basis for temperature transient analysis of a single zone. This paper extends our first step in the development of a comprehensive, temperature analysis workflow to the analysis of a horizontal, multi-zone, I-well.

The workflow necessary to calculate the sandface temperature for each zone in a multizone completion will be presented. The novel aspect of this new workflow is that allowance is made for the affect of fluid flowing from deeper zones. Its utility will be demonstrated using a real case history.
Automation of Safety Valve Travel Timing Delivers Business Value in the Caspian
Authors: Marinai Luca , Khetarpal Ajay , Grange Brett , Mackinnon George , Houghton Christopher
Published: March 2012

Over the last three years the BP AGT Region in the Caspian has deployed a new Field of the Future technology to automate the monitoring of safety critical valves' actuation time. This paper discusses the deployment of this tool, particularly focusing on the business value delivered and the lessons learnt. The Azerbaijan-Georgia-Turkey (AGT) Region is a BP organisational unit, operating a number of major upstream and midstream assets in Azerbaijan, Georgia, and Turkey, including six large integrated offshore platforms in the Caspian Sea, and three export pipelines.

Automating the monitoring of valves is not always included in the business case for intelligent oilfields, and the operations focus may be seen as less value-adding than some of the reservoir or well based applications, but the business value is clear. The operational prize is relatively easy to measure and capture when retrofitting to a brownfield site that has reached a steady state of performance. BP in Azerbaijan chose to initially deploy this technology about two years after startup, once the maintenance team's focus shifted away from post commissioning problems, and comparison to steady state operation was possible, and the application had reached maturity.

Detailed valve time tracking adds value by reducing the need to plan safety valve testing, if a plant shutdown occurs -planned or unplanned during the window within which procedures dictate a valve test must be conducted. In addition, the application provides performance tracking over time that might not be available from routine planned testing. The avoidance of yearly function checks has resulted in significant savings in manpower costs and plant outages and early warning of valve performance degradation can be acted upon before they result in failures.

Running this application in the Caspian has demonstrated business value to BP locally through improved reliability and reduced maintenance costs, and has resulted in the take up of this new technology across BP worldwide.

Field of the Future is a registered trademark of BP.
Seria North Flank: Development and Management of a Smart Field
Authors: Yong Ivan
Published: March 2012

Brunei Shell Petroleum (BSP) first started completing Smart Wells in 1999, trialing standalone technologies such as permanent downhole gauges and inflow control valves in individual wells. Once these were seen as successful, the technology was used extensively on a single platform. This was later extended to application in a whole field, taking advantage of refinements such as variable downhole control valves and multiphase flow metering.

Learning from the successes of other oil producing fields such as Champion West and Bugan, Seria North Flank was planned and designed as a fully Smart field. Seria North Flank would be the first field to fully integrate Smart technology with Smart field processes, improving the efficiency of Well and Reservoir Management activities and accelerating reservoir understanding in order to reduce uncertainties for future development. This resulted in the development of over 120 million barrels of oil, with improved Unit Technical Costs compared to an offshore development.
Review, Analysis and Comparison of Intelligent Well Monitoring Systems
Authors: Silva M. F. , Muradov K. M. , Davies D. R.
Published: March 2012

Intelligent Well (IW) technology has built-up several years' production experience. Numerous publications have described how remote flow control and monitoring capabilities can lead to fewer interventions, a reduced well count and improved reservoir management. Despite the maturity of IW equipment, the concept of the integrated IW as a key element in the "Digital Oil Field" still not fully developed. Today's practice is to evaluate the IW value chain in a "fit-for-purpose" manner rather than by an integrated modeling workflow. Reservoir engineers still struggle to convince their management of the IW's value, while the well engineer is only consulted immediately before completion deployment. Hardware and software interface problems result because appropriate technology was not selected.

An increasing variety of real-time, downhole, monitoring and measurement systems are now available for deployment or are in development. Sensors for high resolution pressure and temperature, high frequency pressure (acoustic), multiphase flow rate, phase-cut, electric potential (electro-kinetic), seismic (accelerometers) and casing condition monitoring (strain) are all now (at least semi-) commercial; not to mention the option of installing quasi-distributed and/or distributed rather than a single point measurement. The former sensors provide a wealth of information about flow performance and in-well and near-wellbore formation conditions. However, each extra sensor increases the well's installation complexity and operational risk. A well-founded understanding of what data is actually needed; the most suitable sensor types and interfaces together with avail liability of the necessary data reconciliation and validation methodology are key factors for the success of an integrated IW project.

This paper will review intelligent well monitoring systems, their availability, applicability and limitations. It will discuss data acquisition issues in-depth; e.g. resolution, data processing and reliability. Examples of fit-for-purpose sensor/data sets applicable to different IW applications will be given. This paper will guide the completion engineer to identify the appropriate set of downhole sensors for a specific, integrated, IW application.