bluuebunny/crossref_metadata_2025 huggingface dataset:
Smart Oil and the Development of the Networked Organisation
Authors: Chapman A. , Forbes P.
Published: July 2010

The world is becoming flatter through global integration and smaller through interconnected communications and commerce, however something more profound is also happening, the world is becoming smarter. For oil and gas organisations this means finding a way to lead in a new environment shaped by three factors

Energy availability to meet the world’s growing needs Energy affordability Environmental input

To date oil and gas organisations have implemented a number of intelligent energy solutions spanning:

Individual technology applications and subsystem optimisation These technology implementations required limited changes to people, process and organisation Collaborative and remote operations Production operations centres, operations and maintenance centres and real-time drilling centres, required significant changes to ways of working, shifting the focus from technology implementation to people, process and organisational change Cross asset optimisation Cross asset support centres and optimisation centres added a further dimension to the people, process and organisational change required

Global integration and smart oil will require both technology, and further significant people, process and organisational change to make it successful. This paper examines where smart oil might take oil and gas organisations in the future, the associated challenges, the networked organisation required and the latest thinking on:

How do operational processes need to change in a global model? How do you leverage expertise, by locating and consulting with experts within the global workforce, wherever they may be? How do you develop community based working, where people connect and interact with others effectively in real-time? How do you capture and share knowledge and learning to retain and effectively reuse knowledge?
Intelligent Visualization for Decision Support in Supervision and Control
Authors: Graven T. G. , Högberg M.
Published: July 2010

This paper describes a solution based on data analysis and innovative visualization methods that aim to aid the control room operator detect faults developing in the process at an early stage. The solution also helps the operators keep an overview in disturbance situations by indicating how the disturbance propagates through the plant. By combining the result from analysis of historical process data with information on alarm and events, the operator is made aware of important changes, relationships and patterns in the process that otherwise would have been very difficult to detect. Novel visualization methods are used to highlight critical factors while at the same time allowing the user to explore and understand large amounts of information at once. A fully functional prototype has been developed and tested on various use cases, both on offline data from a set of different oil & gas facilities as well as on a training simulator at a petrochemical plant.
Intelligent Field Centers IFCs: Integrating People, Processes and Technologies to Optimally Manage Giant Fields
Authors: Barghouty M. F. , Al Dhubaib T. A. , Jama A. A. , Jaimes O.
Published: July 2010

As part of the implementation of its strategic goals, Saudi Aramco effectively leverages intelligent field (I-Field) processes and technologies. The I-Field initiative (development architecture) includes four levels: Surveillance, Integration, Optimization and Innovation, with a vision for full implementation and coverage of all producing fields within the medium term. The accomplishment of this ambitious goal requires a well coordinated approach company-wide to truly benefit and extract value from the I-Field approach and practices.

The value proposition of the I-Field program includes increasing production potential, recovery factor and efficiency with the most safe and environmentally sound practices. One facet of achieving this corporate objective is through enhanced reservoir management strategies and integrated multidisciplinary collaborations. One of the contributing initial elements is the creation of Intelligent Field Centers (IFCs) that will enable and facilitate collaborative decision making around reservoir management processes and tasks.

The first established IFCs had emphasis on reservoir management tasks with a longer vision and a wider objective of optimizing the company’s assets and operations in achieving its expanding goals. This first group of IFCs is foreseen as nuclei for a growing contemporary practice in managing the company’s assets.

In order to come up with the optimum design of these centers and to ensure that they meet the objectives set out by the company, a rigorous, multistage methodology was utilized that started by a comprehensive assessment study. The results of this assessment revealed several high priority workflows being performed by the reservoir management groups, which, once implemented in the IFCs, should deliver improvements in efficiency and, therefore, impacting production and ultimately increasing recoverable reserves.

The assessment and design results showed critical cross-functional and I-Field requirements, such as collaboration, change management, integration, interoperability and openness, automation and knowledge capture.

This paper will detail the methodology followed in assessing the requirements and designing the use of the IFCs.
Is It Essential To Change The Way We Buy Digital Oilfield Capabilities To Get The Benefits We Want? How Do These Capabilities Affect Relationships With Service Providers?
Authors: Popham Michael , Edwards Tony
Published: July 2010

Many benefits of Digital Oilfield (DOF) initiatives come from improved organisational integration. To date, much emphasis has been placed on integrating different functions within a company. However, experience from the defence sector suggests that significant gains can be realised by integrating across the supply chain. In this paper, we look at how these benefits were captured in defence and explore how this knowledge can be utilised in DOF improvement programmes. We also demonstrate that procurement models encouraging organisational integration proved essential to deliver Network Enabled Capability (NEC), the Defence sector equivalent of DOF.

Areas examined include: -

– What different procurement methods were adopted to deliver NEC initiatives? Why were these novel approaches required? How did they affect the capabilities that were delivered? – What business models are being used in defence which are not seen in Upstream Oil & Gas? Are these models likely to succeed in our industry? Examples explored include "Contracting for Availability" and "Through Life Capability Management", where customers are guaranteed specific outcomes and benefits over many years for a fixed, known whole life cost. – How do the roles and responsibilities of customer, Systems Integrator and supply chain vary in different business models? Who benefits in each scenario? – How does the availability of real time data between customers and suppliers change the way we procure capabilities and services? – What are the benefits of partnering with the supply chain? – The criticality of building relationships of trust and mutual benefit between customer and supplier. When a customer becomes critically dependent on a service, how does this relationship evolve? – Balancing long term benefits of coordinated procurement with short term delivery needs.

The paper concludes by exploring to what extent a similar story is unfolding with DOF and asking how can defence experience be leveraged?
Implementing Integrated Operations in a Mobile Offshore Production Service Provider
Authors: Bye Roar , Petrojarl Teekay , Hansson Lisbeth , Okstad Eivind
Published: July 2010

Teekay Petrojarl Production (TKPJ), 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. 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 TKPJ's effort to reach operational excellence. This paper describes all the activities we have entered to achieve the status of operational excellence. Different projects have been going on at the same time to identify needs and try to work in different ways. Based on what has been successful, a path for the implementation has been found. This paper describes the different activities that have been going on towards the implementation of IO, and how this holistic perspective is securing a successful implementation.
Improved Coordination with Integrated Planning: Organisational Capabilities
Authors: Ramstad L. S. , Halvorsen K. , Wahl A. M.
Published: July 2010

The need to increase production, lower operating costs, provide longer field lifetimes, and improve exploitation of the oil and gas resources is met by a change in work processes labelled by actors on the Norwegian continental shelf as ‘Integrated Operations', also known as e-fields, smart fields, and intelligent energy. These organizational changes are meant to improve decision-making by utilising real time information to collaborate across social, professional, organisational and geographical boundaries. Integrated Planning transfers these principles to the planning domain, supporting integration of information and utilizing experience, allowing for knowledge-intensive decision-making. Disciplinary or domain-specific activity plans are integrated into one holistic view in order to optimize the use of common resources like logistic support and maintenance expertise. In addition, a holistic view of the operations allow for more efficient deviation and change management, as changes in one asset domain might prove to be an opportunity for another domain. The organization's ability to take advantage of the extensive information accessible and flexibly handle deviations is reinforced by organisational and human qualities or capabilities. Organizational capabilities are development paths for acquiring certain skills or competences. The paper presents a theoretical framework of how to understand and analyse integrated planning, and proposes four organizational capabilities for successfully implementing Integrated Planning, namely organizational learning, communicative capabilities, agility & resilience, and mindfulness.
Integrated Operations Methodology and Value Proposition
Authors: Lilleng Trond , Sagatun Svein Ivar
Published: July 2010

This article proposes a model for value creation whereby a set of integrated operations (IO) success criteria are matched against key work process aspects. The principles in this model are implemented in Statoil's governing documents as an IO guideline.

The necessary and sufficient conditions for successful value creation by means of IO are modelled in a layered structure with seven success criteria. These success criteria are: Mindset, leadership and trainingOrganisation, networking and work process frameworkCollaboration work arenasInformation visualizations and work spacesInformation accessCommunication infrastructure, data transmission and standardsData capture and remote activation

The purpose of the IO guideline is to: Enable a common platform for improvements and training for all processes and business areasContribute to a common performance level among processes and business areas world wide in Statoil andDescribe the required steps for a successful implementation of IO

A consequence of this model is that the capital expenditure and improvement efforts related to one criterion must be met with matching efforts on the other criteria in order to achieve the desired outcome with respect to improved work process efficiencies, increased production, reduced costs and improved HSE.

The paper discusses the proposed IO model in a life cycle perspective from exploration to production. Examples and experiences from using of the model are included. A summary and some conclusions are given in the last section of the paper.
Antipatterns: A Tool for Continuous Improvement
Authors: Feineman David R
Published: July 2010

Process design patterns are fragments of business processes, used as a solution to commonly encountered problems. A process antipattern is a special form of pattern that is ineffective or has negative consequences but may also be routinely followed. The objective in studying process antipatterns is to identify suboptimal performance, and replace it with better practices. This paper describes some antipatterns in the implementation of digital oilfield projects, refactored solutions that enable recovery from those antipatterns, and the root causes that create them. It concludes with a description of how continuous improvement enabled by antipatterns differs from more traditional approaches to project lessons learned, and why they represent a better way to capture and reuse experience based learning.
Investigation of a New Simulator for Surfactant Floods in Low Permeability Reservoirs and Its Application in Chao-522 Field, 2010 Update
Authors: Yin D. , Gao P. , Pu H. , Zhao X.
Published: July 2010

In this research, the modeling and application of a new three-dimensional, two-phase, three-component surfactant simulator are presented. The simulator is based on the non-Darcy flow characteristics of surfactant flooding in the low permeability formations. The change of threshold pressure and influences of surfactant on convection, diffusion, adsorption, and retention, are all considered. A new equation for the calculation of surfactant adsorption is employed, which can significantly promote the matching degree between the mathematical model and field practice. This mathematical model was adopted to conduct a field scale simulation modeling for a surfactant flooding pilot of the Chao-522 field, Daqing.

Base on the predictions of several injection cases, the injection process was fixed and injection parameters were optimized. The practical injection has received significant feedbacks, like pressure reduction, injection rate increase, and oil recovery increase. The average incremental oil production rate for the individuals was up to 30%. The pilot testing showed a favorable industrial potential in the Chao-522 field.
Advanced Collaborative Environments - The Growth of a Capability Transformation Programme
Authors: Goodwin Stephen , Ford Alan , Griffiths Peter , Moore-Cernoch Kerry , Williams Paul
Published: July 2010

Advanced Collaborative Environments (ACE) have been shown to generate improvements to BP's business performance. To deliver efficient collaborative practices, asset teams have altered their ways of working, their organisational structures and business environments. These ACEs are designed to ensure that offshore production facilities can have immediate access to shore-based specialist support teams via visual, audio and data connectivity to improve the quality of decision making and the problem-solving processes.

BP has several ACE programmes in operation around the world, supporting application of the Field of the Future concept and driving better decisions faster. This paper describes the performance benefits (in terms of increased production, lower costs, improved safety and operational integrity) that the creation and usage of these ACEs have brought to the organisation, as well as highlighting the need to see collaborative environments not as purely process or technology driven initiatives, but more as a capability transformation programme. The authors explain the necessity of genuine engagement and ownership by the end-users so they can search for and leverage advantage themselves. ACE programmes require significant operating expenditure, and it has proved of vital importance to put efforts into maintaining the programme profile, sustaining senior management endorsement and encouragement of the programme, both in funding and leadership behaviour.

This paper also describes the need to develop relationships centered on trust and respect between the onshore and offshore communities so that jointly made decisions can be consistently implemented with confidence.

The personal characteristics and behavioural traits and etiquettes which individuals need to have to work effectively within these environments are also discussed. Offshore personnel need to know when to ask for advice and in turn onshore users can become "respected brokers" to either deal with the issue themselves or seek further input from specific functional teams.

The similarities and differences between the Gulf of Mexico (GoM) and North Sea programmes illuminate the forces which are at work when shaping an ACE programme, and along with the successes, areas for further improvement and plans for the future of both programmes are analysed.
Asset-Wide Reconciled Production Monitoring—A Key Enabler to Successful Real-Time Field Management
Authors: Ibrahim Kolin , Narayasamy Devarajan , Jaberi Md-Yussof , Briers Jan , Goh Keat-Choon , Boer Frank de
Published: July 2010

This paper describes how Brunei Shell Petroleum Co Sdn Bhd (BSP) uses cross validated and reconciled real time production data across large offshore and onshore production networks to support more proactive day-to-day oil and gas production surveillance and management. Examples are presented of the gathering network surveillance systems for the extensive BSP East and Darat Production Assets.

In modern oil fields, there is an abundance of instrumentation distributed over often large geographical areas. The production network ranges from the individual wellheads, to production manifolds, test and bulk separators, past surge vessels and export pumps, to crude dehydration tanks at a central crude terminal or to the gas compressors and gas export points. At least the initial parts of the production gathering network at the wells will have multiphase flow with uncertain and variable oil, water and gas proportions. Normally the most downstream flow meters are well calibrated with good calibration records, but the actual accuracy of the majority of the flow meters upstream will be uncertain, and they will not be nominally designed to handle multiphase fluids or mixtures of fluids with varying densities. Conventionally, it is regarded to be problematic to track production variations in real time across the network back to the source wells. This is due to issues with metering multiphase flows and assumed uncertain transport delays.

It is shown here that it is now practical to track in real time production rates across large production networks, working back from the most downstream, well metered, points to the individual bulk separator units or production platforms or the wells themselves. Indeed, it is possible to obtain a consistent, real-time reconciled view of the current production rates across these larger production networks. This allows more accurate surveillance of production from the wells, early detection of measurement issues and quicker responses to system upsets. Various common blockers to real time network wide production flow surveillance are addressed, including noisy meters, storage tanks, on-off pumps and hard-to-measure multiphase flows from the wells. The work reported may be seen as a "top-down" approach that complements the existing metering systems, integrating the data to "make the best of" all available metering and instrumentation. An example shows how better metering and instrumentation, virtual metering and real time data analysis are combined to detect and correct significant discrepancies.
I-Field Data Acquisition and Delivery Infrastructure: Khursaniyah Field Best in Class Practices: Case Study
Authors: Almadi S. M. , Al Dhubaib T. A. , AhmadHusain H. A. , Al Walaie S. A. , Al Khabbaz F. M. , Alaidarous O. A. , Al Temyatt S. F.
Published: July 2010

Khursaniyah Upstream Facilities development program has successfully implemented the latest systems and applications that support I-Field Data Acquisition and Delivery Infrastructure (I-Field DA&DI); providing better monitoring and early intervention capabilities. Such an implementation relies on a robust real time field to desktop data acquisition and delivery system. I-Field DA&DI integrated together different advanced intelligent surface and subsurface gauges and subsystems; forming data collection for reservoirs vital signs such as temperature, pressure, water cut, etc. The system is based on scalable, adaptive bandwidth, and with embedded resiliency that meets I-Field data acquisition and delivery requirements (data type, frequency, resolution, security, integrity, quality, reliability, etc.).

Saudi Aramco's earliest I-Field implementation projects were at Qatif and Haradh III. These projects were instrumental in developing I-Field data acquisition and delivery requirements for real-time reservoir management and production engineering. The projects assessment revealed limitations and challenges in the data acquisition and delivery infrastructure. Lesson learned from these implementations were adopted in the Khursaniyah Upstream Facilities Program. Furthermore, the Khursaniyah experience has resulted in new findings and lesson learned that will help in improving future implementations to increase systems capabilities and optimize cost.

This paper presents the experience and lesson learned from the latest implementation of Khursaniyah I-Field. The paper highlights examples of some of the inherited challenges in previous implementations and the newly adopted data acquisition and delivery architecture. The adopted architecture, methodology, and subsequent experience gained in overcoming these challenges now serve as a guide in future implementation.
Safety Presentation in Large Screen Displays—A New Approach
Authors: Weyer U. , Braseth A. O. , Eikås M. , Hurlen L. , Kristiansen P.
Published: July 2010

During the last decades, computerized operator stations and soft controls have replaced hardwired wall panels in the offshore petroleum industry. Aspects such as maintenance problems, increasing cost, and lack of flexibility motivate this move towards a computerized interface design. There is, however, a general consensus that there is a great potential for improvement with regards to how information is being presented in computerized systems.

IFE (Institute for Energy Technology) in Halden, Norway has developed and patented graphical symbols using a new design scheme called IRD (Information Rich Design). The displays based on this design scheme are not like traditional Piping and Instrumentation Diagram (P&ID) inspired design, but are based on pattern recognition in addition to use of a new dull color principle where only abnormal situations are highlighted. The new design scheme was initially designed for process interaction, but has become a state of the art standard for Large Screen Displays (LSD) in the Norwegian petroleum industry. Starting with process information, the concept has been further developed during the last years to also include safety information. The aim is to give the operators an overview of the safety state of the plant, and to provide the information needed when an emergency situation occurs. The information content of these safety displays has been specified in cooperation with operator crews through different projects for the Norwegian petroleum industry. The displays are developed using a rapid prototyping method.

This paper addresses, describes and discusses this new Information Rich safety display concept, using the dull color scheme. The motivation behind the information content of the displays is also explained. At the end of the paper some specific design examples and symbol explanations are provided.
Virtual Flowrate Metering in Subsea Producers and Injectors Enables Integrated Field and Reservoir Management: Don Development Case Study
Authors: Loseto Michele , Chacon-Fonseca Joel , Bagci A. Suat , Gilbert Russ
Published: July 2010

Continuous surveillance of production and injection well flow rates throughout field life is essential for well performance monitoring, reservoir management and to meet operational targets. Ideally, surveillance would be achieved using multiphase flow meters on each well, but frequently this is not economically feasible. As an alternative to providing continuous flow rate surveillance, several real-time rate estimation methods can be implemented using existing surface/subsea & sub-surface measured variables, and obtain Best Real Time Estimations (BRTEs) based on the confidence in each method. BRTEs at well level can be added to provide Aggregated Real Time Estimations (ARTEs) at both field and facility levels. Where physical meters exist, a direct comparison and cross validation can be made with the relevant ARTEs, ensuring accuracy and confidence in ongoing well and field surveillance.

The above BRTEs/ARTEs approach has been deployed on a well performance monitoring system in the Petrofac operated Don Fields Development (North Sea UKCS), centred on real-time surveillance and advanced data processing & visualisation. Estimations were implemented based on first principle equations validated with integrated models of reservoir, well and subsea/surface networks, providing Liquid Rate, Oil Rate/Water Rate, Gas Rate and Gas Lift Rate estimations on the production wells, and Water Injection Rate estimations on injection wells. Deployment included user interfaces to allow BRTEs configuration and updating, as well as Aggregate Tables to compare ARTEs with physical field and facility flow meters.

In summary, BRTEs/ARTEs successfully achieved the concept of virtual flow metering on the Don Development, providing the means for continuous well, field and facility surveillance. This enhanced surveillance experience is enabling unique optimization opportunities, allowing engineers to determine optimum settings for maximizing asset production and associated revenue.
We Have Built the Rooms, Our Work Processes are in Place – But Now What – Where is the Value?
Authors: Haugland Ketil
Published: July 2010

This paper addresses an unfortunate observation, that all too often, even the best intended integrated drilling operations get stranded. When this happens, advanced collaborative environments are reduced to function as little more than ordinary meeting rooms. What remain advanced are the fancy screens, the impressive communication technology and the latest in room design and furniture.

Why is this happening and how may it be resolved?

In trying to answer the above question, the paper look at the way knowledge management in the drilling industry appear to be concentrated about data - and information management; about ICT systems and software.

The paper addresses the actual collaboration that takes place inside the collaboration room, the role of people and human expertise. It discusses organizing principles and the role team-work and decision making.

Rather than subscribing to the view that decisions can be handled by automata the paper discuss the full complexity of oil well drilling and how decision making is actually happening in real-time under dynamic conditions. While computers crave rational decision processes, people make decisions from interpretation of less than perfect knowledge, based on experience and expertise.

The paper discuss naturalistic decision making (NDM) models such as recognition-primed decision making; how they apply in real-time and how engineers use them to make sense of the data available in collaboration rooms and Operation Support Centers when assessing real-time occurrences.

In offering solutions to the initial questions, the paper looks outside the drilling industry to other high-reliability organizations working in real-time. The final recommendations include experience from aviation, military and fire brigades etc. and how these organizations have defined the role of human expertise.
Use of Real-Time Data in Well Integrity Management
Authors: Chitale Ashish A , Blosser William R , Arias Brian J
Published: July 2010

Real time data provides key information that can be used to monitor oil and gas wells to maintain well integrity and avoid costly failures. Integrity management is at the heart of BP's operating philosophy. The company uses new technologies enabled by real time data to allow continuous improvement in well integrity management.

The use of real time rate calculations has provided technical assurance to maximize production within BP's deepwater subsea field development. Production has been increased by 10,000 stb/D while maintaining well integrity and process safety assurance within safe engineering operating limits. Similarly, the Na Kika fields apply advanced flux based tools and sand alarming capabilities to protect wells from sand completion failure. Additional fields are currently using BP proprietary technology to monitor and proactively alarm on wellhead annulus pressures, successfully mitigating the well integrity risk of collapsed tubing.

Well integrity management is critical for any operating company. In deep water environments where subsea well costs can exceed 100 million dollars, loss of well integrity can have serious consequences associated with production capability, loss of containment, reputational damage, and regulatory license to operate. Application of new technologies is transforming simplistic past practices into highly sophisticated automated monitoring and advanced control mechanisms enabled by real time data. These technologies have a vital role in delivering advanced capabilities so that engineers can make better decisions, faster, to help retain long term value.

This paper, through case studies, will demonstrate the ability to use innovative workflows and technologies, enabled by real time data, to identify and mitigate well integrity risks. Key risks such as annulus leaks, sand control failures, and mechanical failures are monitored using Field of the Future technologies. These examples from different operating areas of BP will demonstrate continuous improvement, showing how engineers use these technologies to maintain well integrity.
Semantic Web Technologies for Event Modeling and Analysis: A Well Surveillance Use Case
Authors: Zhu Tao , Bakshi Amol , Prasanna Viktor K. , Cutler Roger , Fanty Scott
Published: July 2010

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

In oil & gas operations, optimisation opportunities of the field production efficiency and performance can be developed and guaranteed by combining monitoring and control elements in so-called "value loops". Such an approach is possible when reliable and consistent data and information from the complete production system are provided to the right users at the right time.

This paper presents existing field applications of advanced data validation and reconciliation (DVR) techniques which use all available information and measurements in order to provide reliable and consistent data from reservoir to oil and gas delivery.

Implementation and application of advanced DVR to offshore production installations located in Middle East and West Africa are described in detail with specific focus on well production determination and gas balancing and measurements.

Specific highlights are given to advanced DVR models development, field implementations and on results obtained in continuous well flow rate calculations, in equipment monitoring and topside measurements.

By combining sensors, flow measurements and modelling, advanced DVR has permitted to question and validate measurements but also multiphase metering information, equipment operation and flow models parameters.

Operational field experience gained by TOTAL demonstrates that online use of advanced DVR techniques allows to: Improve continuous monitoring of well productionReduce inaccuracy of gas flow measurements and balancesDetect instrumentation failureMonitor field equipment behaviour

This gives the user the possibility to improve well production figures and environmental reporting and also the opportunity to optimize equipment operation and instrumentation maintenance.
Business As Usual Or Silos Of Excellence: Operationalising Intelligent Energy Through All Production Functions
Authors: Morris Carl , Taylor Dominic
Published: July 2010

Few would disagree that the philosophy of intelligent energy permeates through a large proportion of Upstream operators and service companies. Programmes of work to realise this philosophy are now mature. Collaboration, information visualisation, integration of information to aid decision making all feature as commonplace activities. However, the philosophy is largely siloed within parts of the subsurface community and a general intelligent energy culture does not exist throughout the E&P community. This is especially pronounced when we examine the changes, or lack of changes, that have taken place within operational surface teams over the last ten years.

This paper investigates the extent to which day to day decision making, aimed at optimising production at an acceptable cost, is fully integrated between sub-surface, drilling and surface operations and examines the value that can be generated through this level of integration. Taking surface equipment as an example, it goes on to examine the pre-requisites and integration points required to make a composite picture that means decisions are made taking into account all production constraints. It contends that reliance on automated data is insufficient and that everyone concerned with production activities, even down to operator and maintenance technicians, need to see themselves as key information providers into the production decisions that constantly need to be taken. Citing specific examples of where this has happened, positive cultural side effects can be seen. The paper concludes by looking at the pros and cons of transparency of information between sub surface, drilling and surface operations, effectively making all personnel information consumers and allowing them to input into optimisation decisions.
Urucu Field Integrated Production Modeling
Authors: Campos Sthener R. , Teixeira Alex F. , Vieira Leonardo F. , Sunjerga Snjezana
Published: July 2010

The main objective of this paper is to present a model based integration platform to perform 60+ oil wells optimization in PETROBRAS Urucu field (Solimões Basin, Amazon Rain Forest), while honoring operational constraints on wells, production separators, pipelines, and total field gas processing capacity.

The solution was built based on current technologies of modeling gas and water coning in the high-permeability reservoirs of Urucu, including detailed 3D finite-difference well models automatically history matched to production data, and empirical models based on fundamental flow theory. The well models have been integrated into a prototype solution to simultaneously solve for all 60+ optimal well rate controls. The optimization scheme should determine the optimum setting of well control (e.g. liquid rate) of all the wells in the field and advise on production management of each individual well. The developed concept is presented in the paper.

Another important development presented is a virtual metering modeling that estimates production rate of each well, based on real time data of pressure and temperature measurements on wellhead.

The Urucu field optimization strategy relies intensively on the engineering work related to process and technology. An international and multidisciplinary group including academic collaboration was established to compose the various knowledge needed to embrace the challenge.
Experimental Investigation of Caustic Steam Injection for Heavy Oils
Authors: Madhavan R. , Mamora Daulat
Published: July 2010

An experimental study has been conducted to compare the effect of steam injection and caustic steam injection in improving the recovery of San Ardo and Duri heavy oils. A 67 cm long × 7.4 cm O.D (outer diameter), steel injection cell is used in the study. Six thermocouples are placed at specific distances in the injection cell to record temperature profiles and thus the steam front velocity. The injection cell is filled with a mixture of oil, water and sand. Steam is injected at superheated conditions of 238°C with the cell outlet pressure set at 200 psig. The pressure in the separators is kept at 50 psig. The separator liquid is sampled at regular intervals. The liquid is centrifuged to determine the oil and water volumes, and oil viscosity, density and recovery. Acid number measurements are made by the titration method using a pH meter and measuring the EMF values. The interfacial tensions of the oil for different concentrations of NaOH are also measured using a tensionometer.

Experimental results showed that for Duri oil, the addition of caustic results in an increase in recovery of oil from 52% oil initially-in-place (OIIP) (steam injection) to 59 % OIIP (caustic steam injection). However, caustic has little effect on San Ardo oil where oil recovery is 75% OIIP (steam injection) and 76 % OIIP (caustic steam injection). Oil production acceleration is seen with steam-caustic injection. With steam caustic injection there is also a decrease in the produced oil viscosity and density for both oils. Sodium hydroxide concentration of 1 wt % is observed to give the lowest oil-caustic interfacial tension. The acid numbers for San Ardo and Duri oil are measured as 6.2 and 3.57 mg KOH per gram oil respectively.
EOR Geomechanical Screening- Identification of Risks to Mitigate and Opportunities to Pursue
Authors: Qobi Latifa , Alexander Dave , Strauss Jonathan , Kindy Fahad
Published: July 2010

Geomechanics plays a significant role in the decision making process associated with many parts of the E & P business, spanning exploration, appraisal and production activities and supporting field (re-) development, abandonment and well execution phases. Petroleum Development Oman (PDO) has many mature fields that are subject to either secondary or tertiary recovery mechanisms. Geomechanics has been demonstrated to have a significant impact on the productivity, safety and environment. This is most prevalent in EOR projects and the associated waste disposal systems.

The aim of this paper is to demonstrate: ▪The range of potential threats and opportunities related to steam and polymer flood in EOR developments▪Fit for purpose procedures that can be utilized for early screening of potential risks▪How an early risk and opportunity register related to the geomechanics behavior of the reservoir due to these developments can be established and classified in a scale of likelihood of occurrence versus impact▪Define fit for purpose data gathering, well and reservoir surveillance plans for mitigation

Such work is needed for a comprehensive identification of field measurements, laboratory tests and well and reservoir monitoring opportunities early in the project development process. Results from a clastic reservoir will be used as an example to illustrate the above.
EOR Development Screening of a Heterogeneous Heavy Oil Field - Challenges and Solutions
Authors: Strauss J. P. , Alexander D. M. , Al-Azri N. , Al-Habsi M. , Al-Musallami T. , Koning M. , Eriavbe F. , Al-Jarwani R. , Landman A. J.
Published: July 2010

This paper covers EOR development concept screening from a sub-surface perspective. The field in question is a medium sized heavy oil field with complex geology that is located in South Oman. The two front running concepts considered are steam and polymer flood, both of which present their own challenges. Common to both concepts are the difficulty in obtaining adequate conformance in a field that is characterised by high and highly variable permeabilities in a channelised environment and that includes lateral extensive shales that break the system up into vertically distinct sand units. Additional challenges are presented by a permeable regional scale aquifer, an erosive top surface that reduces the equivalent oil column (EOC) in the core of the field leaving thicker columns laterally close to the edge aquifer and the friable nature of the sand that makes sand control necessary. Challenges specific to steam are the relatively high initial pressure, inferred connection to a regional-scale strong aquifer, and relatively high CAPEX associated with the development. Polymer on the other hand represents a relatively untested option for oil with viscosities of greater than 400cP as are present in this field.

Modelling work used to identify risks and the subsequent development potential of these two options is presented. Potential development and maturation solutions for the various options are discussed and concepts are compared.
Alkaline-Surfactant-Polymer Flood: From the Laboratory to the Field
Authors: Stoll W. M. , al Shureqi H. , Finol J. , Al-Harthy S. A. , Oyemade S. , de Kruijf A. , van Wunnik J. , Arkesteijn F. , Bouwmeester R. , Faber M. J.
Published: July 2010

After two decades of relative calm, chemical EOR technologies are currently revitalized globally. Techniques such as alkaline surfactant-polymer flooding, originally developed by Shell, have the potential to recover significant fractions of remaining oil at a CO2 footprint that is low compared to, for example, thermal enhanced oil recovery, and they do not depend on a valuable miscible agent such as hydrocarbon gas. On the other hand, chemical EOR technologies typically require large quantities of chemical products such as surfactants and polymers, which must be transported to, and handled safely in, the field.

Despite rising industry interest in chemical EOR, until today only polymer flooding has been applied on a significant scale whereas applications of surfactant-polymer (SP) or alkaline surfactant-polymer (ASP) flooding were limited to multi-well pilots or to small field scale. Next to the oil price fluctuations of the past two decades, technical reasons that discouraged the application of chemical EOR are excessive formation of carbonate or silica scale and of strong emulsions in the production facilities.

Having identified significant target oil volumes for ASP flooding, Petroleum Development Oman (PDO), supported by Shell Technology Oman, carried out a sequence of single-well pilots in three fields, sandstone and carbonate, to assess the flooding potential of tailor-made chemical formulations under real subsurface conditions, and to quantify the benefits of full- field ASP developments.

The paper discusses the extensive design process that was followed. Starting from a description of the optimisation of chemical phase behaviour in test tubes as well as core-flood experiments, we elaborate how the key chemical and flow properties of an ASP flood are captured to calibrate a comprehensive reservoir simulation model. Using this model we evaluate PDO's single-well pilots and demonstrate how these results are used to design a pattern-flood pilot.
Experimental Investigation into the Influence of Convective Dispersion and Model Height on Oil Drainage Rates during VAPEX
Authors: Alkindi Abdullah , Muggeridge Ann , Al-Wahaibi Yahya
Published: July 2010

Vapour extraction (VAPEX) has received considerable attention as an enhanced heavy oil recovery process. Like SAGD it relies on significantly reducing the oil viscosity but has the advantage over SAGD that it will be effective in thin or deep reservoirs where thermal methods are impractical due excessive heat losses. Nonetheless field applications of VAPEX have been limited partly due to difficulties in predicting the high oil rates observed in laboratory experiments and thus in upscaling the results to field scale.

In this paper, we present a laboratory investigation of the VAPEX process using analogue fluids in a well characterized glass bead pack. The experiments were focused specifically on determining the role of convective dispersion and reservoir thickness on drainage rates. Longitudinal and transverse dispersion coefficients were measured with and without gravity in order to quantify the impact of interstitial velocities and contrasts in the fluids' viscosity and density on the rate of mixing as encountered in VAPEX.

The experimental measurements of oil drainage rates were higher than predicted by the standard Butler-Mokrys analytical model assuming diffusion-controlled mass transfer. The use of measured dispersion coefficients however significantly improved the model predictions. In addition, the results found drainage rates to have a higher than square root dependency on model height. The combined effects of the roles of convective dispersion and model height on drainage rates were incorporated into a predictive model that satisfactorily matched measured rates in the laboratory.