bluuebunny/crossref_metadata_2025 huggingface dataset:
Combining Distributed Temperature Sensing with Inflow Control Devices – Provides Improved Injection Profile with Real-Time Measurement in Power Water Injector Wells
Authors: Hembling Drew , Berberian Garo , Watson Mark , Simonian Sam , Naldrett Garth
Published: July 2010

Passive ICDs (Inflow Control Devices) have been used in the past to enhance performance of producing horizontal wells in unfavorable environments such as non-uniform permeability and/or pressure variations along horizontal sections. This is the first ever attempt, to the best of our knowledge, at using ICDs combined with a fiber-optic DTS (Distributed Temperature Sensor) to manage the water injection profile across a horizontal reservoir horizon.

The cost of the permanent monitoring installation is comparable to a single coiled tubing deployed PLT intervention. This paper addresses how a passive ICD completion, utilizing DTS technology, was used to optimize and monitor well performance. In addition, the operational aspects of permanent vs. intervention monitoring are addressed while highlighting the opportunity for additional value creation using real-time monitoring combined with ICD technology.

This field trial demonstrates the effectiveness of the ICD system when used in an injection well for injection profiling and fluid diversion during acid stimulation. In addition, the DTS proved to be an effective alternative to production logging in this horizontal water injection well.

The key factor in the success of this project was the use of the 3-1/2" ICD completion along with a DTS system to monitor and passively control the injection sweep across the entire reservoir section. DTS data were also obtained during pre-injection and acid stimulation operations. This was the first occasion in which an operator was able to evaluate stimulation efficiency of an ICD completion using permanent real-time monitoring methods.
Coupled Reservoir Geomechanical Modeling of a Thermal Gas-Oil-Gravity-Drainage Project
Authors: Hussein Assef Mohamad , Minton James , Rawnsley Keith , Qiuguo Li , Zhang Xing , Koutsabeloulis Nick
Published: July 2010

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

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

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

The composite pipe system known as X200™ is a steel strip laminate technology which uses high-performance adhesives to manufacture a metallic composite pipe. It offers a new method of low-cost pipeline construction suitable for onshore gas and oil pipelines in a variety of configurations. The pipe is based on a thin wall liner that provides the fluid containment, the material of which will vary according to service requirements. The grade of steel, stainless steel, special alloy, or even reinforced thermoplastic can be user-defined to suit a given fluid application; the current design is based on 316L stainless steel.

Fusion bonded epoxy (FBE) coated ultra-high strength steel strips are pre-formed and helically wound around the liner to form a laminated high strength reinforcing layer providing the pipe’s hoop strength. These components are bonded together to form a rigid pipe, using an adhesive. The complete structure is then coated with one or more layers of a suitable pipeline external coating material, as required by conditions. The resulting pipe is considerably thinner and lighter than the equivalent rated conventional line pipe products because of the beneficial strength-to-weight ratio of the materials utilized.

Unlike conventional line pipe that is manufactured in a plate mill, and then transported from the mill to the construction site; X200 pipe can be produced at the job site using a portable manufacturing line – greatly reducing the logistics burden for projects and reducing the time to first hydrocarbon production. All units in the manufacturing process fit within standard ISO containers, each weighing between 5 and 20 tonnes. This allows for economic transportation and handling.
Benefits From Implementing an Integrated Asset Operations Modelling System
Authors: Amro A.A. Bin , Sakaria D. , Lestariono Y. , McAlonan N. , Shere A.J.
Published: July 2010

Abu Dhabi Company for Onshore Oil Operations (ADCO) chose the North East Bab (NEB) field complex and asset to pioneer intelligent field technologies and work-practices within the company from development, to production start-up in 2006 and in subsequent enhancement projects. This paper describes implementation and operational experience from the online production optimisation and monitoring software now used as part of the asset team’s work-flows.

Offline modelling of the NEB complex started in 2006 to demonstrate the feasibility of the concept. In what is now becoming standard practice, an offline integrated model of the reservoir performance, production, gas-lift, water and WAG injection wells and surface facilities was set up. Experience from using this model and workshop sessions with all disciplines within the NEB Asset team were then used to specify and commission a commercially available web-based system.

The online system is being used by the team to help optimise reservoir, well and plant performance. Common access to up-todate information throughout the organisation has encouraged faster decision making and prioritisation of measurements with resulting optimal improvement implementations in the field. The system monitors performance against reservoir management targets for production/injection and facilitates diagnosis of any deviations from plan by highlighting flow-assurance issues from the reservoir to well to process plant to export pump. The methodology used is transparent to any user and so confidence can be established in the continuously updated results for well and network flow assurance, reservoir pressure estimation and voidage monitoring. The increasing focus on information, rather than raw data, is improving operational efficiency and the team plan regular enhancement of the system features.

The paper illustrates, using field examples, the benefits being realised from the online performance monitoring and full loop optimisation of both production and injection wells.
A Case Study: "Production Management Solution "Back Allocation and Advance Well Monitoring" - Litoral de Tabasco Asset
Authors: Olivares G. , Perez O. , Escalona C. , Vargas C. , Baarda M. , Vernus J-C.
Published: July 2010

There has been a significant increase in activity in recent years in the development of exploration fields in Mexico offshore operations. Critical operational issues for managing these fields are the large volume of Excel files, disorganized acquisition, and minimal sharing of the different sources of available data. In 2005, some PEMEX (Petroleos Mexicanos) Assets decided to address this data gathering and analysis bottleneck by integrating all operational data into one single central data store to allow the Asset engineers, involved in the monitoring and diagnostic field process, to access a unique and shared source of field information, i.e. "One single version of the truth". One of the most recent developments is AILT (Activo Integral Litoral de Tabasco), located in the Marine Southwest Region – Gulf of Mexico, as is show in Fig. 1, where this case study was developed.

Fig. 1 Map of Mexico illustrating the geography the Litoral de Tabasco asset

When the project started, AILT had 7 platforms and 15 wells and now consolidates all production in the area with 44 wells and 24 platforms using shared facilities. This required the implementation of a workflow to accurately determine the production of each well by applying back allocation and near real-time operational conditions using multiphase measurements. A series of automated workflows integrates all the operational data, from monitoring of the wells in real time to official accounting and reporting system.

The automated workflows have provided a cost-effective solution that minimizes uncertainties in estimating production volumes at the well level for the AILT area, and improves production consolidation required for official accounting purposes. The automatic workflows have further enabled the production team to integrate all operational data, and analyze and monitor the performance of each well as part of the integrated facilities network. In addition, rule-based concepts within these workflows assist in monitoring reservoir drawdown and proactively prevent the contractual penalties related to batch delivery delay to Pemex refineries.
Collaborative Environment Infrastructure in Al-Khafji Joint Operations, A Case Study
Authors: Bedaiwi Mohammed I. , Dharmawan Mohammad A.
Published: July 2010

In today’s exploration and production (E&P) industry, information technology has become a critical component to support business and operational processes. The increasing volume of petrotechnical data with high-resolution 3D seismic data sets and well logs, combined with real-time data acquisition from well sites requires scalable and robust computing infrastructure.

E&P specific challenges, such as remote operation, shortage of experts, and knowledge retention, require changes in the working environment from a specialized and isolated traditional workflow to a multidiscipline collaborative workflow. This collaborative working environment requires technology to enable geoscientists and reservoir engineers to work in an interrelated way. The collaborative working environment can be enhanced further with a virtual workspace to overcome physical distance of collaboration with remote locations.

This paper describes the collaborative environment infrastructure project in Al-Khafji Joint Operations (KJO). Located in Al-Khafji, the border region between Saudi Arabia and Kuwait, KJO has to cope with the E&P specific challenges mentioned above. The project included the design and implementation of an information technology infrastructure to enable a collaborative environment, various geoscientist workflow tools, data management and human interaction.
Practice and Understanding of Separate Layer Polymer Flooding in Daqing Oilfield
Authors: Yaning Liang , Shicheng Zhang , He Liu , Xiaohan Pei , Hong Duan
Published: July 2010

Daqing Oilfield is one of the earliest which develop displacement technology by polyacrylamide (PAM). 1 ton polymer can increase 100 to 120 tons of oil, the recovery from above 40% to nowadays 50%. In view of the geological and physicochemical characteristics, a series of technologies have been developed, such as polymer flooding mechanism, the productivity forecasting, proposal optimization, domestic excellent quality polymer production, surface injection, downhole separate layer injection, and separate layer testing during injection, etc.. The oilfield is characterized by heterogeneous multi- layer sandstone reservoir, during polymer flooding, separate layer injection technology is also needed to alleviate the interlayer differences, enhance oil recovery and improve the whole development effect.

After polymer flooding in main oil layers, the object of polymer flooding in Daqing Oilfield turned to laminated layers with lower permeability and more interlayer differences, these layers were compatible to polymer solution with medium or low molecular weight, using polymer solution with the same molecular weight for displacement will cause difficult injection into these poor layers, and thus have an impact on polymer flooding effect. In order to solve this problem, a new technology is developed through injection of polymer solution with different pressure and different molecular weight in different layers, which can realize the adjustments of both separate layer polymer molecular weight and injection rate, and also field test was carried out in the polymer injection blocks, good results of well stimulation have been seen.

This paper briefly introduces the development and practice of separate layer polymer injection technologies, presents its focus on the principle, string structure and parameters of eccentric different molecular weights polymer injection technology and its field applications in Daqing oilfield.
Application of a Real-Time Dynamic Model-Based Production System for Operations and Surveillance of Oil & Gas Gathering Networks
Authors: Alva-Argaez A. , Holoboff J. , Khoshkbarchi M. K. , van Wassenhove W. , Cutting D.
Published: July 2010

In this paper we present a methodology for synchronized integration of a dynamic simulation model of the wells and production facilities with the real-time online data obtained from the production field. Through dynamic simulation, the production system can be characterized as a transient, multiphase operation capable of modeling time-dependent phenomena. The implementation incorporates development of an accurate dynamic model of the wells and the production network, as well as an online, real-time application which transfers data in a time synchronized manner between historian database and the simulation model at predetermined time steps.

This system has been implemented by Pioneer Resources on the Oooguruk oil field which is the basis of this case study. One important outcome of this system is that it acts as "virtual instrumentation" for key unmeasured variables such as well flow rates. The system can also monitor the performance of specific equipment and support decisions to switch to production modes such as artificial lift. The system can be run offline as a look-ahead tool to predict future behavior given initial conditions or to run what-if scenarios. It has been shown that real-time models that match the field data improve understanding of the overall system, and provide the tools to translate vast amount of data into decision support for daily operational strategies.
Integrated Production Model Calibration Applied to a Gulf of Mexico Sub-sea Field
Authors: Saputelli L. , Rudolph S. , Embser J.
Published: July 2010

Reservoir, Production and Operations Engineers utilize integrated production models (IPM) to understand and optimize performance in reservoirs, wells and pipeline networks. This often requires an initial calibration followed by subsequent updates.

IPM calibration may offer several challenges since it involves non-unique solutions for reservoirs, wells and pipeline network parameters. In addition, suspect results can occur from manual data entry, uncertainties in subsurface parameters, subjective interpretation and poor quality data. These challenges are exacerbated when the user needs to repeat the procedure periodically (e.g. every month) or when new alternative scenarios require subsequent evaluation.

In this work, a consistent and systematic procedure was developed to assist in the calibration of an IPM under the presence of uncertainties. The procedure was successfully applied to a subsea Gulf of Mexico (GOM) field which consists of several reservoirs, wells, sub-sea pipeline network and surface equipment.

The IPM calibration is based on a workflow engine that adjusts IPM parameters to minimize an error function. The workflow engine is used to couple the IPM to a spreadsheet and an optimizer. The spreadsheet computes an objective function (weighted error function of measured vs. simulated results for each IPM variable) and the optimizer follows a gradient-free taboo and scatter search algorithm. Finally, IPM parameters (e.g. reservoir tank pressures, well productivity indexes (PI), pipeline internal diameter, roughness, equivalent choke diameter and choke correction) are selected from the objective function global minimum.

The calibration procedure was also tested by different users leading to similar results. The workflow engine permitted the evaluation of thousands of IPM scenarios in a few days, which would be impossible to do manually. The calibrated IPM predicted field production rates within 4.2% of the actual performance. The procedure developed in this work can be extended to deal with any combination of well, reservoir and pipeline models.
Managed Pressure Drilling: A Multi-Level Control Approach
Authors: Breyholtz Øyvind , Nygaard Gerhard , Siahaan Hardy , Nikolaou Michael
Published: July 2010

Managed pressure drilling (MPD) is emerging as a powerful technology for precise control of wellbore pressure within tight bounds. MPD comes in a number of variants, each taking a different approach to controlling pressure by creating a closed, pressurize mud circulation system. While MPD offers unprecedented pressure control capabilities, it creates operational complexity that renders many standard work flows unsuitable for reliable operation. This is because MPD requires that several tools (pumps, chokes, valves, etc) must be coordinated simultaneously, a task at which humans may not be particularly effective. A solution to this problem is the use of enabling automation tools. Such tools would reliably integrate MPD-related activities using a multi-level hierarchy, allowing humans to concentrate on higher-level decisions, while leaving the reliable execution of lowerlevel decisions to automation. In this paper a multi-level control approach of an MPD operation will be presented. The control hierarchy approach consists of three different levels of control; a feedback control level consisting of fast independent control loops, one supervisory control loop which coordinates the different control loops in an optimal way, and finally an optimization level which tries to meet operational targets while maximizing the economical aspects of the operation. The multi-level control approach will result in an autodriller system.
Decision Support and Monitoring Using Autonomous Systems
Authors: Ølmheim Jørn , Landre Einar , Spillum Øystein , Hepsø Vidar
Published: July 2010

A major trend in the oil and gas industry in the recent years have gone towards moving installations from the surface to the seabed utilizing existing surface based facilities or by developing new onshore facilities. Enabling this trend is an increased instrumentation of the equipment, down-hole and on the seabed. Increased instrumentation results in more data that has to be processed by human operators. Research shows that human operator information overload leads to poor decision making. To avoid information overload, we need a new breed of system where more of the information processing and decision making can be handled by computers.

Over the last couple of years we have worked extensively with autonomous systems. We see autonomy as a vital property in this new breed of systems, where we have identified three scenarios that can benefit. These are:

Production and process optimization Environmental monitoring and control Equipment condition monitoring

The key elements of our approach are a combination of the distributed data processing capabilities of software agents with a variable autonomy approach to the interaction with the human operator. Variable autonomy enables a human operator to defer control to a system when the system state is within a given envelope. The system will escalate decision making to the human operator when it reaches its decision making boundary.

The goal of our work is to make the human operator more capable of handling critical situations and prevent unwanted incidents by transforming the stream of data into information and proposed actions. The work will be focused around the transformation of data into decisions and the interaction between the human operator and the computer system.
Front End Loading for Change Management and Capability Delivery
Authors: Popham Michael
Published: July 2010

Digital Oilfield (DOF) initiatives seek to improve the way we work, enabling more safe, efficient operation whilst maximising hydrocarbon recovery. These goals are in everyone’s interests, yet delivering change across an organisation remains challenging. Pilot projects have not always delivered the expected benefits and widespread adoption has proven difficult.

Success will require an integrated approach to People, Process, Technology and Organisation (PPTO). In this paper, we discuss a new approach to Front End Loading for change management and capability delivery called "Visualisation and Experimentation" (V&E). Over the past decade, V&E has been used extensively in Defence, Aerospace and The Emergency Services.

V&E uses realistic mock ups of proposed capabilities to allow user centred design and assessment of potential changes. V&E scenarios combine real PPTO components with simulations of those that don’t yet exist, allowing testing of different combinations of technologies, processes and organisational models. V&E delivers significant benefits: -

Informed investment decisions. User in the loop assessment allows benefits and impacts to be understood before committing to a pilot. Increased benefits and improved take up of new ways of working. End users from multiple assets can test, improve and then approve a potential change in multiple scenarios. Save time and money. Fewer unsuccessful investments are made. De-risk change programmes. Integrate PPTO before a pilot is run. Test key decisions and processes, ensuring that the final product works as required.

Examples will show how V&E would be applied to DOF problems varying in maturity: -

Understanding a new concept better ("DOF for the Environment"). Try before you buy for a range of potential solutions (Remote Monitoring).

The paper concludes by answering the question "Can V&E be employed in Oil & Gas".
Robotics for Integrated Remote Operations
Authors: Pretlove J , Skourup C , Gunnar J , Røyrøy Anders
Published: July 2010

The major challenges for future oil and gas installations are to create and increase business value in addition to improve HSE (Health, Safety and the Environment). The oil and gas industry has recognised the potential of operations and maintenance in ‘normally unmanned areas’ where access to the entire process is based on utilisation of new robotics-based technologies from remote onshore locations.

This paper concerns remote integrated operations by deploying teleoperation and telepresence of oil and gas installations. The challenges involve more than the technology of transferring data and performing operations. A teleoperator or a telerobot is a ‘machine’ which extends a human operator’s sensing and manipulation capability to a remote environment. An essential issue of telepresence is to keep the human operators in the control loop to enable them to use their high levels of skill to complement the power of remote manipulators.

Teleoperation within oil and gas differs from other known applications as offshore installations represent large, complex and dynamic processes located hundreds of miles away, often in very harsh environments where failures may result in major consequences for the environment and process equipment.

The challenges of offshore teleoperation are to enhance the operator’s perception of the current situation so that the operator has a complete understanding of the state of the process and operates the process as if he was offshore without hundreds of miles and complex technology in between.

This paper outlines the challenges and opportunities of deploying robotics in integrated remote operations with a description of laboratory and early field tests as part of a joint project between ABB and Statoil.

Without any doubt, safe and efficient remote operation is critical for operating profitable new fields which may be completely unmanned in the future.
Real-Time Intelligent Production Monitoring of a North Sea Asset
Authors: van der Linden Ruud , Reijn Hans , Muñoz Esteban , de Wolff Frans , Renes Walter
Published: July 2010

The increasing complexity of natural gas extraction because of reducing reserves, complex behavior and more intricate contractual rules (due to liberalization of the West European energy markets) creates a need for more effective production efficiency. In order to deal with these challenges Wintershall is realizing a real-time monitoring system to optimize production for its (Southern) North Sea fields.

As part of this initiative Wintershall and TNO Science and Industry are developing a model-based advisory tool that uses real-time production monitoring data to optimize production. This paper describes deployment of that tool to optimize production from reservoir to export of one of Wintershall’s North Sea assets. The tool is being used for early event detection, intelligent condition monitoring and support of operators and engineers to make informed decisions that have direct added value to operations.

The cases in the paper show the system’s applicability for early detection of deviation of the measured productivity indices from the mass balance controlled dynamic model predictions and optimizing downtime of wells by mitigating effects of salt precipitation and optimal water washing procedures.

Next to the case data, data preprocessing and validation, two key aspects of the development of the tool will be discussed. Firstly, we will discuss how (dynamic) models are used in model-based monitoring methods that provide the operator with crucial information about production. Secondly, the paper will present a framework that was used to create distinct levels of production monitoring functionality. Next to this, the paper will present application results and validation of the results obtained.

E&P is nowadays getting more familiar with the potential benefits of integrated asset modeling, intelligent monitoring, production optimization and integrated operations – while at the same time it is experiencing many challenges associated with its successful implementation. We feel the work presented in this paper underlines these benefits and offers valuable lessons learned about a successful implementation case.
Sustaining an Intelligent Energy Organization: Insights on the Journey
Authors: Fanty Scott , Tobin Scott
Published: July 2010

Chevron has a vision to transform upstream workflow processes through implementation of innovative solutions that encompass changes in process, organization, and enabling technologies. This effort is creating a sustainable intelligent energy organization. This paper highlights Chevron’s experiences throughout this ongoing transformation. Chevron has a wide range of assets in numerous diverse operating systems with many drivers that must successfully address variables such as: current state (process, organization, and technology), asset type and maturity, work force, and return on investment. There are four key areas that must work in unison for transformation to become sustainable:

Strategic Management Framework: A compelling future vision, aligning guiding principles, strategies, and tactics with the vision to implement and sustain transformation of upstream workflows. Governance Framework: Integrating a diverse set of interdependent governance systems involving corporate, business units, and external entities. Solution Lifecycle Management (SLM): A framework to address key considerations, such as managing transformation roadmaps, developing workflow and technology solutions, capturing the value of solutions, and offering integrated support to ensure sustainability. Organizational Capability: Organizational capability framework focused on building key competencies (e.g., multidisciplinary virtual teams) and ensuring new competencies are addressed.

With the plethora of drivers and conditions highlighted above, sustaining upstream transformation requires a well orchestrated management framework. The body of work created by Chevron Upstream lays the foundation for a sustainable intelligent energy organization and paves the way to a transformed future.
Carbon Capture from Industrial Emission Sources for Use in Enhanced Oil Recovery Applications in Kuwait
Authors: Oskui G. P. , Matrouk M. F. , Salman M. J.
Published: July 2010

Reducing CO2 emissions by capturing from industrial sources and creating value by injection it to depleted oil reservoirs for Enhanced Oil Recovery (EOR) purposes can provide a possible dual benefit by lowering carbon emissions whilst maximizing hydrocarbon recovery in the future. Kuwait has an excellent potential for this technology where carbon capture linked to EOR has the potential to be optimized and implemented on a large scale.

Kuwait has one of the largest recoverable oil reserves in the world, in excess of 95.5 billion barrels, and most if not all of its production is still due to primary reservoir energy. Primary and secondary drive mechanisms are expected to result in the recovery of ∼45% of the reserve, leaving more than 50 billion barrels unrecoverable. This unrecoverable reserve portion is the target of IOR/EOR techniques.

A recent screening study in KISR and Kuwait Oil Company (KOC) has concluded that Kuwait has many oil fields that are amenable to CO2 miscible flooding, which could potentially lead to incremental recovery in the order of billions barrels of oil. Kuwait lacks natural high purity CO2 gas fields, as have been found in some other parts of the world. This makes capture from anthropogenic sources, and in particular from flue gases emitted by power plants, gas processing facilities and other large industrial complexes such as refineries and Petrochemical industries, the most viable option as a source of sustainable and affordable CO2.

This paper addresses the recent finding of the screening study performed for number of Kuwaiti reservoirs concluding that many oil fields that are amenable to CO2 miscible flooding, which could potentially lead to incremental recovery in the order of billions barrels of oil. The road map, and further challenges that Kuwait oil industry faces in adopting and requirements for implementation CO2 injection methods for Kuwaiti reservoirs is outlined.
Improving Recovery from Thin Oil Rim by Simultaneous Downdip Gas and Updip Water Injection -Samarang Field, Offshore Malaysia
Authors: Bui Thang , Forrest James , Tewari Raj Deo , Henson Richard , Bakar Mohamad Abu
Published: July 2010

The Samarang Field is a complex stacked reservoir system, consisting of multiple sand packages separated by thin but continuous shale layers. The general reservoir structure is a faulted anticline. Most reservoirs have an oil rim with associated gas cap and have some natural water influx.

During the redevelopment study for Samarang field, an extensive IOR/EOR study was performed, focusing on the largest reservoirs of the field. A full-field simulation model for the M reservoirs (over 25% of the field STOOIP) was built and calibrated with the historical production, pressure, and fluid-contact movement data. Using this model and various cross section models, an extensive investigation was conducted to evaluate the benefit of injecting water and hydrocarbon gas to improve oil recovery in these reservoirs. The results indicated that updip water injection into the gas-cap region of the reservoirs is beneficial in improving oil recovery. Simultaneous updip water and downdip gas injection gave the highest oil recovery, compared to other injection schemes. This Gravity Assisted Simultaneous Water and Gas injection scheme (GASWAG) improved the sweep efficiency of the lower section on the inner part of oil rim with the downward movement of water and at the same time, increases the swept efficiency of the upper section on the outer part of oil rim with upward movement of injected gas.

The investigated EOR schemes for M reservoirs could potentially increase the cumulative oil production by 20 MMSTB compared to infill drilling only. This increase represents ∼7% of OIIP. A significant fraction of this oil production can be produced by reactivating existing idle wells during the application of the EOR process. This paper describes the investigation of the gas and water injection to improve oil recovery in the M reservoir layers.
Proactive Maintenance in the Context of Integrated Operations Generation 2
Authors: Sätra Ulf Skytte , Christensen Rebecca , AS Norge , Tanase Adrian , Koppervik Ingvar , Rokke Espen
Published: July 2010

With increased requirements to improve production availability; and to have a continues updated overview of the condition status of subsea production systems (SPS), oil and gas operators have increased focus to reach beyond the current practice of integrating onshore and offshore centers and processes for continuous onshore support. Integrated Operations (IO) generation 2, is a further extension to integrate operation centers of the operator and their vendors with heavily automated processes and digital services in a 24/7 operation.

In order to reach IO generation 2, Proactive Management as foundation for operations with a preemptive maintenance program giving an early insight of coming abnormal issues is essential. Focusing on knowledge and understanding of how the equipment and installed base performs is essential and will be empowered by a management system which takes a holistic approach and an automatic integrity diagnoses functionality. To achieve IO generation 2, work processes which promote collaboration and continuous improvements and visualization of the equipment will be necessary to facilitate a common awareness and maintaining an optimum field operation.

By continuous monitoring of the integrity of the SPS in an IO generation 2 context, the Condition and Performance Management (CPM) system enables preemptive maintenance leading to maximum production at minimum maintenance cost. Increasingly important and supported by the CPM system, is the enforcing of health, safety and environment as stipulated in company goals and in national and international regulations.

The CPM system facilitates enhanced collaboration, and it is configured to support the identified IO generation 2 work processes regarding work interfaces and roles. The agreed work processes for an IO generation 2 set-up make the base foundation of the CPM system, from day-to-day monitoring and collaboration to in-depth analysis and improvement of the installed base performance.
The Influence of Data Quality on WorkFlows and Decision-Making in Well Delivery
Authors: Sawaryn S. J. , Whiteley N. , Deady A. , Borresen A. , Gibson N.
Published: July 2010

The paper discusses how data quality influences workflows and decision-making in drilling and completions and examines the use of semi-automated processes for quality assurance. With poor data, additional steps are required and workflows must be repeated. In even relatively simple situations, controlled tests suggest that small changes or omissions may have a significant influence on the work efficiency or outcome.

In earlier work, the quality of any data stream has been described in terms of identity, presence, measurement frequency, accuracy, continuity, units and associated metadata. For some of these a degree of self checking is possible, applying simple algorithms to the data stream to detect presence and bounds, with alarms to alert the operator if these are transgressed. In other cases, such as the change in drag and torque with depth, the stream must be checked against a trend, called a pseudo-log determined from the physics. These calculations are performed by "smart agents" directly in real time on the WITSML data feed from the rig. The paper describes the early work developing smart agents to address data quality and structure of the associated toolkit that can be used to construct more complex agents from a wider selection of data sources, including system generated ones. The computational resources required are also discussed.

The increase in digital data and skills shortage makes manual assurance of all the data streams neither practical nor cost effective. Since current applications are not tolerant of errors and omissions, a step change in data quality is needed if more automated workflows are to be achieved. Greater assurance of the data at source and an improved understanding of the workflows will help.
The Life Cycle Simulator: From Concept to Commissioning… and Beyond
Authors: McArdle S. , Cameron D. , Meyer K.
Published: July 2010

This paper describes the concepts behind the multi-faceted life-cycle simulator and demonstrates its effectiveness in practice. Dynamic simulators have been successfully implemented in the oil and gas industry for process design and operator training and have become a standard tool in problem solving. As the oil and gas industry has evolved, operational concepts have also necessarily developed. Continuing improvements and employment of new technologies in order to optimize processes have become routine in recent years. The life-cycle simulator is a concept whereby a dynamic simulator integrates the new technologies and intelligently utilizes the updated model as an enabling tool for integrated operations and decision support for the industries new developments. This paper describes a case study where a full life-cycle simulator has been implemented. It also presents an online simulation prototype developed in association with Statoil. It outlines a future vision and steps taken for the simulator as it is incorporated further into integrated operations.
"The Predictive Organisation"— How The Defence Sector Improved Asset Availability and Integrity
Authors: Popham Michael , Keely Daniel
Published: July 2010

The Oil and Gas industry shares many requirements and characteristics with the Defence sector; Operations are conducted in remote, challenging, often hazardous environments with little established infrastructure. Increasingly, remote monitoring is being used to provide more efficient inspection and maintenance of critical equipment. This provides valuable expert resources with effective status monitoring and the ability to function across an organisation, irrespective of location.

Drawing on experience from the Defence sector, this paper discusses how organisations use remote monitoring to deliver predictive, rather than reactive maintenance. It explores the benefits of integrating predictive maintenance with logistics and supply chain management to create a "predictive organisation" which can project and then optimise asset availability and integrity. New approaches for operators to consider are identified which are proven in the Defence sector.

When applied to a fleet of over 240 fast jets, these methods delivered £1.4bn cumulative savings over 6 years whilst meeting availability targets. The annual OPEX budget for the fleet fell from £711m to £328m. The customer was able to demand additional availability as required.

Areas examined include: -

– What drivers underpin remote monitoring solutions in both industries? What are the key challenges? – How can data from a wide range of existing sensors be better used to provide reliable decision support? – How can information from a disparate range of equipment from multiple vendors be integrated into asset availability models? – How are availability levels assured, even across large portfolios? How is increased availability delivered on demand? – How can information derived from remote monitoring be used in a wider collaborative network to deliver increased benefits? – What security challenges do collaborative, multi-organisation remote support centres introduce?

The paper concludes with a summary of lessons identified and an example of how these are being harnessed in Oil and Gas.
Leveraging Web 2.0 Technologies for Innovation Capture
Authors: Watt Andy R.
Published: July 2010

To fully leverage innovation within an organisation, communication channels must work both ways. We need to move away from the old broadcast model to an open dialogue with the target audience, ensuring the message is understood and the call to action is being addressed.

Using open source software, the "Woodside Innovation & Improvement Zone (WIIZ)" is one example of how Web 2.0 technology is being used to create a culture of innovation within the company.

The WIIZ incorporates a number of Web 2.0 concepts: tagging, user participation, voting, design simplicity and two-way communication. Importantly, the software used is not of great importance, a number of different tools could have been used to achieve the same goal. Simplicity, usability, flexibility and cost effectiveness were the primary technology drivers.

The WIIZ is in a "Perpetual Beta" state allowing user-driven enhancements to be made and fully transparent two-way communication applies to the innovation ideas and to the actual site design and functionality.

The site is currently administratively time-consuming, with future enhancements to be made to reduce this overhead. User feedback has been very positive from all levels within the organisation. The project was not started specifically as a Web 2.0 demonstration, but rather has used this technology where appropriate.

Capturing Woodside's innovation and continuous improvement ideas, projects and challenges in a fully transparent, community driven, collaborative way allows us to harness the skills, creativity, experience and passion of our staff more effectively than ever before.
A Guided Workflows Approach to Oil Field Management
Authors: Daum Steve , Getty Robin , Berg Frans van , Clinton Robert
Published: July 2010

It is evident that Digital Oil Field Projects have succeeded in making reservoir, production and operations data more widely available. However, it is also evident that many operators still fail to realise the full value of these data. Too often, oil field professionals are overloaded with information with the direct result that the organisation fails to respond appropriately within the available window of opportunity. The authors believe that in order to realize sustainable improvements in operational efficiencies and in decision-making for production optimisation and reservoir management, the Industry now needs to find ways to ensure that the new streams of information and knowledge that result from Digital Oilfield Projects can flow freely throughout the organization. IT solutions need to do more to screen, classify and rank data, to present the most significant information to the most appropriate person as and when it is needed, to marshal the right analysis tools and configure them optimally for the task at hand, and to route critical actions and results across the organization in the manner most appropriate to the prevailing circumstances.

Much effort has been spent attempting to devolve increased levels of governance to computer systems, including responsibility for the management of workflows, but workflow automation solutions applied to date have tended to be too prescriptive and too inflexible to cope with the dynamic and varying circumstances that humans invariably have to deal with in a real world production situation. This paper describes the piloting of a "guided workflows" solution for Well Test Validation in one of Shell's Operating Companies. This was the first workflow tool built in Shell using PRODML™ connectivity standards.

The solution automates the gathering and pre-analysis of production and well test information, delivering the screened and prioritized results for validation by the appropriate professional, e.g. Production Programmer, before the start of the working day. PDS incorporated human workflow extensions into Shell's production web portal that were used to guide the user through the most appropriate analysis steps and route results to the appropriate team member and other company experts for further analysis and actioning. The solution incorporated overviews of the progress and status of well test validation activities across the company, and provided audit trails to support organizational learning and compliance checking at the granularity of individual tasks and decisions.

The pilot results indicated significant potential for the approach in related areas e.g. production surveillance, optimization and reporting. The extensive use of the PRODML™ standards favourably impacted systems integration project costs and timescales, and increased software reuse.