bluuebunny/crossref_metadata_2025_split huggingface dataset:
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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.