bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improving Production in Gas/Condensate Reservoirs by Wettability Alteration to Gas Wetness
Authors: Liu Y. , Zheng H. , Huang G. , Li G. , Li K. 
Published: December 2007

Abstract
Many gas-condensate reservoirs experience a sharp drop in gas production due to condensation near the wellbore as pressure drops lower than the dew point. Wettability alteration approach has been demonstrated successful in laboratory. However few experiments have been conducted in real reservoir rock with a low permeability. The gas-condensate reservoirs impaired by condensation near the wellbore usually have low permeabilities. In this study, we conducted experiments in core samples from the Dongpu gas-condensate reservoir with a permeability of about 0.1 md. Firstly a new and cheaper chemical was found to change the wettability of the rock from water-wetness to gas-wetness effectively. This chemical was thermally stable at a temperature of 170°C. Experimental results also showed that this chemical was effective at very high salinity. Secondly spontaneous water imbibition tests were run to show the effect of wettability alteration on recovery. Thirdly relative permeability data of gas and water were measured before and after the wettability alteration to preferential gas-wetness. Experimental results demonstrated that the relative permeabilities of both the gas and the water phases were increased significantly after the wettability alteration to preferential gas-wetness. The residual water saturation was decreased and the gas production was enhanced greatly due to the wettability alteration.
Field of the Future: Making BP's Vision a Reality
Authors: Reddick C. 
Published: December 2007

Abstract
Rapid changes in digital technology are revolutionising the ways in which we acquire and process data and are improving the quality and efficiency of decision making. Through the application of these digital technologies, both new and existing, BP aspires to operate its assets at the technical limit of efficiency, recovery and cost.
To make this aspiration a reality, BP has implemented a programme called FIELD OF THE FUTURE. The scope of this programme covers development and deployment of technology and business process solutions to most aspects of oil and gasfield operations - from reservoir to export, in both mature and new fields, onshore as well as offshore. The purpose of grouping these technologies under a single programme is to obtain maximum leverage from these technologies by ensuring appropriate integration between them, making strategic choices about where they are deployed and ensuring rapid propagation of early learnings.
This paper describes the portfolio of technologies needed to deliver its vision of FIELD OF THE FUTURE. The following technology themes form the core of BP's FIELD OF THE FUTURE Programme:
Real-time reservoir management Production optimisation Remote performance monitoring and collaboration Advanced collaborative environments Connecting global know-how and expertise, 24/7
The paper will also describe how BP is deploying these technologies and capabilities, with particular emphasis on the revised business processes and enhanced people capabilities needed to underpin successful deployment at scale across its assets.
Finally, the paper will summarise current status of technology development and deployment in BP, the successes achieved to date and challenges that remain.
The Field of the Future Business Process Transformation: Insights and Challenges
Authors: Feineman D. R. 
Published: December 2007

Abstract
BP's FIELD OF THE FUTURE concept makes use of sensors, automation, and computer networks to move real time operations data to remote sites for analysis, enabling informed and fast intervention decisions. Realizing the value from BP's FIELD OF THE FUTURE technology investments requires an integrated design and change implementation approach to business processes, information flows, and people's roles: excellent implementation of the enabling technologies alone rarely solves business problems. Since most oil companies have access to similar base technologies, how we approach process, people, and change management is a strategic differentiator in digital oilfields.
Within BP, we now have more than two years of experience in holistically approaching the issues of business strategy, process, people, and technology in E&P operating assets. Some key insights include:
Transforming the business starts with process: teams often don't have a holistic view of how they work today, so it is difficult for them to assess the impact of real time information and continuous optimization. Understanding work processes, and their assigned roles, is the logical starting point for this analysis. Building an integrated view of asset activities requires people with systems thinking skills: comparatively few people have the high level view of operating asset integration and information flow to facilitate the development of a current or future work design.
The challenges that remain include:
Communicating and positioning the transformation offering Educating implementation project managers about the benefits of including process and people tasks in their plans Establishing reasonable expectations on the engagement and time commitment needed in redesigning and implementing new processes Knowing the right level of analysis: not confusing process with procedure Recognizing the special challenges of greenfield startups: how to start-up a new asset with new processes from day one.
Alkaline/Surfactant Flood Potential in Western Canadian Heavy Oil Reservoirs
Authors: Liu Q. , Dong M. , Ma S. 
Published: December 2007

Abstract
For heavy oil reservoirs (with oil viscosities ranging from 1,000 to more than 10,000 mPa-s), primary production and waterflood can only recover 5 to 10% initial oil-in-place (IOIP) due to the unfavourable mobility ratio of the water phase to the oil phase. Heavy oils usually have a relatively high content of organic acids, which can be neutralized by alkalis to form in-situ surfactants. With the assistance of these in-situ surfactants, an oil-in-water emulsion with a much lower viscosity than heavy oil can be generated. In this way, the heavy oil is entrained in the water phase and produced out of the reservoir.
An initial study was carried out to evaluate the feasibility of alkaline/surfactant (A/S) flooding for western Canadian heavy oil reservoirs. The integrated approach included extensive emulsification tests, oil/brine interfacial tension measurements, viscosity measurements, and sandpack flood tests. The experimental results showed that the dynamic interfacial tension of oil/water can be lowered to an ultralow level (&lt; 0.01 dyne/cm) by an alkaline solution and a very dilute concentration of surfactant, leading to easy emulsification of heavy oil in formation brine under slight interfacial disturbance. A series of sandpack flood tests were carried out to investigate the recovery performance of A/S flooding for five western Canadian heavy oils with viscosities ranging from 650 to 18,000 mPa-s at 22°C. Tertiary oil recoveries in sandpack flood tests were between 20 to 30% IOIP. The results of these sandpack flood tests suggest that A/S flooding is a promising enhanced oil recovery process for thin heavy oil reservoirs, in which thermal processes are not suitable.
Learnings on Sustainable Model-Based Optimisation—The Valhall Optimiser Field Trial
Authors: Stenhouse B. 
Published: December 2007

Abstract
Full field optimisation is a key element of BP's FIELD OF THE FUTURE technology strategy aimed at delivering a capability for remote operation and remote performance management of BP's upstream producing assets. Field of today, Valhall, is a BP operated asset in the Norwegian sector of the North Sea with a track record of applying model-based optimisation technology to support production delivery.
In 2002, Valhall identified the potential business prize from using model-based optimisation technology to support operation of the Valhall platform. The opportunity arose out of the complexity of the Valhall facilities together with the potential to optimise CO2 emissions taxation as well as production. Initial application of this on-line, advisory optimisation technology indicated significant benefits yet, paradoxically, usage of the optimiser fell away gradually after approximately a 6 month period.
In 2004, in order to capture learnings for BP's FIELD OF THE FUTURE programme, the BP Exploration and Production Technology Group, together with the Valhall asset embarked on a field trial of the optimisation technology. The objectives of the field trial were two-fold:
To demonstrate measurable value delivery from the optimisation technology. To establish the federal requirements for sustainability of the technology and associated value delivery.
Optimisation of an upstream producing asset is a cross-disciplinary process requiring close team-working and ownership of optimiser advice from all engineering disciplines, reservoir management, well performance and facilities, through to operations and commercial staff.
Working with the FIELD OF THE FUTURE business process transformation team, the field trial focused on all aspects of the people, process and technology required to deliver sustainable value. The paper discusses key conclusions from the field trial and also how the learnings will influence the way forward for this technology in BP.
Influence of Temperature on Wettability Alteration of Carbonate Reservoirs
Authors: Hamouda A. A. , Gomari K. A. R. 
Published: December 2007

Abstract
Carbonate reservoirs become more water-wet during thermal recovery. The effect of temperature on wettability-altering process is caused by contribution from several parameters involving fluid/fluid and fluid/rock interactions. This paper aims at describing the interrelationship between different parameters of a simple oil/water/rock model over temperature range of 25 to 130 degree centigrade.
Saturated and unsaturated fatty acids as well as naphthenic acids with saturated and unsaturated rings are selected for this work to alter the water-wet calcite surface. The type of selected acids is based on the distribution of these components in reservoirs in the Norwegian continental shelf.
Contact angle measurements on the treated calcite surfaces are used as indication of wattability alteration. At fluid/fluid interface the interfacial tension and distribution of the solutions of n-decane /fatty acids /water systems are measured at elevated temperature. A set of experiments is also performed in order to understand the role of the temperature on fluid/rock interface by zeta potential measurements.
As the temperature increases, calcite surface becomes more water-wet. The obtained results at fluid/fluid interface (IFT and distribution coefficients) and contact angle measurements show that the trend of decrease in contact angles with temperature follows the same trend as IFT and distribution coefficients, specifically if one divides acids to saturated and unsaturated separately. Electro-kinetic measurements (zeta potential) of calcite surfaces with temperature demonstrate that increasing temperature reduces surface charge to less positive, which may enhance the repulsive forces between dissociated acids and calcite surface. Due to this change in surface charge, the adsorption of acids on the surface becomes less effective at high temperatures; hence wettability of the calcite surface tends to be more water-wet.
ISIS—A Real-Time Information Pipeline
Authors: Foot J. , Webster M. , Trueman D. , Yusti G. , Grose T. 
Published: December 2007

Abstract
BP's ISIS technology (Integrated Subsurface Information System) is changing the way BP manages reservoirs through the provision of multi-disciplinary analysis and visualisation of real-time integrated dynamic surveillance data, information and knowledge processes. The technology enables faster and integrated operational decision making, provides continuous real-time access to all digitally acquired sensor data in a well or on the platform, on a 24/7 basis, alerting users to production events which require their attention and can be acted upon. The tools developed by the ISIS Technology Program turn the vision of a real-time data pipeline into a reality by providing an innovative solution for remote visualization of information. The technology provides a robust environment for the transfer of data from the point of acquisition to the point of decision-making.
ISIS and the parallel facilities/operations project entitled D2D (data to desk) use common systems for real-time data management and visualisation. While these developments serve the distinct discipline needs of the subsurface and facilities/operations communities in terms of computational processes, there is a single collaborative system sharing technology of mutual benefit to all communities.
The ISIS system is being deployed across BP's operations as a key element of BP's FIELD OF THE FUTURE programme (1). Initial installation has been completed in seven operational assets across BP that has proven the capabilities and business benefit of the technology. Installation of the technology has been the catalyst for changing the way the field teams approach surveillance; these changes are being enhanced through use of adaptive change projects with the field teams which are changing the way BP operates its fields.
Seismic Geomorphology and Connectivity of Deepwater Reservoirs
Authors: Ragagnin G. M. , Moraes M. A. S. 
Published: December 2007

Abstract
Assessing reservoir connectivity and permeability heterogeneity is essential for predicting reservoir performance. As reservoirs are three-dimensional entities, there is little value in trying to predict reservoir connectivity based on two-dimensional data such as geological sections or maps. A new method for seismic volumetric visualization, complemented with outcrop analog data, was used for assessing reservoir connectivity and permeability heterogeneity of the deep-water reservoirs of Marlim Sul field, Campos Basin, Brazil.
The method consists of combining reflectivity and impedance seismic volumes. For the reservoir target zone, reflectivity was used as top drape covering the whole area, with color contrasts discriminating reservoirs and non-reservoirs, whereas in the impedance volume a cutoff value was used to show only the reservoirs. Such volumetric visualization technique permits the better identification of architectural elements and the better understanding of the evolution of the depositional system. However, some limitations still remain. Before building a reservoir model, it is necessary to assess (1) the internal permeability heterogeneity of the different architectural elements, and (2) the petrophysical nature of the boundaries among the different elements. This was performed by comparing geometries and facies observed in subsurface with geometries and facies documented in outcrop analogs. The main controls on connectivity and permeability heterogeneity in deep-water reservoirs are permeability barriers and baffles, such as hemipelagic shales and marls, turbiditic drapes, debris-flow deposits, shale-clast breccia and cemented zones. Such features present a complex and varied distribution. Barrier and baffle 3D maps of the different architectural elements and of the limits among them obtained in representative outcrops were used to complement seismic information.
The integration of seismic volumetric visualization with outcrop analog data, calibrated by well information and tested again production data, proved to be useful for improving reservoir models.
Developing Young Exploration and Production Professionals To Solve the "Big Crew Change"
Authors: Tealdi L. , Kreft E. , Donachie J. M. 
Published: December 2007

Abstract
Analysis of SPE Membership age distribution reveals under-representation of those younger than 35 years and the average age approaching 50 years. Assuming this is representative of the global E &P industry, a large portion of the current industry workforce will retire within the next 10 years. It follows that attracting and retaining young people is a key strategy today for tomorrow's successes.
The "big crew change" indicates the risk of a significant reduction of available E &P expertise available. Meanwhile, producing oil and gas fields are maturing and new finds are more complex to locate and develop. This means personnel will need to develop a larger cross-disciplinary skills base with each individual skill advancing to address the increasing complexity of operation. The development of young people should be carefully planned within E &P companies, since young professionals represent a vital asset and a major source of competitive advantage in the future.
Maintaining young professionals' motivation and favouring their pro-activeness should achieve continuous growth, excellent performance and dedication to the industry. Existing E &P expertise plays a crucial role. Experienced personnel need to be actively involved in mentoring-coaching programs to facilitate and drive skills' development in newer industry entrants. Organizations who do not pursue an agenda for speedy and comprehensive professional and technical development of their young employees risk their ability to follow future market trends. Such organizations will likely fail to maintain competitive innovation and change.
The paper describes the importance of young professionals in the E &P industry today, offering suggestions on the delicate theme of retention, motivation, performance, empowerment, and specialist versus cross-discipline skills development. Results from various international surveys of the comments of both young, and experienced, professionals are presented.
Increasing Confidence in Production Forecasting Through Risk-Based Integrated Asset Modelling, Captain Field Case Study
Authors: Wickens L. M. , Energy RPS , Jonge G. De 
Published: December 2007

Abstract
To assist in the probabilistic forecasting and decision making process for their Captain North Sea heavy oil asset, Chevron has developed an Integrated Asset Model (IAM). This model includes probabilistic predictions of facilities performance and production, enabling decision risk analysis for strategic and operational decisions. The IAM includes risk-based oil, gas and water production forecasts for the Captain Field and cash flows. These forecasts take full account of facilities constraints and uncertainties in reservoir and operational parameters through links to decision risk analysis software. This paper describes the novel approach used and model application.
Given the presence of multiple reservoir models, multiple PVT descriptions, three-phase flow, and a variety of well types from infill to ‘new field’, the best source of reservoir performance profiles for each well was the in-house Eclipse™ reservoir simulation models. The production profiles for each well are represented by a rate versus cumulative production curve. A particular feature of the IAM is its ability to automatically capture the output of individual Eclipse™ data sets. The results of the simulation models are combined into a single spreadsheet model. This is of particular importance as it enables the effect of facility throughput limitations on gas and water production to be readily assessed. In particular it provides the ability to choke back individual wells on a priority basis from any of the wells in the separate simulations.
A key feature of the model is the ability to investigate new scenarios without the need to run additional Eclipse™ simulations. Validation of this feature is demonstrated.
An example of the model's application to a Captain development decision on whether to proceed with a well workover will be discussed.
New Downhole Electromechanical Service Tool Advancements Provide Increased Integrity in HP/HT Environments
Authors: Foster J. , McConnell R. A. , Moore D. W. 
Published: December 2007

Abstract
During the 1990’s, a battery-powered electro-mechanical downhole service tool used to set/retrieve various pressure containment devices in the wellbore was introduced to the industry. These electro-mechanical actuators are capable of generating high but controllable axial forces at the point of application without relying on surface mechanical manipulations or explosive devices. This capability eliminates most of the logistical special safety considerations inherent with explosive actuators. Since the self-powered tool is independent of the surface machinery, another advantage is that it is possible to reduce the surface footprint for more efficient logistical management.
The electro-mechanical service tools are compatible with conventional slickline intervention methods and provide a practical alternative for explosive and hydrostatic setting tools. (See Fig. 1). This tool has also added significant cased-hole functionality to slickline intervention methods. While the first generation of the electro-mechanical service tools met the majority of conditions needed in the 1990’s, their functionality could not meet some of the operating requirements needed by the deeper, higher pressure fields being produced today.
This paper will describe a new tool system that provides the advantages of the standard downhole power unit (DPU®) system but overcomes the temperature limitations imposed by the more demanding downhole environments in today’s oilfield. The control logic, power management, and power delivery methods used to develop a functional and reliable electro-mechanical actuator for high-temperature/high pressure applications will be discussed. Also outlined is the environmental test program representing real world conditions that was used to validate its reliability. Finally, case histories will be presented.
A Rigorous Well Model To Optimize Production From Intelligent Wells and Establish the Back-Allocation Algorithm
Authors: Graf T. , Graf S. P. , Evbomoen P. , Umadia C. 
Published: December 2007

Abstract
The installation of intelligent wells to improve the economics of production is now common practice. These wells allow the access to marginal reservoirs, for which dedicated production might not be economic, and also accelerate the recovery. Sensors, flow-control and other devices can be used to manage the production from the commingled reservoirs and optimize the recovery.
Traditional methods for production optimization and back-allocation of complex well configurations, such as nodal analysis, work only for a static problem. They cannot account for the dynamic changes that occur in time in the connected system of reservoirs and wellbore. Once multiphase flow occurs, both the change of the fluid mobility in the reservoir and the change of the choke performance cannot be correctly addressed. Moreover, the large number of uncertainties from reservoir to wellbore behavior that influence the performance of those advanced wells cannot be accurately dealt with using traditional approaches.
A process is introduced that creates the most accurate well model of an intelligent completion accounting for all effects influencing the pressure behavior in the wellbore and in the reservoir. This model is used for optimization over all static and dynamic uncertainties to derive an interaction strategy with the intelligent well that maximizes oil production. Furthermore, the back-allocation algorithm is calibrated and trained on the proxy model of the well model.