bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Decision Analytic Approach to Geosteering Operations
Authors: Kullawan K.. , Bratvold R.. , Bickel J.E.. E. 
Published: June 2014

Summary
The technique of geosteering has been widely adopted in the petroleum industry for proper wellbore positioning. The benefits of geosteering have become more pronounced as drilling environments have become more complex. Geosteering-related technologies, such as downhole information-gathering tools and real-time data-transmission and data-analysis applications, have been continuously and significantly improved to support geosteering decisions. However, the full value of these advancements has yet to be realized.
Because of uncertainties in predrill geological models, information gathered while drilling is applied in making real-time reservoir-navigation decisions. To achieve an optimal result requires a series of high-quality decisions regarding well-trajectory adjustment.
Interestingly, geosteering-related literature does not demonstrate that the industry has applied a logically consistent approach for making geosteering decisions. Common practice, as described in the literature, does not clearly and quantitatively state measurable objectives, key underlying uncertainties, or relevance between underlying uncertainties and real-time information. Furthermore, it is unclear how a specific geosteering decision is being reached. Lacking a systematic and transparent framework for supporting geosteering decisions, the current approach is unlikely to result in optimal decisions for placing the well in the best possible location.1
In this paper, we introduce and discuss a decision-driven approach to the geosteering process. The main contributions of the paper are threefold: (1) a review of 46 SPE papers on geosteering, including a discussion of the main features of current geosteering methods; (2) the development and discussion of a decision analytic framework to support high-quality geosteering decisions; and (3) implementation of Bayesian inference techniques to consistently update ahead-of-the-bit reservoir uncertainties while behind-the-bit data are gathered in real time. The new framework relates real-time information to the key reservoir uncertainties and provides an unbiased and consistent approach for making high-quality geosteering decisions.
Monitoring Well Performance and Rate Compliance in Real Time: A Case Study
Authors: Al-Dulaijan A. K. , Al-Thuwaini J. S. , Alali A. M , Towaileb H. A. , Al-Daif H. Y. 
Published: June 2014

Abstract
This paper presents an approach to monitor, support and optimize reservoir performance in real time using an Intelligent Field. The approach is demonstrated with a case study based on the experience of implementing Intelligent Field solutions in one of Saudi Aramco's onshore fields. The field is equipped with surface and subsurface instrumentation to capture and deliver real time data. The case study highlights the critical process of utilizing Intelligent Field data to monitor compliance between actual well production/injection rates and the reservoir management guidelines.
The case study shows a giant field with under-saturated, heterogeneous and peripheral water-flooded reservoirs. A fundamental part of reservoir management best practices is to balance the pressure distribution within the reservoir and to ensure uniform flood front movement in the field through maintaining a calculated voidage replacement ratio (VRR). Due to the heterogenous nature of the reservoirs, the voidage replacement level is different from one area to another, which adds complexity in designing and monitoring the optimal injection-production ratios and guidelines. Frequent violations of these guidelines could lead to unwanted consequences, such as early water breakthrough and undesired reservoir pressure.
The demonstrated workflow starts by assigning monthly wells production/injection guidelines based on the field target rate, well status and reservoir/well performance. Then, the workflow captures the real time flowing wellhead pressure and temperature to convert them through IPR/VLP models to rates. Then the calculated rate per well is compared to the assigned target rate per the production/injection guidelines. Responsible engineers receive compliance reports twice a day to take remedial action as needed.
Implementing this workflow helped both reservoir and production engineers to monitor changes in well performance and ensure the compliance to the target rates in real time.
Gas Lift Optimization by Real Time Monitoring using SCADA System
Authors: Ezzine Mohammed 
Published: June 2014

Abstract
By depletion of reservoir, water encroachment occurs and wells were shut-in by heavy column and salty water deposition in the tubing, the decision of lifting wells was taken and wells were converted to Gas-Lift, by injecting Gas and Water in the same annulus to straighten up the field daily production about 30% (2000 m3/d).
Current Production is reached 1500 m3/d, caused by dynamic change in reservoir and operating parameters, the necessity to introduce an innovative technology to improve recovery is strongly recommended.
Data collected in real time from field is used and integrated in nodal analysis software, to optimize the Gas-lift allocation and maximizing wells production vs. Gas injection.
Examples from field are used and a case study of integrated system is illustrated.
Data Management system will be fed automatically from the field, this will increase accuracy by eliminating human error.
Strategies Accelerating Progress of Digital Oil Fields (DOF)
Authors: Mubarak Saeed M. , Winford E.. 
Published: June 2014

Abstract
The petroleum industry has recognized that DOF technologies make it possible to provide more efficient, accurate, and timely information to decision makers. Business value has already resulted from some DOF technology implementations, but there is still much opportunity to be captured and many lessons to learn to take full advantage of the digital oilfield.
The infusion of digital technologies into hydrocarbon upstream industries has significantly impacted the E&P business environment. In this new environment, it is imperative for organizations and their leaders to formulate and deploy strategies that strengthen: Organizational structure and capabilities to support the use and care of DOF.Comprehension business needs and expectations through clear communication.Competencies of industry professionals to improve collective performance.
Pioneers are exploring venues to create adaptive business environments capable of integrating this technological change into their strategies and business value architecture. Continued improvisation of implementation methods can result in the perception that DOF is just very uncertain and wasteful to warrant significant time, attention, and resources. This paper describes a more ordered and disciplined implementation methods that may be used to facilitate tangible DOF progress facilitating the management of assets more intelligently.
This paper also undertakes the mission of uncovering various strategies and technologies for leveraging knowledge, experience, and decision making that could accelerate the progress of DOF implementation. Some of the content of the paper is based on actual survey results, on field observations, and on rational speculation about future trends and advances in DOF technologies and their implementation.
Production Optimisation of a Long Horizontal Well Using Permanent Down-hole Distributed Temperature and Pressure Monitoring and Surface Controlled Zones
Authors: Carlsen Magnus , Kofoed Sara Sparre , Rijkels Lex , Marketz Franz 
Published: June 2014

ABSTRACT
Optimizing production and understanding inflow from long horizontal wells in tight chalk reservoirs has traditionally been difficult. The horizontal sections of these wells have been typically segmented into four to eighteen zones, driven by completion, stimulation and reservoir management requirements. Surface controlled sliding side doors have been used in a number of wells to control the zones for production optimisation, but permanent down hole monitoring of each zone had not been undertaken in the Danish sector so far.
The subject of this paper is the installation and application of zonal pressure gauges and distributed temperature sensing in a recently drilled long horizontal oil producer in the Danish sector of the North Sea. Despite a very challenging trajectory and reservoir pressure variations along the horizontal section the well was drilled to 24,000 ft measured depth and equipped with permanent downhole monitoring and control capabilities. The horizontal reservoir section was segmented into five zones. In each zone a surface-controlled sliding side-door and a pressure and temperature gauge were installed. A fibre-optic cable for distributed temperature sensing (DTS) along the upper four zones to a depth of around 15,500 ft was installed as well. The upper four zones also contained an extra coiled-tubing operated sliding side door for restimulation purposes.
After completing the well each zone was matrix acid stimulated. Stimulation monitoring with DTS allowed quantification of zonal acid coverage and identification of the scope for re-stimulation. During initial production of the well the pressure and temperature gauges in each of the zones proved valuable for start-up operations. Cross-flow between zones was identified and this knowledge was used for improved management of commingled zonal production.
This paper describes how temperature and pressure data from each zone has been used for well production optimisation, in sometimes unexpected ways. The combination of being able to react without intervention using the real-time data has proven to be critically important and supported more efficient operations.
Smart Water Management as part of Supply Chain Logistic for Source Rock Development
Authors: Olsen D. K. , Weitner M. , Olson D. C. , Perino J. O. , Womack D. M. 
Published: June 2014

AbstractSource rock unconventional play development for both oil and gas (O&G) has become economically feasible because of two enabling technologies: horizontal drilling and hydraulic fracturing. This opens a much larger hydrocarbon resource than conventional oil & gas found within traps and covers a much wider surface area than historic oil fields - often in areas unaccustomed to petroleum production and lacking the required infrastructure to support production. To generate the required drainage channels, these tight source rocks have to be fractured to generate flow paths that permit economic production. Water has become the default carrier fluid required to transport proppant required in fracking because of its relative ease of handling, low cost and wide availability. Managing the logistics of water in the supply chain can be a complex and challenging process, particularly given its close scrutiny by regulators and the public. Given the challenges and complexity however, it is still often handled by a series of spreadsheets and project planning software and usually managed under a separate production schedule due to the long lead times needed for permitting, engineering, construction, filling and the required pumps and monitoring equipment. Unlike municipal and utility water systems, water systems for well stimulation are mobile or temporary as end use points move from pad to pad during development of hundreds of wells per year per company. Sourcing, transport, use, reuse and disposal of water vary from basin to basin posing significant challenges and complexity in the management and treatment of frack and produced water.In this paper, the authors discuss Smart Water Management (SMW) in source rock play development primarily for North American and tight oil and gas formations, but with insights that apply worldwide and to the broader field of unconventional development including coal bed methane. SMW incorporates the processes and methods used to more intelligently manage scheduling and logistics in forecasting, supply, transport, storage, use, fracking, flow-back and produced water treatment, reuse, and disposal along with solids and brine, and chemicals handling. Thus optimize water availability, minimize fresh water use, reduce the major costs and the transportation impact, and improve spill/leak detection and regulatory compliance.
Collaborative Work Environments in Shell - Global Scale, Learning and Evolution
Authors: van den Berg Frans G. , McCallum Giles A. , Graves Matt , Heath Elizabeth , Evans Allen 
Published: June 2014

AbstractWith seven years experience, Shell has concluded that Collaborative Work Environments (CWEs) provide significant benefits in the production surveillance and field management area. As a consequence, the company has embarked on a wide scale implementation in all its major existing and new assets around the world. Many of these are now in place. The environments have enabled faster and better decision making by improved communication and easy sharing of relevant information and data. Business benefits include increased oil production, longer equipment life, improved HSE and lower operating cost.The concept of CWEs has evolved, gradually expanding from original real time monitoring centres. Currently, centres for production surveillance and field management and drilling monitoring centres are the most common.The implementation programme has evolved, converging on standard solutions and designs. Standards are now available for processes, disciplines and organisation to be involved, the required information and data, the audio visual technologies and for the physical facilities, the collaboration rooms and offices. In each asset, an assessment identifies the key aspects relevant to the asset and formulates the best collaborative solution for it.Considerable learning has been obtained in various aspects, such as improved access to global expertise, introducing standard processes and ways to sustain the solutions and the benefits.
Delivering Access to Expertise in Upstream Oil and Gas Operations
Authors: Alqadi Eyad 
Published: June 2014

Abstract
Oil and Gas upstream operators are tasked with maximizing rates of production, availability and quality, whilst at the same time minimizing cost of production. Addressing this with a dwindling pool of expert resources following the "great crew change" makes the challenge even greater. Consequently, achieving increased utilization of expert resources will be critical to the future wellbeing of upstream operators.
This paper will initially explore a number of use cases where technology-based solutions can be used to "take the problem to the expert" rather than the "expert to the problem". The provision of long distance/remote access to expertise in real-time using integrated voice, video and data solutions will be shown to derive business benefits in terms of: Reducing the time taken to reach decisionsGiving access to a wider range of experts, thus improving the quality of decisionsReducing the cost of expert interventions by avoiding expensive and time consuming travel to rigs, wellheads and processing facilitiesIncreasing the utilization of experts by enabling them to work simultaneously on multiple issues potentially spread across multiple assets
The paper will then go on to address the key elements of the technology architecture required to deliver this remote access to expertise. It will also demonstrate how the need for standard reference communication architectures has to be tempered with a requirement for flexibility to accommodate multiple use case scenarios and operating environments. This paper will be based not only on the authors’ organization’s own research and development in this field, but also on practical experience implementing wide area collaboration technologies in upstream operations in a number of international and national oil companies. As a consequence it will include not only information on leading edge developments in collaboration technology, but also best practice based on practical experience in the field.
Live Well Models a Tool for Production Optimization
Authors: Rachapudi R. V. , Haider B. Y. , Al-Mutairi T.. , Al Deyain K. W. , Al-Yahya M.. , Shakeel A.. , Qureshey K. R. , Harith Mikhail 
Published: June 2014

Abstract
Continuous well performance monitoring plays a key role in making decision related to well workover and production optimization. Well parameters and corresponding rates over a period of time will represent the change in well performance. Live Well models are useful for estimating the continuous well production rates. Well models become live if they get updated with changing fluid and reservoir properties along with proper calibration to latest well conditions.
In general industry practice is to update the model manually; this is a tidious and time consuming process. Umm Gudair Field Development team implemented a real time system using available resources that integrates and runs workflows between corporate data base, well surveillance data base and well models. Workflows were implemented as part of the real time system to calculate the well parameters from sensor readings and update the models to run on daily basis, such that the models become live and production rates will be estimated.
The daily output generated from the workflows is basically updated well models and parameters along with production estimation report that will get emailed to users. The daily report contains the information about well status, potential, reasons for well closure etc. The workflows are intelligent enough to flag the need for model calibration and surface rate measurements. The daily estimated well parameters will be saved back to database for visualization. In conclusion, real time system was implemented to keep the well models live and useful as a tool for optimizing the oil production, improving the ESP’s run life and delaying the well intervention requirements.
PDO’s Journey Of Process Control Optimisation - A Look Back To The 15 Years Of Existence Of The PCO Team - Challenges, Achievements, Training, Future
Authors: AL-Harthy Hilal 
Published: June 2014

Abstract
In EP industry, the dynamic behavior of well and process facilities is hardly considered. As a consequence, the full design capacity of the plant is under-utilized and at the same time extension projects/ de-bottlenecking are easily justified. Petroleum Development Oman (PDO) solution to this has been the creation of the process control and optimization team which continuously reviews and optimizes the dynamic performance of the production processes in view of improving the equipment/plant availability, enabling smoother operations, freeing-up hidden capacity and operating closer to equipment/plant constraints.
The Process Control & Optimization (PCO) team has also been active in developing control innovation solution to different process dynamic behavior problems and input to engineering project for robust process control design and flawless start up. Typical control solutions have saved the company millions of dollars in waste elimination and in providing in house control solution to engineering design projects. Some of these intelligent solutions are a key enabler of successful execution of Well, Reservoir and Facilities Management (WRFM), Process Safety Management (PSM) and Production System Optimization (PSO).
This paper presents the PCO journey in PDO with a look back to the 15 years of existence of the PCO team with main focus on people, process, technology and sustainability.
The Use of KPIs to Measure Performance Improvement in a Collaborative Work Environment
Authors: Ajmi Jasim , Simmonds Keith 
Published: June 2014

Abstract

Description
One of the perennial challenges of a Collaborative Work Environment deployment is how to demonstrate and quantify the value of benefits that arise from the investment. There does not appear to be a consistent approach to measuring the benefits either at the point of implementation, or on an ongoing basis.
Indeed most oil companies have to rely on just some form of a Post Implementation Review to provide a snapshot of the performance and to extrapolate benefits and savings based on this.

Application
While this approach will enable some measure of effectiveness at one particular point in time, this does not help on an ongoing basis. Considering the costs in terms of time and money typically invested in such implementations, a more precise form of measure is required for management purposes.
This paper looks at the approach used by PDO, the range of performance measures and KPs that were considered and that have been adopted. This approach is now being used across PDO’s the enterprise wide deployment of their second generation CWEs across Oman.

Results
From the work carried out at PDO, a number of measures were identified that enable both the effectiveness of the implementation and the operational performance to be reported on. The operational performance measures are such that these are used across all ten assets and enables regular monthly metrics to be recorded and used for management purposes.

Observations
The work and experience to date has highlighted a number of key learnings

Conclusions
From the work carried out a number of measures were identified that enable both the effectiveness of the implementation and the operational performance to be reported on. While these have not been easy to agree and do require a level of collect and assess on a regular basis there is real value from this work. The operational performance measures are such that these are used across all ten assets and enables regular monthly metrics to be recorded and used for management purposes. These will continue to be used over the lifetime of the CWEs.

Significance of Subject Matter
This demonstrates that a structured and considered approach taken during the deployment of a Collaborative Work Environment can be used to help to provide both a measure of the actual implementation as well as more importantly a means to monitor to assess the value and benefits being provided once in live operation.