bluuebunny/crossref_metadata_2025_split huggingface dataset:
Expandable Monobore Drilling Liner Extension Technology: Applications and Implementations Following the First Commercial Introduction and Deployment
Authors: Stockmeyer Carl F. , Storey Bryan , Emerson Alan Brent 
Published: June 2014

Abstract
First presented in SPE paper 102150, four "pre-planned contingency" case histories for the monobore liner extension system were outlined. As is possible in contingency applications, the enabling recess shoes were installed as an ‘insurance’ for potential well problems, but the monobore liner extensions were not required in these wells. The wells were in the Kristin and Kvitebjorn fields in the Norwegian sector of the North Sea where pressures and temperatures are considered HPHT applications with 13,000 psi (900 bar) BHP and 340° F (170° C) BHT respectively. These values were considered in the design basis of the expandable system.
As a basis of design this technology provides the option for the operator to begin well construction with one smaller casing size and conserve or increase hole size in the reservoir which may drive down costs significantly. As a contingency the system provides alternatives to: squeezing or reducing the hole size after failed leak-off or formation integrity tests; isolating trouble zones such as reactive shales, sub-salt rubble zones, and low fracture gradient transitions (Figure 1). This tool prevents the operator from being forced to reduce casing size or subsequent drilled hole size and tubular size. The realization of this technology yields immeasurable benefits when retaining hole size allows for large O.D. Intelligent Well System (IWS) components and being able to either evaluate the reservoir as fully as desired or to produce wells at rates deemed commercially necessary and optimum. The first commercial installation of the entire monobore liner extension system was accomplished and discussed in SPE paper 108331 (Figure 2).
The technology developed from collaboration between BP and Baker Oil Tools specifically to provide a one-trip, top-down expansion system, capable of deploying a monobore liner extension to prevent loss of hole size.
This paper details: ➢Key System Features and Benefits➢System DevelopmentDownhole recess shoe qualificationCasing selection qualificationZonal Isolation RequirementsMonobore liner extension selection, one trip system➢Field Trial and First Commercial DeploymentPre-planningExpansion ProcessPost deployment results➢Planned Contingency ApplicationsRecess ShoesRecess Shoes with liner➢Casing BOD (Basis of Design) Applications➢Summary
Recent Advances and Practical Applications of Integrated Production Modeling at Jack Asset in Deepwater Gulf of Mexico
Authors: Ozdogan Umut , Keating James F. , Knobles Mark , Chawathe Adwait , Seren Doruk 
Published: June 2014

Abstract
This paper presents an integrated production model construction and forecasting workflow along with three practical real field applications from the Jack asset located in deepwater Gulf of Mexico. Integrated production modeling is a composite modeling strategy that couples subsurface (material balance or simulation) models to a surface network model via well–bore models. The objective of using an integrated production model (IPM) is to predict the reservoir performance, while honoring mechanical design constraints of the surface network. The integrated production model construction process consists of five steps, which are framing, modeling, static quality check, initialization, and dynamic quality check followed by forecasting. An IPM was built for Jack and used as the primary forecasting method for (1) evaluation of artificial lift alternatives (gas lift, sea floor boosting, and electric submersible pumps) (2) identifying key artificial lift design parameters using Experimental Design, and (3) supporting injection facility design. In all of the studies, a black oil flow simulation model was used as the subsurface model and coupled to a surface network model.
Formulation and Implementation of Three-level Spatial and Temporal Mesh in Multiscale Simulation of Multiphase Immiscible Flow
Authors: Atan Safian , Ramirez Benjamin 
Published: June 2014

Abstract
Current reservoir characterization technologies allow very detailed description of the reservoir. Unfortunately, most of the time, these detailed descriptions are lost in the numerical flow simulation process because the models are required to be rescaled. This is due to the limitation of current flow simulation algorithms which could not handle very large models.
This paper proposes a multiscale numerical method that will efficiently solve flow problems of very large, multi-segmented reservoirs. This method contains three-levels of coincidental computational meshes that decouple the diffusive and convective flow problem in both temporal and spatial domains. We implicitly solve for the diffusive-pressure field in the block-scale mesh and then interpolate the solution to the coarse-scale mesh, and then finally to the fine-scale mesh. The convective-saturation solution is solved explicitly on the fine-scale mesh. The saturations are then rescaled back to the coarse-scale meshes and the block-scale mesh pressure field are re-solved.
This algorithm will preserve the flow character of the geocellular models as it minimizes the rescaling requirements. The algorithm is amenable to parallel computing and because of the non-iterative nature of the de-coupled systems of equation, will also allow better scalability for parallel computing environments.
Using Accelerated Learning to Enhance HS&E Skills Training
Authors: Knight P. J. 
Published: June 2014

Abstract
It has been suggested that a very low percentage of subject is retained when training using traditional teaching / presentation methods. Accelerated Learning (AL) theory evolves traditional "chalk & talk" methods by engaging the learner in active learning, encompassing emotion, all the senses and the personality. Referred to as "whole body" versus "head" learning, (AL) is not just "playing games" or "having fun". It is a structured approach that provides good retention results and minimises course preparation and planning times.
This paper describes in-house HS&E skills development with a group of multi-cultural delegates; (AL) was employed to enhance the learning experience, further understanding and improve subject matter retention.
The (AL) process was followed thus: Learner interest and curiosity were aroused before the event by personal communication to each delegate. The delegates’ management teams invited them to attend and highlighted the positive benefits of their gained knowledge.
Each part of the program centred on activity to involve delegates in the learning process – for example, touring the facility with a digital camera, photographing hazards with resultant control measures, and presenting their findings.
During the event, delegates participated in activities to help practice their learning, for example creating and presenting mind maps of key subject matter, and building a "management system Jenga tower" where questions relating to operational controls were written on the individual pieces. Each person had to answer the question correctly before moving on.
Following an examination at the end of the development event, delegates were assigned three real-world risk assessment tasks to ensure applying their knowledge in the workplace as soon as practicable.
The results of the course indicated that students had understood more core concepts of risk assessment than would otherwise be achieved using traditional methods
Modeling Flow along Fault Damage Zones in a Sandstone Reservoir; an Unconventional Modeling Technique Using Conventional Modeling Tools in the Douglas Field, Irish Sea, UK
Authors: Bentley Mark , Elliott Alison 
Published: June 2014

Abstract
The Douglas and West Douglas fields are part of the Liverpool Bay development in the East Irish Sea. The reservoir is a high net-to-gross, largely good quality (100-1000mD) Triassic sandstone lying in a series of fault terraces. The fields have been on production for over 10 years and whereas some wells have shown a watercut development typical for a waterflood, other wells recorded anomalous behaviour. This work addressed these anomalies as these directly influence the value of a late-life infill programme.
The subsurface team reviewed outcrops of the reservoir in NW England, addressing the possibility of vertical flow up and along damage zones of faults which may be otherwise sealing (‘fault-related fractures') - a feature not previously identified in the field. The presence of fault-related fractures, observed in the outcrops, was tested in simulation models and provided a solution to the anomalous behaviour.
A novel technique was employed to pragmatically characterise the fault-related fractures in the simulator. The technique involved installing wells as ‘pipes’ in cells around the faults, allowing flow up and along the fault damage zones without necessarily affecting fault transmissibility across the major zones. The size and location of the pipes representing the fractures was then used as a history matching parameter in the model and resulted in the improved history match of the anomalous wells and the match in general.
Case History – World's First Slim Open Hole Smart MRC Wells
Authors: Al-Amri Khalifah M. 
Published: June 2014

Abstract
Smart Maximum Reservoir Contact (MRC) wells have been successfully utilized extensively across Saudi Aramco to increase reservoir contact, well productivity and total oil recovery. This concept has primarily been used in newly drilled wells. It requires larger than conventional hole and casing sizes to achieve the dimensions required for the Intelligent Well System. Converting an existing well to an MRC poses a new challenge.
This paper presents a case history of two old existing dead wells in Saudi Aramco that were successfully converted into the first Slim Open Hole MRC Wells in the world. The two wells were originally drilled as vertical producing wells with 7" 23# liner set above the top of the target zone and extending to surface. To access more reserves from the field, the decision was made to sidetrack the wells to a new location and drill an MRC wells to achieve maximum productivity from those wells. The wells were planned to be a three lateral wells with a total of 12,000' of reservoir contact in each well. To maximize the long term productivity of the wells, it was decided to run Intelligent Well Systems that enables remote monitoring and control of each lateral throughout the life of the two wells. The final success of these converted slim open hole smart MRC wells are supported by more than expected production gain.
Production Optimization in an Oil Producing Asset – The BP Azeri Field Optimizer Case
Authors: Jalilova N. , Tautiyev A. , Forcadell J. , Rodríguez J. C. , Sama S. 
Published: June 2014

Abstract
The Azeri Field Optimizer is a modeling and optimization platform that encompasses the requirements of offshore and onshore production teams in a single, unified decision support system. The tool supports the following functionalities: data gathering and conditioning, model validation and calibration, economic process optimization and what-if analysis. The Azeri Field Optimizer uses Aspen HYSYS, PROSPER, Microsoft Excel, Aspen IP.21 data historian and ad-hoc MS SQL databases.
The heart of the tool is a high fidelity asset-wide model linked to an optimization solver that receives plant data from a centralized data historian (IP.21). The model uses a combination of first principles and bespoke algorithms to provide an accurate representation of all pressure-flow relationships, material balances and energy equations from the well bores to product delivery points.
The tool has been designed around the existing asset workflows and processes to facilitate the adoption of the technology and it has been created in such a way that allows dynamic re-configuration of the model and optimization problem by automatically capturing equipment availability indicators. This enables the asset optimization team to perform accurate day-to-day production analysis and optimization studies in a timely fashion.
The system has been tested in a number of real production situations where it has helped to: a) pinpoint hidden process behaviors that can be turned into an opportunity for economic improvement, b) identify process bottlenecks under various different production scenarios, c) co-relate offshore and onshore process constraints to find true overall optimums, and d) identify potential oil production increases averaging 3%.
This paper describes the technology and methodologies used for creating the Azeri Field Optimizer and discusses on the benefits achieved so far.
Streamline Simulation for Modern Reservoir-Engineering Workflows
Authors: Thiele M.R. , Batycky R.P. , Fenwick D.H. 
Published: June 2014

Distinguished Author Series articles are general, descriptive representations that summarize the state of the art in an area of technology by describing recent developments for readers who are not specialists in the topics discussed. Written by individuals recognized as experts in the area, these articles provide key references to more definitive work and present specific details only to illustrate the technology. Purpose: to inform the general readership of recent advances in various areas of petroleum engineering.
Abstract
In this article, we present a high-level description of streamline-based flow simulation and focus on four areas in which the technology has proved valuable: reservoir-flow surveillance, flow simulation, history matching, and flood management. We highlight the advantages and disadvantages of streamline simulation (SLS) throughout the article and conclude with a look at possible SLS evolution. SLS re-emerged in the early 1990s to alleviate some computational problems faced by finite-difference (FD) simulation when confronted with high-resolution geological models characterized by heterogeneous spatial distributions of static properties. Since then, development and application of SLS has advanced the technology significantly, such that SLS complements conventional-modeling approaches in many reservoir-engineering (RE) workflows.
What Is SLS?
A streamline is defined as a line that is everywhere tangent to the local velocity field at a given instant in time. The smoke lines generated in a wind tunnel and shown in advertisements to demonstrate aerodynamic qualities of cars are a good representation of streamlines under the assumption of steady state.
Modern SLS used in the oil and gas industry has its roots in the analytical and semianalytical streamline and streamtube methods that date back to the work of Muskat and Wyckoff (1934). Since then, important early contributions were made by several authors (see Datta-Gupta and King 2007 for a reference list). Streamlines also have a long history in the areas of fluid mechanics and groundwater flow, and petroleum literature has drawn heavily from those sources.
In contrast to the early semianalytical streamtube work of the 1970s and 1980s, modern SLS generally is understood to be associated with work published after 1990 and is characterized by six important ideas: tracing 3D streamlines by use of the concept of ’time of flight?? (TOF) rather than arc length, expressing the mass-conservation equations in terms of TOF, periodic updating of the streamlines in time, solving the transport problems numerically along the streamlines rather than analytically, accounting for gravity effects, and extension to compressible flow. All of these improvements originated from the need to relax the limiting assumptions inherent in the early semianalytical streamtube methods and adapt the method to more-realistic and -complex reservoir scenarios (Batycky et al. 1997).
KM Tools for the Next Generation: New Concepts in Rig Tracking and Visualization
Authors: Blue Duncan , Sadlier Andreas 
Published: June 2014

Abstract
Rig counts are a critical business barometer for the drilling industry, suppliers, and the investment community. Rig count trends are governed by exploration and production spending, which is influenced by the current and future prices of oil and gas and reflects the true strength and stability of the industry. They also serve as the foremost indicator of demand for products and services used in drilling, completing, producing, and processing of hydrocarbons. Historically, there has been a primary source of rig counts within the industry. This system is the most accurate because it counts only wells actually drilling for oil and gas. However, as the industry has become increasingly more sophisticated, so has the need for new advancements in the rig count methodology.
Addressing this need, a new process has been developed to expand the capabilities of the existing "active" rig count system. This new process has, among other things, enabled checks and balances and audit trails, enhanced data accuracy even further, provided better means of communication, and has adapted to the rapid changes in technology. The transformation from a "rows and columns" visual depiction of data to an interactive mapping visualization has significantly increased the systems' ease of use as well as provided a multitude of ways to view and access the data and to produce necessary reports. Furthermore, future enhancements are planned for weather analysis, benchmarking/comparison of rig efficiencies and real-time bit inventory tracking, and the ability to download performance information for real-time optimization of drilling parameters/bit selection. Although the new interactive mapping system is in its infancy, it has been well received.
The authors of this paper will present a detailed description of the new method and how it continues to address the need for reliable reporting of rig activity information. This will include an overview of the future systems and enhancements.
Who is my Neighbor? – A Method for Optimizing Collaborative Links in Integrated Upstream Operations
Authors: Thomas James , Pandey Anil 
Published: June 2014

Abstract
The wave of enthusiasm for collaborative working that has swept the upstream oil and gas sector in the past 5 years, has largely been focused on better connecting existing teams and their meeting structures through the widespread deployment of technologies such as video conferencing and real-time data sharing – ‘collaborative working' has become the mantra. However, collaboration for the sake of collaboration can be more disruptive to the efficient and effective delivery of business results than teams working in discreet silos.
Creating sustainable improvement forces companies to look beyond doing things the way they have been done in the past but with collaborative technology thrown in, and connect people and groups based on their workflows. This requires moving away from discipline-focused teams attending a constant string of meetings to ‘batch process' information. Instead, workflow-focused teams should act at the necessary pace dictated by the requirements of their workflows and be provided with the appropriate enabling collaborative tools and technologies. The terms ‘necessary' and ‘appropriate' are key.
If order and discipline are to be maintained in this brave new world, then it clearly requires a firm understanding of the business workflows, the roles of the people acting within them and the toolset needed to enable them.
This paper describes ‘Collaborative Linkage Analysis', a structured approach to defining collaborative requirements. It is based on successful execution of the methodology with several upstream operators and ensures that people are working the processes interactively and collaboratively, not just attending videoconferences and team meetings.
Combining Condition Monitoring and Predictive Modeling to Improve Equipment Uptime on Drilling Rigs
Authors: Faller Karl 
Published: June 2014

Abstract
The offshore drilling industry has maximized utilization, stressing personnel and equipment to improve productivity. Component failure causing unplanned shutdowns is a major problem. Multiple technologies including sensors, data collection and analysis with expert software mitigates the risk of costly unplanned downtime.
Condition Based Monitoring (CBM) continuously collects relevant, near real-time and periodic, data from critical equipment components. It applies predictive analytics using decision tree analysis to build models depicting in advance the potential for failure and helps establish root cause. The purpose is to increase uptime, improve performance and reduce maintenance costs on offshore drilling rigs.
A Confluence of technologies are used, including: -Sensor engineering to extract relevant data-Data collection/processing-Expert software for Predictive, Decision Tree modeling-Actionable information distribution through internet/intranet
It is a proactive approach replacing reactive or calendar/task based systems. It is proven and well established in other industries and recognized as a "best practice".
There are many challenges in the driller environment.
Offshore drilling is remote, widely dynamic operationally, manned with over burdened personnel. Machine condition data does not exist. Some operational data is collected but it is not analyzed and trended for the purpose of eliminating downtime. The CBM/PdM technology reduces downtime with limited personnel involvement.
Solutions:
Sensor technology exists that can be applied to equipment components such as bearing sets. Detailed data collected from the lubricants can be trended and analyzed. Multiple variables (predictors) are used to establish equipment profiles, define normalcy and measure variant, deviation and trends. Regression analysis can produce decision trees forming predictive models about potential problems, well in advance of any incidents.
How a lubricant/bearing decision tree works -
Sensors are installed and collect relevant data from the bearing sets in near real-time with time/date tags. Data (content ppm, viscosity, temperature) is collected from the lubricants and is tagged, analyzed and correlated with the bearing data.
The data is fed into the predictive analytics engine (software), which performs a complex analysis and builds a decision tree that models the data.
A great advantage of decision trees over classical regression and neural networks is they are easy to interpret into actionable items with a clear understanding of how and why a downtime incident is avoided.
Bypassed Oil Detection Using Spectroscopy and Nano Technology
Authors: Jahagirdar Shruti Ravindra 
Published: June 2014

Abstract
Detection of the bypassed oil zones during any matured waterflood or EOR process is a critical step in planning the further applications of these processes on a field. While technically deciding whether to continue to waterflood or plug thief zones as a remedy to high water cuts, it is of utmost importance to take into consideration that the overall economics of the project governs most of the decisions not only the technical applicability.
The ‘Bypassed Zone Detection Tool’ described and proposed in this article will detect the bypassed zones and thief zones located in a reservoir precisely, by using Raman Spectroscopy. The number of such zones detected and the depth of their location can be used in planning of further waterflood or EOR process. The same tool has been described in the author's previous paper with respect to microbial detection by Raman Spectroscopy in order to detect bypassed oil zones. However, since MEOR reservoirs are very few and none commercially proven yet, this paper is aimed at direct oil detection with the same tool as also the assistance of the tool in planning an enhanced recovery process economically. This aspect has not been analyzed in the previous paper.
The tool promises applicability in a wide variety of situations and downhole areas thus proving itself as a strong candidate for commercial use in near future.