bluuebunny/crossref_metadata_2025_split huggingface dataset:
In-House Developed Workflow Smart System for Rig-Less Operation
Authors: AL-Bahrani Hasan 
Published: November 2016

Abstract
E-Business, an industry abbreviation that is short for "electronic business," refers to business that is conducted or facilitated in some way over the Internet. However, e-Business not only refers to the act of buying or selling; instead, it also covers the areas of customer service and collaboration with business partners. E-Business also refers to the processes and tools that allow an organization to use Internet-based technologies and infrastructures, both internally and externally, to conduct day-to-day business process operations of any kind, in addition to services or commerce that must be conducted over the Internet.
Well Surveillance Group adopted Automated Workflow under Services Teams responsible about well intervention under Kuwait Oil Company. The paper explains the development an E-Business Model as a case study. First, organization structure should be identified. Then strategic plan analyses take place to understand the organization goal. After that, record of each activities and responsibilities to the organization unit or department. In Addition, each activity should be break and converted to measurable task and information required to completed. Finally, link tasks together according to tasks relationship, information required exchange between them, authority manpower or unit, assigned to tasks to complete the organization workflow activities. This report simplifies the case and focus on Automation and integration satisfy both interal and eternal cusomers. The data analysis shows more than 90 % improvement to satisfy customer request. It also carify that automation minimizes delay of communication and inetrgration between responsible team/business unit/employee. The Workflow system customization help to get instance reposnse related to wel intervention. It also, helps sharing information and eliminate dubplication task between team/business unit/employee. The measurable HSSE impact of automate the business process through workflow found also significant by reducing paper less work and manpower driving KM from office to oil field in oil sector. The case study presented in this paper suggest recommendation on how to adopted such system in their task by giving guidelines of each phase of developmine such system.
A New Approach to Forecasting Production from Liquid Rich Shale Reservoirs
Authors: Makinde Ibukun , Lee W. John 
Published: November 2016

Abstract
The oil and gas industry is in need of rapid and simple techniques of forecasting oil and gas production. Forecasting production from unconventional, low permeability reservoirs is particularly challenging. As a contribution to the ongoing efforts of finding solutions to this problem, this paper presents a new method of forecasting production from liquid rich shale reservoirs called the Principal Components Methodology (PCM).
In our study, we simulated production of fluids with different compositions for 30 years with the aid of a commercial compositional simulator. We then applied the Principal Components Methodology (PCM) to the production data from several representative wells by using Singular Value Decomposition (SVD) to calculate the principal components. These principal components were then used to forecast oil production from wells with production histories ranging from 0.5 to 3 years, and the results were compared to simulated data. Application of the PCM to field data is also included in this work.
Various factors ranging from ultra-low permeability to multi-phase flow effects have plagued the mission of forecasting production from liquid rich shale reservoirs. Traditional decline curve analysis (DCA) methods have not been completely adequate for estimating production from shale reservoirs. The PCM method enables us to obtain the production decline structure that best captures the variance in the data from the representative wells considered. This new technique eliminates the need for parameters like the hyperbolic decline exponents (b values) and the task of switching from one DCA model to another. It also allows us to forecast production without necessarily using diagnostic plots. With PCM, we were able to forecast oil production from shale reservoirs with reasonable certainty.
This study presents an innovative and simple method of forecasting production from shale reservoirs. It provides fresh insights into how estimating production can be done in a different way.
KPI's for Advanced Process Controller at ADGAS
Authors: Alsereidi Rabeiah 
Published: November 2016

Abstract
It has been noticed that the nature of the gas liquefaction plant is highly interactive and sensitive to small changes which can propagate in a way ending to alter production rates if not attended properly and in timely manner. For example, slight changes in parameters of Multiple Component Refrigerator (MCR) Compressor could eventually affect Main Cryogenic Heat Exchanger (MCHE) leading to reduced production rate or unstable plant operations. It even gets harder to stabilize when another variable or more gets disturbed in the same time. ADGAS implemented Advanced Process Control Solution (APC) for LNG Plant with intent to increase throughput while respecting all the constraints required for ensuring integrity and reliability of its assets. It is also helping to improve efficiency, reduce emissions and also to reduce operator stress by substantially reducing operator interventions required.
Model based predictive control is used in implementation of APC. Overall structure of controller includes 5 controllers. This type of implementation is not so uncommon in industry today, however, at ADGAS we had some challenges which were eventually overcome using innovative solutions: MR Composition ControlMR OptimizationNeed for Robust Inferential structureTackle impact of gas drier change over on upstream and downstream plant
A base case data was considered to compare pre and post APC implementation. Overall benefit of APC project appears initially when the PID control loops are tuned and later when APC controllers are commissioned. Hence the benefits from the improvement of PID control loops also need to be considered on the overall benefit estimation of APC. On ADGAS Train 3 LNG unit, the tangible economic benefit of APC is quantified in terms of increase in LNG, C3 and C4 LPG production & energy reduction. Intangible benefit includes increased naphtha production, plant stability and less load to panel operator.
The Cost and Sustainability Benefits with Integrated Process and Power Automation Architectures in Electro-Intensive Oil and Gas Plants
Authors: Smith Christopher J. 
Published: November 2016

Abstract

Objectives/Scope
The oil and gas plant industry is looking for increased cost and energy savings, particularly with the recent changes in global macroeconomic conditions. In response to this plant automation suppliers have been looking at simpler more collaborative automation architectures. This paper outlines the case for an integrated architecture which enables benefits throughout the entire plant definition, construction, and operative lifecycle, preserving the relevant engineering autonomy for three distinct automation domains, Process Control, Process Safety and Electrical Network Management.

Methods, Procedures, Process
Describes the automation landscape and briefly defines the various automation domains, subsystems involved and description of the common interface techniques used on generic system in the upstream oil and gas industry. Describes the emergence of the Electrical Management and Control System based on IEC61850. Reviews newer smarter electrical technology used for efficiency and energy availability gains and its consequent impact on the automation systems designs. Contrasts the techniques used in the shift between static and dynamic load shedding and its relevance to the architecture.

Results, Observations, Conclusions
A preferred integrated architecture is described with an outline of practical constraints and objectives. A first order model estimate of engineering effort savings in integration is determined. The evolution of more efficient Electric Power technology and the emergence of a networked EMCS electrical design information model and architecture coupled with a VFD usage provides an increased rationale for the incorporation of dual-language supervision of ICSS and EMCS. The paper concludes that engineering, capex and plant energy efficiency improvements in mechanical and electrical designs can be improved through adoption of the preferred automation architecture.

Novel/Additive Information
The paper develops a model based comparison of automation effort on multiple segmented autonomous systems using different networking information models.
Lean Optimization on Well Placement: Directional Drilling Operations in South of Oman Wells: A Case Study
Authors: Kindi Nasser Al , Shehhi Qasim Al , Al Adwani Abdullah , Al Habsi Saud , Emanuel Roy 
Published: November 2016

Abstract
Drilling operations within the oil and gas industry can be very complex and expensive; and while directional drilling and well placement are critical in the well delivery, additional complexities and time consuming processes must be followed to drill and deliver the wells, as desired, following the trajectory.
It is desirable to evaluate the implementation of best practices to improve well delivery efficiencies, minimize nonproductive time and transfer lessons learnt from one well to another.
Lean thinking has existed for many years; it was first developed within the automotive industry in the 20th century, and then began to be applied within other industries. The lean concept is based on eliminating waste by more closely examining processes to identify and eliminate waste in every stage of a process, thus improving efficiency and lowering production costs.
Lean thinking has become popular amongst senior level management within the oil industry, and has become part of core strategies for many companies, with dedicated resources to systematic lean implementation in many areas of business with clear goals and objectives.
An operating company began lean implementation in different areas. An opportunity to lean and standardize the development drilling process was recognized in the south of Oman, with improvements to be replicated in the other fields, as applicable.
This paper describes the implementation and outcome of a lean philosophy for directional drilling. By adopting and engaging in simple lean thinking, improvements can be achieved in many areas. The value of lean implementation and workflow is presented. Also discussed are results obtained that led to significant savings in the survey time, contributing to faster well delivery and improved efficiencies.
High Integrity Pressure Protection as an Economic Alternative to Flare System Upgrade in Brown Field Project
Authors: Al-Hosni Ali Khaleel , Hafez Mohamed , Gawari Rajendra , Raval Prayag 
Published: November 2016

Abstract
In a brown field modification, increasing the capacity of a compressor station from 200 MMSCFD to 350 MMSCFD mandates replacement PSVs at the compressors discharge which in turns leads to excessive flare load and large capital investment. As per the production profile the production rate will sustain at this level for 1.5 to 2 years and then will sharply decrease to a turndown rate of 125 MMSCFD. Considering the short term utilization and the large capital investment to upgrade existing flare network an alternative solution was sought of by introducing a non-conventional design of HIPPS. Introducing this solution, reduction in shutdown duration up to 50% and saving in capital investment by approximately 30 to 40% of project cost the target have been achieved
Ensuring Safety through Flexibility Enhancement of Amine Unit Operation
Authors: Ahmed Alya Al , Rafiq Shahid , Narayana Sathyanath , Awadi Ibrahim Al 
Published: November 2016

Abstract
Limitations in Amine storage capacities at one of GASCO's Plants necessitates the use of temporary ISO-Storage containers to store surplus Amine during Plant / Process shutdown. This poses serious risks to equipment and personnel safety which could be categorized as a safety critical issue. This paper addresses the study carried out to resolve the issue, exploring various options and how the proposed solution mitigates the risks and ensures process safety by enhancing operational flexibility of the amine unit.
Optimization of the Plant layout for HSE constraints resulted in location of amine regeneration section farther away from the amine unit, leading to an increase of solvent inventory above design levels. As a result, during shutdown operations, the existing storage capacity was deficient by a significant margin, necessitating use of temporary facilities to overcome the shortfall.
A study was carried out to find solutions to the issue and various options were explored. Limited availability of space in an existing Plant, working within hazardous area and tie-ins with existing processes posed several challenges. The entire study was carried out utilizing GASCO's in-house resources involving full spectrum of discipline engineering expertise.
The selected option involved provision of an additional storage tank and associated facilities. This included identification of the required tank sizing and storage capacity, feasible location of tank and transfer pump, feasibility study of pipe routing and tank bund containment calculations.
The following benefits will be achieved with the proposed solution:
- Safe access for operation/maintenance.
- Proper containment of spillages / leakages within the tank bund.
- Nitrogen blanketing to stop H2S release and reaction of lean amine with oxygen.
- Venting (routed to a safe location).
- New lean amine tank will have fixed firefighting foam system.
- Use of fixed 6 inch line instead of hose for lean amine transfer.
- Shutdown delays will be avoided.
- Process contamination will be avoided.
As the proposed location was within the hazardous area close to live Plant units, tank installation was required to be carried out within the shutdown period. This triggered the development of a novel approach for a modular fabrication of tank, transportation in parts and installation strategy, to maximize pre-shutdown activities and enable optimum use of shutdown duration for the installation. Accordingly, study addressed this concern through extensive interaction with tank fabricator and recommended suitable methods.
Modular fabrication and installation of a new tank within live process units to ensure reliable and safe operations, is a novel approach to addressing the solvent storage issue. This approach will also avoid delays and extended shutdown duration.
The Autonomous Management of Wells with Unplanned Sustained Casing Pressure
Authors: Brodie Alan 
Published: November 2016

Abstract
Unplanned Sustained Annulus Pressure (SAP) in the A Annulus (sometimes referred to as the tubing/casing annulus or TCA), is the most common of all well integrity management challenges. Typically, this is as a result of a failure in a well integrity barrier envelope element / component. Monitoring for this situation is of critical importance because it generally means the ‘double barrier' well integrity policy that most OPCO's follow is breached. Depending on the nature of the SAP, it is often necessary to close in the well pending workover. In other cases, where a workover is not economically viable, the well may be prematurely abandoned. Alternatively, the wells may remain in operation ‘under dispensation'.
In the cases where wells continue to operate ‘under dispensation' increased manpower is required for monitoring and manual bleed down. This is to avoid the SAP exceeding the Maximum Allowable Annulus Surface Pressure (MAASP) and to monitor for any changes in the nature of the SAP. In addition to the obvious increased risks associated with a pressurized annulus, where only a single barrier to flow exists, other significant risks are also, often unknowingly, accepted. This is due to the way annulus pressure is typically measured and recorded. These annulus pressure measurement risks and a field proven solution to mitigate them, are described in this paper.
The paper also describes a field proven solution to the challenge of managing wells with unplanned SAP in the A annulus. It involves retrofitting technologies, which were originally developed for use in gas lifted wells, where the wells are designed to cater for planned SAP in the A annulus.
A leak from the A annulus of a gas lifted well would usually pose a higher risk of an explosion than would be the case from a non gas lifted well with SAP in the A annulus. Consequently, the paper therefore concludes that the approach used to provide a double barrier envelope to prevent a gas release from the A annulus in gas lifted well, can therefore also be applied in non gas lifted wells, where the SAP in the A annulus is unplanned. As a result, the risks of operating wells ‘under dispensation' are reduced. Wells which previously had to be killed or plugged pending workover or abandonment, may also be reclassified as ‘capable of operating under dispensation'.
The paper describes how the system can be automated, to facilitate autonomous annulus pressure monitoring and bleed off without manual intervention. It goes on to discuss how the nature of the SAP can also be tracked and the sampling frequency optimised.
Finally the paper describes how these technologies can be retrofitted to existing wells. This is possible, without the need for workover, annulus depressurization, wireline intervention or significant wellbay piping modifications.
Overcoming the Design Challenges of Brownfield Projects
Authors: Hassan Khurram , Wasnik Rakesh Vasant , Singh Harendra , Kamal Faris Ragheb , Takeiddine Oussama 
Published: November 2016

Abstract
Major investments have been made by the Oil & Gas industry in large-scale Greenfield projects to boost offshore & onshore facilities production. In today's low oil prices scenario, industry's focus is shifting towards Brownfield projects which have relatively low CAPEX and high Return on Investment (ROI). However, Brownfield project execution involves many unique design challenges that are not generally encountered in Greenfield development. The paper presents a variety of such challenges, and strategies for mitigating the same.
Successful execution of Brownfield projects is inherently complex due to constraints and unknowns in existing facilities. Many issues are identified only during execution stage, and thus result in late changes in design and /or scope. Shortfalls become apparent only during execution, resulting in delays to project completion, production loss to Company and possible cost overruns to Contractor. This may lead to erosion of ROI for such projects. It is therefore essential to identify issues early on in design, and ensure alignment of all stakeholders, including the Vendors.
Key design challenges usually faced during Brownfield project execution include:
Limitations in existing design, especially for equipment / systems not adequately addressed in Front End Engineering Design (FEED) such as utility systems, flare systems, layout constraints, safety related design requirements, tie-ins etc. Incompatibility between the existing and new equipment / systems Data / Estimates on health of existing equipment Availability of current asset documentation / as-built data in electronic format Discrepancies between design codes / standards used in existing systems versus latest codes / standards Poor planning due to lack of details and understanding of existing facilities
Design and engineering challenges are required to be addressed early on in the project lifecycle, to avoid project execution issues. For example, in one of the Brownfield Engineering Procurement and Construction (EPC) projects, the scope included replacement of an existing pump with a new pump of similar design. It was later found that the new pump also required modifications in the control system, recycle loops, facility layout, etc. In another case, an existing separator that was considered adequate for receiving well fluid from a new pipeline was later found inadequate based on network simulation results, and thus required major modifications in the implementation phase.
NPCC has been involved in many challenging Brownfield projects. The paper describes strategies to address such design complexities and challenges based on the successful experience in a number of major EPC Brownfield projects.
ERD Lower Completion Deployment: An Iterative, Multi-Disciplinary Approach
Authors: Beaman Daniel , Newton Daniel , Clews Matthew , Alvarez Juan , Allahyarov Rashad , Molster Jon , Al Khatib Osama , Parihar Shardul , Ryan James , Akyabi Khalid , Niznik Michael 
Published: November 2016

Abstract
The long term development from four artificial islands of this giant offshore field in the United Arab Emirates (UAE) is requiring longer and longer ERD wells. This can only be achieved by drilling higher angle, higher departure and increasing lateral lengths. Horizontal departure ratios have increased from 2:1 to 3:1 and will, before the development has finished approach 4:1. Maximum Reservoir Contact (MRC) lateral lengths at the beginning of the development were planned to average 10,000ft but are already being lengthened to 20,000ft, and beyond.
This paper describes the many challenges that have arisen and have been successfully overcome to enable deployment of 6 5/8" horizontal lower completions of lengths up to 20,000ft into wells that are greater than 30,000ft MD.
These challenges have been surmounted through the use of proprietary in-house software, leveraging partner resources and global experience, close collaboration between drilling, completion and field development teams, new technology equipment development and deployment methodologies.
Several case histories will be presented and discussed at length in this paper. These will focus on specific aspects for each of the wells such as the; high strength liner connections, high load liner running tools, reservoir drilling fluid composition, swellpacker design, use of drillpipe or casing swivels, centraliser type and the effect of dog leg severity in the long reservoir lateral.