bluuebunny/crossref_metadata_2025_split huggingface dataset:
Samarang Integrated Operations (IO) - Enabling Real Time Monitoring and Operation of Remote and Mature Asset
Authors: Murugesan K.. , bt Ishak Munira Nur , Bt C Mohamood Nurul Izzwani , Salim Muzahidin Muhamed , Som Mohamad Kasim , Wong Lee Hin 
Published: June 2014

Abstract
Samarang is an existing oil field in offshore Sabah, East Malaysia, developed in 1975. It comprises of 7 wellhead, 3 production, 1 gas compression platforms and 1 Living Quarters. Majority of the platforms are provided with fully pneumatic instrumentation / control and shutdown systems, with no provision for remote monitoring/control except for SMG-A and part of SMDP-A.
Under Samarang Re-development project to increase Samarang production and improve reserve recovery, Integrated Operation (IO) applying real time optimization concept will be implemented.
The main challenges to achieve Samarang IO a real time monitoring and operation environment are as follows: Extensive re-instrumentation work such as installation of electronic transmitters for wellhead and other surface facilities, actuated choke valves for gaslift control, sand monitoring system, downhole gauges & ICVs for smart wells, interfacing with well test meters, operational flowmeters, compressor control panels, instruments associated with separator & crude oil transfer pump etc.Remote Terminal Units (RTU) for the remote unmanned satellites which require certification for Zone-2 hazardous area and weather proof to IP65High reliability and availability designed RTU with dual redundant, hot failover and data buffering up to 5 days.High Availability (HA) data historian configuration with hot failover PI interfaces data collection nodes to enable continuous and uninterrupted surveillance and optimization process.Real time monitoring and control HMI at offshore Central Control Room (CCR), Operation office (SBO) and HQ in a Tri-Node Collaborative Working Environment.The data communication upgrade from remote satellites to mother platform through Wireless Ethernet Radio using TCP/IP-DNP3 protocol; from offshore to onshore (about 55km) through Digital Microwave Radio and leased lines
This paper describes the implementation of Samarang IO key infrastructure – The Real Time Data Acquisition and Control System and underscores its benefits towards achieving real time monitoring and operation.
Second Generation CWE's Can Enable Enhanced Oil Recovery How to add value by deploying CWE's country wide
Authors: Crockett Brian 
Published: June 2014

Abstract

Description
Enhance Oil Recover wells require a greater degree of monitoring and the necessity to respond immediately to anomalies. This is a case study of how a National Oil Corporation moved from one Well and Reservoir Management focused Collaborative Work Environment to a countrywide deployment of eleven CWE’s involved in integrated production system management, monitoring and development of fields moving over to Enhanced Oil Recovery.

Application
To demonstrate how a new design approach to CWE’s permitted Operations teams to use real-time data and exception based surveillance to identify anomalies sooner, maximise the use of collaborative processes and technology to decide faster and ultimately perform better. This paper will explore how a second generation CWE can facilitate collaboration between WRM and Development teams to transition from self-producing wells to EOR wells.

Results
This approach was implemented in Oman across all clusters with Gas lift, beam pumps, Electrically Submersible Pumps, Steam and polymer injection.
The time taken to bring well back to full production was reduced and consequently deferment decreased.

Observations
The following changes in patterns of behavior were observed:

Conclusions
The conclusions can be summarized under the following headings:

Significance of Subject Matter
This demonstrates how a dynamic approach to deployment of a standard solution can be adapted to meet the individual challenges faced by a diverse set of oilfields with a varied Enhanced Oil Recovery strategy.
Drilling Assembly Vibration Model Validated with Frequency Domain Examination of Distributed Downhole Measurements
Authors: Feauto B. l , Jeffery C.. , Hanley C.. , Duff R. G. 
Published: June 2014

Abstract
Resonance is the tendency of a system to oscillate with greater amplitude at specific frequencies. When present in the downhole environment, this effect limits drilling performance. Often, this issue is resolved by employing Finite Element Analysis (FEA) to predict the critical or natural frequencies, which is validated by observing increased vibration levels when rotating at a critical speed. However, this approach is based solely on circumstantial evidence and does not confirm the vibration is occurring at the predicted frequency.
By using multiple Downhole Dynamics Data Recorders (DDDR) in a Bottom Hole Assembly (BHA), the actual vibration frequencies occurring downhole can be calculated and compared to predicted frequencies, thereby validating the FEA model.
This technique was recently used to identify the cause of recurring over-torqued connections in a deepwater application. Analysis of the DDDR data, alongside critical speed modeling, revealed that isolated vibrations within the drill collars were allowing connections to work themselves tighter during specific drilling intervals. These measured vibrations were shown to be resonance-induced by matching predicted natural frequencies with the calculated frequencies from the DDDR, where the observed vibrations increased and decreased in magnitude as the rotation corresponded to the modeled frequencies.
The innovative visualization of downhole vibration data and the validation of critical speed modeling techniques provide a step forward in drilling assembly optimization efforts. These findings will improve the industry’s understanding of critical speed modeling, which in turn will illuminate potential shortcomings of the current methods of vibration mitigation. Practitioners will now be able to design BHAs with more confidence in the results of specific modeling principles, which will ultimately improve performance, reliability and efficiency by eliminating harmful dynamic behaviors.
Improving Resevoir Management through Big Data Technologies
Authors: Seemann D.. , Williamson M.. , Hasan S.. 
Published: June 2014

Abstract
It’s time to set a realistic and pragmatic plan for implementing Big Data Technologies so we can revive our vision of Real Time Fields and fully capitalize on them the way we planned all along.
With the introduction of real time streaming data and the resulting data overload, the petroleum industry has effectively entered into the world of "technical" big data. Using traditional data management techniquess on real time data has resulted in data abbiguity and handicaped our ability to understand the information as it flowes through our hands, we are processing more data but less thoughtfully.
Harnessing the power of big data can return us to the concept of diagnose and forecast, enhancing performance, organizations that master this will be capable of responding more rapidly to evolving situations, but success will depend acquiring the expertise.
Real-Time Automatic Operation and Optimization of Produced-Water Treatment
Authors: Asdahl S.. , Rabe K.. 
Published: June 2014

Abstract
In general, the operation of produced water treatment systems is often based on manual sampling, visual observations, operator judgment and manual tuning by operation of valves. Work has been conducted to automate the operation of a Compact Flotation Unit (CFU). The objective was mainly to reduce the overall amount of discharged of Oil-in-Water (OiW). As discharge peaks often govern the overall OiW percentage in discharge, a real-time operated and optimized CFU system could immediately detect and reduce the effect of such peaks. Furthermore, the waste generated and utility consumption should both be reduced. The CFU operation would not require operating personnel which is an absolute requirement for an unmanned installation or subsea operation. The work was conducted in a produced water test rig. Manual sampling and visual observations were successfully replaced with online analyzing- and flow measuring technology. This replacement ensured better process overview and allowed implementation of Integrated Operations (IO) philosophy. Advanced control algorithms for real-time CFU operation and optimization were developed based on implementation of this technology. The work has resulted in a new automatically operated CFU system. Testing in the produced water test rig met the goals: increasing OiW content was detected and effective corrective actions were taken without the need for operating personnel. In addition to reducing the OiW content, the waste generation and utility consumption were simultaneously minimized.
Certification for Interoperability: a Behavior-Driven, Automated Testing Program for WITSML Version 1.4.1 Servers
Authors: Deeks Nigel , Bye Craig , Gidh Yashodhan , Guterman Jose , Metelskyy Denys , Riegel Bill , Lie S. Steinsbø , Magsipok John , Marcotte Donna 
Published: June 2014

Abstract
The Wellsite Information Transfer Standard Markup Language (WITSML) was developed to provide a common data- exchange format, so that drilling data can be used confidently in various domain/business tasks such as drilling optimization, formation evaluation, or safety-related operations, such as real-time pore pressure analysis. WITSML consists of XML data- object definitions and a Web service specification that allow client software applications to store and retrieve information to/from WITSML servers.
A key requirement for interoperability is for WITSML servers to behave consistently in how they interpret and processes data. To help ensure interoperability, certification for WITSML servers has been available for several years. However, for various reasons, these certification processes were not widely adopted, and inconsistency in WITSML server behavior exists.
A new, behavior-based, fit-for-purpose certification process for WITSML servers (version 1.4.1 and higher) is being developed to address these issues. Key to this process is an open source testing tool that automates running a suite of tests, which use standard WITSML queries, data-object definitions, and behaviors defined in the WITSML specification. If a server passes all of the required tests, then it is WITSML certified.
A company that wants to have its WITSML server tested and certified may download the test tool, test suite, and associated data to first test its server in its own environment, before submitting to official testing (which is conducted by Energistics, the vendor-neutral organization that stewards the standards development process).
This paper describes how the testing processes and related technology were developed and are being implemented. This transparent process and behavior-based, automated, and repeatable testing are expected to deliver the ease-of-use and reliable results needed to drive certification, ultimately improving the interoperability and data reliability provided by WITSML.
The testing tool, tests, and processes were developed by the Certification Group of the WITSML Special Interest Group, which comprises representatives from service companies and operators.
Simultaneous Multifracture Treatments: Fully Coupled Fluid Flow and Fracture Mechanics for Horizontal Wells
Authors: Wu Kan , Olson Jon E. 
Published: June 2014

Summary
Successfully creating multiple hydraulic fractures in horizontal wells is critical for unconventional gas production economically. Optimizing the stimulation of these wells will require models that can account for the simultaneous propagation of multiple, potentially nonplanar, fractures.
In this paper, a novel fracture-propagation model (FPM) is described that can simulate multiple-hydraulic-fracture propagation from a horizontal wellbore. The model couples fracture deformation with fluid flow in the fractures and the horizontal wellbore. The displacement discontinuity method (DDM) is used to represent the mechanics of the fractures and their opening, including interaction effects between closely spaced fractures. Fluid flow in the fractures is determined by the lubrication theory. Frictional pressure drop in the wellbore and perforation zones is taken into account by applying Kirchoff's first and second laws. The fluid-flow rates and pressure compatibility are maintained between the wellbore and the multiple fractures with Newton's numerical method. The model generates physically realistic multiple-fracture geometries and nonplanar-fracture trajectories that are consistent with physical-laboratory results and inferences drawn from microseismic diagnostic interpretations.
One can use the simulation results of the FPM for sensitivity analysis of in-situ and fracture treatment parameters for shale-gas stimulation design. They provide a physics-based complex fracture network that one can import into reservoir-simulation models for production analysis. Furthermore, the results from the model can highlight conditions under which restricted width occurs that could lead to proppant screenout.
Modeling Transportation Logistics, Water Use, and Surface Footprint for Shale Gas Field Developments
Authors: Mitschanek Mathias , Thonhauser Gerhard , Prohaska Michael 
Published: June 2014

AbstractOptimizing operational efficiencies in unconventional resource developments is one of the key success drivers for improved economics. In this work, an approach for exactly that problem is presented, designed for a field development scenario in Germany. Starting with a model that captures all key parameters which are influencing a development program such as the gas market and prize scenarios, political situation, environmental regulations, logistical requirements, etc., it immediately turns out that the highly complex model has to be significantly simplified and a sub-model with clear and precise boundary conditions has to be generated. This sub-model is tuned to problems of particular interest, considering technological parameters such as the impact of various state of the art drilling technologies or different fracturing methodologies on the entire development program. It is possible to identify interrelations of various procedures and allows estimating project costs. Operational scenarios can also efficiently be tested, and validated and the financial key parameters of different scenarios can be compared. Moreover, short- and long-term benefits and drawbacks of various solutions can be assessed and optimized. Also, limitations of System Dynamics for that kind of simulation are pointed out, and it is shown how to solve the problem with an Agent Based Modeling approach.
Use of Near Bit Azimuthal Gamma Ray and Inclination Tool Improves Geosteering in CBM Wells, Airth Field, Scotland
Authors: Thwaites Nicholas , Suh Asong 
Published: June 2014

Abstract
Interest in European Coal Bed Methane (CBM), driven by an increasing demand for supplies of natural gas in Europe has been ongoing since the 1990's in the UK, Belgium, Germany, France and Poland.
The nature of Carboniferous age European coals: multiple, thinner coal seams with lower permeability than coals seen in Australia or North America has resulted in a horizontal well or multi lateral wellbore architecture employing geosteering through the coal seams. Use of a conventional directional drilling Bottom Hole Assembly (BHA) in which the Logging While Drilling (LWD) sensors are usually 40ft or more from the drill bit, makes geosteering in structurally complex coals, with changing dip and rolling topography a major challenge. The cost sensitive nature of CBM wells makes the use of geosteering tools such as azimuthal resistivity tools uneconomic.
This paper describes the experience of Dart Energy and its heritage company, Composite Energy, in introducing an instrumented mud motor with a near bit Azimuthal Gamma Ray and Inclination tool as a cost effective geosteering aid on the Airth CBM Field in Central Scotland. The use of an instrumented mud motor enabled Dart Energy to improve geosteering performance, increasing net coal in each geosteered section, near doubling of average Rate Of Penetration (ROP), and reducing the number of time consuming and costly sidetracks.
The improvement in geosteering is a critical part of realising the commerciality of CBM wells producing from thinner, structurally complex Carboniferous age coals found in the UK and Northern Europe.
Shale and Tight Reservoirs: A Possible Geomechanical Control in the Success of Producing Wells, Neuquén Basin, Argentina
Authors: Garcia Mariano N. , Sorenson Federico , Stockman Hernan , Zavala Carlos 
Published: June 2014

Abstract
Many tight and shale-oil gas reservoirs are being explored in Argentina to increase local hydrocarbon production. As known, hydrocarbon resources in the Neuquén basin are massive; however, many are far from being developed to the degree that they can be called resources. Significant work has yet to be done to make this happen.
It is also well known that large areas in the Neuquén basin are under strike-slip stress conditions that may be a strong influence on stimulation effectiveness. After analyzing the production results of several wells and their associated oil/gas fields, a hypothesis was developed that suggests a possible relationship between the tectonic framework and the location of successful wells. This hypothesis might not only explain the productivity results of some wells to Vaca Muerta shale and other tight reservoirs, but also could help in locations of new wells to help reduce investment risks and improve productivity.
This analysis compares aspects from structural geology, petrophysics, and completion descriptions observed in different fields to productivity results. Information included in this paper is sufficient to improve understanding of the conditions for a good or bad well based on this hypothesis; therefore, these lessons can be applied to generate conclusions.
The Uncertainty of Future Commercial Shale Gas Availability
Authors: Rogner Hans-Holger , Weijermars Ruud 
Published: June 2014

AbstractNumerous top-down resource estimates have indicated that shale deposits hold enormous volumes of methane globally. Until recently detailed delineations of shale gas resources and their production have occurred exclusively in North America. The driving forces and enabling conditions behind the rapid exploitation of shale gas resources in North America are assessed to determine if these are transferable to the rest of world. No two shale deposits are created equal and the mere existence of shale does not guarantee success of future gas production. A formation may hold too little oil or gas — or it may not be brittle enough for fracking to work effectively. The challenge is to find so-called ‘sweet spots’, i.e., plays with high flow rates, once stimulated. The amount of shale gas that can be commercially produced under current and future market conditions is determined by the quantity and thermal maturity of shale's organic content, by regional technology cost, access to transmission pipelines and regional gas price levels. The shale gas rush in North America has caused a precipitous drop in natural gas wellhead prices - from some $11/GJ in 2008 to less than $3/GJ in 2012. A review of the economics of shale gas production indicates that (a) the resource appraisal process for conventional gas resources is unsuitable for unconventional gas resources; (b) field development requires continuous (on-the-go) investment in fracking to stimulate well pressure, and (c) depressed US gas prices currently fail to cover full finding and development costs. Unless well technology improves and completion cost declines rapidly, the maturation process of technically recoverable shale gas resources to proved reserves will be delayed. Time value of money effects undermine the commercial availability of shale gas, particularly in regions where ineffective permitting procedures and slow societal acceptance tend to put additional negative pressure on shale field development speed.
Environmental Stewardship: Lessons for European Unconventional Gas from the United States and Australia
Authors: Wilkinson Paul , von Lany Peter , Lane Alexander 
Published: June 2014

Abstract
Europe is on the cusp of an expansion in the development of unconventional gas resources and many analysts are turning to the United States and Australia to learn lessons from markets at different stages of the development curve. Most attention has been focused on similarities and differences in geology, service industry and gas price whilst consideration of environmental stewardship has been dominated by concerns over the potential environmental and health impacts of hydraulic fracturing. Broader issues of local water security, waste water management and landscape impact have, in contrast, received less attention.
To address these issues, the authors take an alternative look at the European market, using experiences in the United States and Australia to consider the risk management practices, regulatory measures and stakeholder engagement techniques that have achieved greatest success in stimulating the industry whilst at the same time protecting environmental assets. Although the industries in the US and Australia exhibit notable differences to that which may develop in Europe, several overarching observations can be made. The importance of joint-stakeholder working, transparency and carefully defined boundaries of jurisdiction are some of the key factors.
Drawing lessons from these examples and others, the authors conclude by identifying three initiatives essential to the emergence of a viable, publically acceptable and sustainable unconventional gas industry in Europe: Collection of robust and reliable environmental baseline data;Using and communicating sound science; andImplementing collaborative governance.
Failure to implement these initiatives could stifle projects, breed uncertainty, promote conflict with existing industries and the public and potentially, discourage investment. Conversely, by implementing the three recommendations, Europe would be better placed to encourage unconventional gas development in a manner that secures social and economic benefits whilst maintaining high levels of environmental stewardship.