bluuebunny/crossref_metadata_2025_split huggingface dataset:
Well Log Cluster Analysis: An Innovative Tool for Unconventional Exploration
Authors: Euzen T. , Delamaide E. , Feuchtwanger T. , Kingsmith K. D. 
Published: February 2011

Abstract
Well Log Cluster Analysis: an Innovative Tool for Unconventional Exploration Tristan Euzen, Eric Delamaide, Tom Feuchtwanger, Kim Kingsmith.
Exploring for economically viable accumulations of hydrocarbons, the task of explorationists is becoming considerably more complex in mature basins because of the unconventional nature of most remaining resources. Analyzing a large volume of data is required in order to develop a comprehensive understanding of reservoir distributions and/or their production performance characteristics. Furthermore, the unconventional nature of reservoirs makes it challenging to interpret well log data and indentify potential gas pay using conventional data analysis approaches.
Well log cluster analysis is an innovative approach that provides the explorationist with an efficient tool for analyzing, screening and filtering a large volume of well log data, in order to identify and map potential hydrocarbon accumulations. The method involves seeking high density areas (clusters) in the multivariate space of well log data, in order to define classes of similar log responses. These classes called electrofacies can be calibrated using various sources of data such as core description or production data and can then be used to process very quickly hundreds of wells.
Cluster analysis and electrofacies classification have been applied to develop unconventional gas prospects in the Upper Mannville incised valley fills of the WCSB. The reservoirs dominantly consist of arkoses with complex mineralogy, and are characterized by both conventional and unconventional production from low resistivity pays. A cluster analysis was first performed on 5 producing wells used as training samples, and an electrofacies classification was then performed on 395 wells in an area of 28 townships. A quality control of the results was done by checking the electrofacies interpretation in front of producing intervals from 41 wells. The preliminary results are very promising, with 89% of the producing intervals used in the blind test properly predicted by the electrofacies classification. Finally, potential gas bearing intervals identified by the electrofacies classification have been mapped in order to define prospective areas. This approach has many potential applications in the field of unconventional hydrocarbons, especially where conventional log analysis doesn't work properly and where a large volume of well log data is available.
Enhancements to Remotely Operated Downhole Fluid- Loss Isolation Barrier Valves Enable Reliable Operation in Debris-Laden Conditions
Authors: Robb Graham , Robb Ewan , Inglis Peter 
Published: February 2011

Abstract
With the increasing demand for technology to perform in more extreme operating conditions, service companies continue to seek solutions that will enable operators to meet the increasing demands more efficiently.
This paper will focus on remotely activated Fluid Loss Isolation Barrier Valves (FLIBVs) that are used to retain wellbore fluids during completion/workover operations to prevent formation damage and improve the well productivity index. One of the current innovations for deep water is a remotely activated FLIBV. Remote activation offers significant benefits to the operator when compared to conventional fluid-loss devices; i.e., the operator can save days of rig time, as there is no need for well intervention to open or remove fluid-loss devices to bring the well into production.
Several designs have been deployed globally over the last few years, however, this paper will focus on one design that provided a remote-opening success rate of 94% in over 140 installations. The valves that did not open remotely were usually those that had been suspended with the ball closed in extremely debris-laden conditions. While the 94% success rate is certainly exceptional, the engineers that designed the equipment felt that the issues that were causing the valve failures should be addressed. When the failures were reviewed, it was determined that the problems concerned suspension in debris-laden conditions. The engineers subsequently made changes that would allow successful performance in the environments in which the original design had failed, and in the cases in which the new design was deployed, 100% remote opening success in over 20 installations to date was achieved. This paper discusses the improvements that were made to address: The opening of the remotely-activated FLIBV in debris-laden conditionsThe testing conducted to prove that the changes would provide a more reliable product that could operate after being suspended in the debris-laden conditions.
Case history data will be presented to illustrate the success of the enhanced remotely opened fluid-loss device.
Lower Completion Type Comparisons: Longhorn Deepwater Case Histories
Authors: Sanford J.R.. R. , Flanagan E.J.. J. , Mancini C.. , Bruton J.. , Woomer J.D.. D. , Franklin B.. , Hebert L.. 
Published: February 2011

Abstract
Selecting a lower completion method is often difficult to evaluate because the true time/cost savings is unknown. This is usually due to the lack of an “apples to apples” comparison. Five (5) wells and four (4) different lower completion types were performed in the Longhorn development (All were performed in the same pressure/temperature regime, similar depths and utilized the same rig). This paper will review the lower completion case histories of this development. The completion types included a conventional single (2 trips), a 1 trip system, a conventional stacked pack (2 zones) and a multizone single trip system (2 zones).
This paper will review, compare and document four (4) different lower completion types. Application of the results should help every completion engineer; answer the question “What lower completion method should I use?” The following time savings, normalized with no non-productive time, were as follows: ❖One trip savings was 1½ days less than a conventional single (2 trips).❖Multizone Single Trip Systems (MST1) (two zone) was only 0.5 day longer than a conventional single (1 zone) which is equivalent to the second zone pumping time.❖MST time savings was four (4) days less than a conventional stacked pack (two zones).
Choosing the correct completion technique is the primary objective of every completion engineer. Understanding the risks and costs associated with each completion type is essential in performing this task.
Leveraging Innovative Technologies to Recover Reserves in the Bakken Formation
Authors: Lloyd W. B. , Starkey A. A. , Jany J. D. 
Published: February 2011

Abstract
The Bakken formation in the Williston Basin has received increasing recognition over the past five years due to the ability of operators to consistently deliver wells with prolific production results and extraordinary economics. This has been made possible by the steady advancement of technologies associated with drilling and completing horizontal wells in addition to the majority of the wells being located in the core of the formation where reservoir pressure gradients are at their maximum.
The magnitude of the Bakken formation means that the majority of the acreage is considered intermediate or outlying from the core presenting the challenge of making the normal pressured reservoir in these areas economically viable. This paper presents a unique combination of drilling optimization with advanced open hole, multi-stage fracturing system (OHMS) technology, which together are pushing the envelope for continued improvement in operational and production efficiencies.
This paper will present directional drilling advantages and artificial lift benefits using rotary steerable technology and advancements in OHMS allowing increased stage density for production optimization. Through the proper implementation of these leveraging technologies, the time to drill and complete a well in the Bakken has been reduced and fracture stage density has been increased over current standards igniting a continuing trend to increase stage density in the Bakken formation as a result of significant gains in sustained recovery.
This systematic approach to streamlining the drilling and completion programs has resulted in notable improvements in the economic metrics for the play. The technological progress presented has resulted in a dramatic shift in the industry in terms of drilling and completion in the Bakken formation and the techniques described can be adapted and applied in virtually any resource play.
Application of Inorganic Whole Rock Geochemistry to Shale Resource Plays
Authors: Wright A. M. , Spain D. , Ratcliffe T. K. 
Published: February 2011

Abstract
In recent years shale resource plays have become increasingly important. However, understanding the controls on reservoir quality in shale formations is still in its infancy, despite thousands of well penetrations. Using examples from several shale resource plays, including the Haynesville, the Eagle Ford and the Muskwa formations, this paper demonstrates how inorganic whole rock geochemical data that are primarily obtained to provide stratigraphic correlations can be used to model mineralogy, model TOC, determine paleoredox facies, recognize zones of biogenic silica and aid with sequence stratigraphic interpretations.
The primary application of whole rock geochemical data to date has been providing stratigraphic correlation based around changes through time in elemental composition, i.e. chemostratigraphy. Stratigraphic correlation is of paramount importance for temporally and geographically constraining other reservoir characteristics. In addition to classic chemostratigraphy, the whole rock geochemical data provide information about terrigenous inputs, which can be used to help elucidate transgressive – regressive cycles and thereby help with understanding sequence stratigraphic correlations.
Reservoir quality in shale is dependent largely on mineralogy. Major element concentrations determined for chemostratigraphy can be used to model most mineral phases, including quartz, clay (semi quantitative abundance of kaolinite, illite and chlorite), calcite, dolomite, feldspars, pyrite and apatite. By adding select trace elements, typically U and Ni, the TOC contents can also be modeled. Furthermore, it will be demonstrated how by combing SiO2 concentrations with elements derived from terrigenous sources, it is possible to recognize zones where biogenic silica is present.
Paleoredox plays an important role in determining TOC values. Consideration of redox-sensitive elements, such as V, Ni, Th, U and Mo provides a means to determine the degree of anoxia during deposition. Using examples from the Haynesville Shale, it will be shown how anoxia is determined and how it varies laterally within the basin.
The methodologies shown in this paper are readily exportable to any shale resource play. The results can be generated from core, side-wall core and cuttings samples, providing a rapid, cost effective means to assess shale in a well-bore penetration.
Coping With Surface and Downhole Interference on Tightly Spaced Completions Pads in the Horn River
Authors: DeMong Karl , Fahlman Jeff , Schnell Rod 
Published: February 2011

Abstract
In gas shales the completion process can be described as changing the source rock into productive reservoir rock with the application of a fracture treatment. Successful shale gas operators have been applying technology to shift to drilling fewer wells and getting better coverage of the rock volume with fracture treatments. Overall this approach gets better results with fewer resources than the historic approaches used on tight gas plays. This tactic, however, has led to significant changes in the way work is done in the field. Now operators are consolidating operations from numerous sites into a few larger pads with many wells drilled from the same surface location. This environmentally sensitive approach has yielded far less surface disturbance but created some other consequences as well. The resulting close surface and subsurface well proximity has resulted in new safety, technical and operational challenges. A large part of the completions engineering effort is focused on solving both surface and subsurface issues related to proximity. Apache has recently completed a pad of 16 wells with 274 completed intervals in the Horn River area.
In this paper both surface and subsurface interference issues will be discussed as well as the plans for coping with the interference. Examples of interference situations and recorded downhole pressure communication from the project will be discussed with a focus on how new processes and automated tools such as the newly developed surface safety protocols and a subsurface proximity calculator enhances the planning of operations and the safety of the site.
Apache has developed a subsurface completions proximity calculator to enhance the ability to plan and adjust downhole operations in an environment that may change day to day or hour to hour. The tool collects all the subsurface data and instantly gives a picture of downhole interactions and supports planning to reduce risk. The avoidance of exposure of high pressure operations to other critical lower pressure operations, such as fraccing proximate to drilling or completion interventions, will be outlined.
Economic Assessment of HSE Risk Management and Raising Efficiency of Financial Resources
Authors: Merzlyakova Ekaterina 
Published: February 2011

Summary
In modern world the well acknowledged tool for management in industrial and environmental safety, and occupational health are the management systems conforming to ISO 14001 "Environmental Management System" and OHSAS 18001 "Occupational Health and Safety Management Systems" International Standards.
Amid the increasing competitive ability and global financial crisis, it is very important to be able to assess the efficiency of investments in HSE activities aimed at mitigation of Company’s negative impact upon the environment and personnel.
When developing such a system of economic assessment, the author has analyzed different methods applied for environmental performance assessment and has studied thoroughly the requirements of ISO 14031 "Environmental Performance Evaluation" International Standard.
Based on mathematical and statistical methods, the author has elaborated an HSE performance evaluation system which enables to assess efficiency of HSE activities performed in the company. This evaluation system assumes differentiated approach to assessing all kinds of negative impact on the environment and the personnel of the company with application of input and output cost indicators. In compliance with ISO 14001:2004 and OHSAS 18001:2007 two kinds of impact on the environment and the personnel have been sorted out in Udmurtneft - environmental aspect and hazard to the personnel, correspondingly.
The research paper contains the detailed calculation of efficiency of financial investments in the personnel hazard management "Feral-herd infections" in N company. This hazard is a top priority risk in the company since such infections are located in the region.
High efficiency of the personnel infection risk mitigation activities was proved on the basis of mathematical method and risk mitigation results were demonstrated by the model risk matrix.
Thus the developed HSE performance evaluation system enables to assess the effectiveness of HSE Integrated Management System on the whole and to allocate the financing wisely and implement risk management activities in the most successful way.
Objectives of the research paper: –development of the HSE Integrated Management System efficiency evaluation system which would allow fulfilling several tasks:–optimization of planning the activities and financing;–providing visuality of HSE activity planning and assessment for the management team;–improvement of HSE management system;–providing transparency of HSE activity in the company.
Designing of Complex Information and Control System of the Deposit "Urubcheno-Tohomskoe"
Authors: Zebzeev Alexey 
Published: February 2011

Abstract
The practical use of modern information technologies is an effective way of increasing the operating efficiency of oil-and-gas, which enables to update business processes at all levels of management, production and sale activities. One of the tools to achieve these goals is the complex management information system (CMIS) starting from the local automation equipment of each processing facility and right up to the the automated integration and data processing system (AIDPS) of the company. The application of complex management information systems provides ample opportunities for the mobilization of reserves meant for the reduction in manufacturing and non-manufacturing costs and losses and also at the increase of income of oil- and-gas companies. To implement the necessary functions in Yurubcheno-Tokhomskoe field, the facilities of automated process control systems (APCS) are supplied with certain amounts of automation. To solve the functional tasks, the specialpurpose software tools are used as capable of operation with real time data. Construction of the CMIS system in compliance with the assigned requirements provides the collection of production information to the necessary extent, storage, processing and representation of the information, completion of the applied tasks which contribute to complex engineering evaluations and modeling of production processes and facilities. While designing the CMIS of Yurubcheno-Tokhomskoe field, the controlled facilities were combined on the technological basis as facilities of oil production and reservoir pressure maintenance, oil treatment and transportation, life support and power engineering. In the CMIS structure the second level of APCS is implemented for operational dispatcher control over the production. The AIDPS accumulates information from lower levels of the automation in real time and converts them into meaningful production events for the further analysis. The basic performance indicators of an enterprise, which are positively influenced by the CMIS application mainly include the increase of efficiency and reduction in production costs. Decrease in cost of production refers to all types of costs: raw materials, energy carriers, human resources, etc., and it is conditioned by an accurate production planning which enables to optimize the use of all the enterprise resources. Increase in efficiency is mainly resulted from improvement of workflow, in particular the planning process, paperless production management, more effective preparation of accounts, elimination of doubling during data access, etc. The CMIS application also provides increase in the enterprise prestige and improvement in the quality of production, emergency situation prevention, production and environmental safety.
Technical and Economic Strategy in the Scale Deposition Management is an Important Factor in Enhancement the Efficiency of Oil Production
Authors: Voloshin Alexander , Ragulin Viktor , Neviadovskyi Evgenii , Ganiev Ilgiz 
Published: February 2011

Abstract
The deposition of inorganic substances that accumulate in the Electric Submersible Pumps (ESP′s), tubing, and piping systems, equipment for the collection of oil is a significant complicating factor in oil production. The practical results of scale management was shows that the cost of prevention scale deposition is ten times less than the financial cost to remedy the effects of scaling.
This paper presents the main provisions of the technical and economic management strategy scaling in the West Siberian oil fields Rosneft, are the criteria for selecting technologies to prevent scaling, implemented in the form of matrices and patterns, as applicable, developed an integrated approach based on the identification of “bottlenecks” in the full cycle of oil production: from the producing formation to the processes of the oil. Depending on the degree of salt saturation of formation water, oil sold technology, offers a range of technologies to combat scaling - from simple, traditional methods of protection to more complex integrated treatments. It is shown that the implementation of such an approach leads to a significant reduction in costs due to the problem of scaling.
Mayskoe Oil Field Tymen Suite Tight Sands Reservoirs Development Strategies
Authors: Naymushin D. , Popov A. , Klimov A. , Martynov A. 
Published: February 2011

Resume
So called “classic” type reserve (reserves are developing by traditional ways - by using regular waterflooding patterns and without huge quality of reservoir stimulation or enhance oil recovery actions) depletion throw down a challenge to oil production companies including in production “tight reservoirs”. “Tight reservoirs” is the term commonly used to refer to reservoirs contents in heterogeneous of permeability deposit (with alternation of it), are contented water in cross section, with gas cap etc., and however, liberal share of it is a low permeability reservoir. This type of reservoirs recovery require from oil production companies apply additional, often not standard and as a rule expensive decisions for achievement profit oil recovery factor. In this article review so type reservoirs development strategies is made by the example of Mayskoe oil field (Tomsk region). For Imperial Energy Company this task is very actual because half of all reserves in Company are tight reservoirs with permeability near 1 mD, this factor explains interest of it in developing this type of reserves.
Bottom-Hole Formation Zone Treatment using Monofuel Thermolysis
Authors: Graifer V. , Kokorev V. , Orlov G. , Bugayev K. 
Published: February 2011

Abstract
The paper sets forth some major aspects of the bottom-hole formation zone treatment with the use of monofuel thermolysis.
The bottom-hole formation zone treatment using monofuel (MF) thermolysis refers to thermal and gas chemical enhanced oil recovery. It is an effective combination of heat and chemical monofuel combustion products; their integrated effect results in the following: –improvement of lithological bottom-hole formation properties as a result of heat treatment and creation of pressure impulse attributing to the removal of asphaltic tar paraffin depositions (ATPD) and fracture formation.–oil viscosity decrease resulted from heat effect and monofuel thermolysis products;–lowering of surface tension at the interface of displaced and displacing fluids and improvement of rock surface wettability.—decomposition of chemical agents under the temperature effect producing gases and other substances which increase displacement efficiency;—formation of water-, gas-and-oil emulsions and foam systems in highly permeable zones resulting in leveling the displacement front and increasing involvement of heterogenous formations into the oil recovery process.
Principally MF represents the solution of combustion agents and oxidants according to the general pattern: “oxidant + combustion agent + solvent”.
The MF advantage is the following: it requires no solution related to propotional dosage and allows control of heat and gas effects by simple methods. In addition it considerably increases allowables for oil formation depths to be treated due to the possible injection of liquid monofuel by high pressure pumps. The injection pattern is single flow. It reduces accessories, and the number and range of the equipment used.
As a monofuel the technology uses water solution of cosoluted nitrogen containing compounds, one of which if fuel, the other - oxidant.
MF decomposition in the fluid is a number of redox reactions yielding the following end products: Water H2O-steam, nitrogen N2, carbon dioxide CO2 and ammonia NH3.
Water is the solvent and reaction product. It changes to steam in the process temperature conditions. The change consumes some energy produced in MF thermal decomposition and oxidation.