bluuebunny/crossref_metadata_2025_split huggingface dataset:
Study on Mechanism of In-Depth Fluid Diversion by "Gel Dam" Placed with Horizontal Well Using X-ray CT
Authors: Lv Jing , Liu Yuzhang , Gao Jian , Li Yikun , Wei Falin , Li Junjian 
Published: March 2015

Abstract
Due to severe heterogeneity of thick positive rhythem reservoir and the gravity influence, the injected water channels and ineffectively cycles through its lower high permeability zones. For the whole reservoir, its sweep efficiency is relatively low and a huge amount of residual oil is enriched in its upper low permeable zones. The technique of in-depth fluid diversion by "gel dam" placed with horizontal well involves the injection of gel by horizontal or sidetracking wells drilled between the injection and production wells in the lower more permeable and strongly swept zones of thick positive rhythm reservoir, creating" gel dams". The injected water then will bypass the "gel dams" and be diverted into the upper low permeability zones where crude oil is relatively enriched. As a result, the sweep efficiency and oil recovery of the upper, low permeability zones can be both increased. In this paper, the EOR mechanism of the technique is studied by means of laboratory water flooding experiment combined with x-ray computer tomography(C T).
The physical model, an artificial cementing heterogeneous model casted with epoxy resin on surface, is made based on the similarity criteria for water flooding process in 2D porous media. The water flooding processes in the physical model, before and after the "gel dam' is formed, are scanned by x-ray C T at different pore volume injected, which provides a visible means for studying the EOR mechanism of the technique, through observing the distribution feature of "gel dam', tracking the oil and water distribution, water flooding streamline's change, fluid saturation distribution and its dynamic variation.
The results of water flooding experiments indicate that, with this technique, the injected water is diverted into the upper low permeability layer to displace the remaining oil therein, and the sweep efficiency and oil recovery both increase significantly. After the "gel dam" formed, the ultimate oil recovery increases by 16.7%, its water cut falls to 62.8%, and its ascending velocity slowed down.
With" gel dam" technique, gel can be placed in the deep reservoir zone to achieve in-depth fluid diversion. It will be a promising EOR method for thick positive rhythm reservoir.
Recent Advances in Oil Spill Response Technologies
Authors: Nedwed Tim 
Published: March 2015

Abstract
This paper discusses recent advances ExxonMobil has made in oil spill response technologies for large spills in dynamic ice conditions; however, much of the work has application in all environments.
We have developed a new dispersant that is effective at much lower dosages than currently available products. For ice conditions, we have developed a concept to utilize the propellar wash of response vessels to supply the necessary energy to more effectively disperse dispersant-treated oil.
In situ-burning has undergone extensive evaluation as an oil spill response option including a multi-year joint-industry research project evaluating a concept to enhance in situ burning in ice using chemical herders. Recent research indicates that chemical herders can also enhance in situ burning in open water. In addition, we have initiated research on a novel concept to use oleophilic skimmers in conjunction with mini floating incinerators to allow immediate in situ burning.
We are also studying tools to enhance our ability to remotely detect and track oil slicks on the water surface as well as underneath ice. For oil under ice, we have been studying the use of a helicopter-mounted nuclear magnetic resonance sensor to detect, track, and map oil location and relative density. We are also studying methods to detect and determine the thickness of oil slicks using remotely controlled helicopters.
The Controlled Freeze Zone Technology for the Development of Sour Gas Resources
Authors: Valencia J.A. , Kelman S.D. 
Published: March 2015

Abstract
Controlled Freeze Zone™ is an efficient single-step cryogenic distillation process for the removal of carbon dioxide, hydrogen sulfide and other impurities from natural gas. Rather than avoiding the freezing of CO2 at cryogenic temperatures, the solidification is allowed to take place, albeit in a very controlled fashion. The technology has shown the potential to more efficiently and cost-effectively separate carbon dioxide and other impurities from natural gas, and to discharge these contaminants as a high-pressure liquid stream ready for underground injection, either for enhanced oil recovery applications or for acid gas injection disposal.

Introduction
Natural gas is the cleanest burning hydrocarbon fuel available and its growing demand is only projected to rise throughout this century. ExxonMobil anticipates total global energy demand to grow 35% by 2040 relative to 20101. Greater demand for electricity accounts for more than half of this increase. The clean burning characteristics of natural gas and its increasingly competitive economics for power generation are driving its expanded use in electrical power generation. Natural gas emits up to 60 percent less CO2 than coal when generating electricity, which becomes quite significant as costs arising from greenhouse gas policies mount. ExxonMobil forecasts natural gas to emerge as the leading source of electricity generation by 2040, and to become the second largest global fuel by 2040 behind oil, displacing coal from the second spot.
Pushing the Boundary of Ultra HP/HT Completion Technology: The First 20,000-psi 470-degree F Permanent Production Packer for As-Rolled Casing
Authors: Doane James , Deng Guijun , Collins Scott , Anderson Gary , Shyu Goang-Ding 
Published: March 2015

Abstract
The growing global demand for hydrocarbons is the key driver for the development of high-pressure/high-temperature (HP/HT), and ultra HP/HT completion technologies. However, well completion of ultra-HPHT fields poses great technological challenges to the operator and service companies. Existing completions technology is reaching its design limits around 15,000 psi and 450°F.
As operators continue to drill in deeper and more extreme formations, the technology demand to suit these environments has steadily increased. Great efforts have been made across the industry to develop safe and reliable completion tools qualified for conditions in excess of 15,000 psi and 450°F. A new technological boundary was set recently in permanent production packer development?the first 20,000 psi, 470°F permanent production packer for as-rolled casing.
A modified ISO 14310 V3 validation test was conducted on this permanent packer in as-rolled casing ID.
The packer passed the test with no visible seal element extrusion, slip damage, or leaks detected at any of the load points in the test (including the bubble test).
This paper presents how the packer utilizes a novel seal system design that evolved from several field-proven HPHT seal systems and the ways technological challenges are addressed using state-of-the-art materials and design processes. The paper comprises conceptual design, design optimization using finite-element analysis, and material characterization for metallurgical and seal materials. The qualification testing processes for the permanent production packer are also described in detail.
Fibre Optic Sensing for Improved Wellbore Surveillance
Authors: van der Horst Juun , den Boer Hans , in 't Panhuis Peter , Kusters Roel , Roy Dayeeta , Ridge Andrew , Godfrey Alastair 
Published: March 2015

Abstract
Fiber Optic (FO) sensing technology is an exciting and novel technique offering many advantages over traditional wellbore surveillance methods1–3. Multiple FO cables can be installed that can be designed for sensitivity to a wide variety of signals such as temperature, pressure4–5, strain6–7, sound8, and the presence of specific chemical compounds. Permanently installed FO cables enable a cost effective surveillance policy where data acquisition surveys can be conducted without well interventions, in real-time, at any time, and continuous along the entire well bore. The avoidance of well intervention eliminates production deferment and operational risks of conventional surveys. Frequent, time-lapse FO based surveys can provide critical reservoir surveillance data for production and recovery optimization.
One instance of fiber-optic surveillance is Distributed Sensing, which uses the entire fiber as a sensing element. Recently, very good progress has been made in Distributed Acoustic Sensing (DAS) for hydraulic fracturing monitoring9, production profiling for commingled oil and gas producers, injection profiling for water injectors10, gas lift monitoring and the acquisition of wellbore seismic data such as Vertical Seismic Profile (VSP) surveys11–12. These applications are also seen to benefit from integration with other methods such as Distributed Temperature Sensing (DTS) and Distributed Pressure Sensing (DPS). In terms of wellbore surveillance, the possibility to monitor flow along the entire wellbore from FO sensing provides useful insights in the complex flow behavior in a well which can be used to optimize well performance.
There are also many improvements to be made in the enabling Distributed Sensing infrastructure such as the handling and evaluation of very large data volumes and seamless FO data transfer, the robustness & cost of the FO system installation, and the overall integration of FO surveillance into the full workflows. It will take some time before all these issues are addressed but it is clear that FO based applications will play a key role in future well and reservoir surveillance.
In this paper some examples of using DAS for Production Allocation are discussed.
Deep Water Lacustrine Architectural Elements and Subsystems Identified in the Subsurface from Borehole Images - An Example from Weizhou Field, Beibuwan Basin, South China Sea
Authors: Xuan An Xiao , Abu Bakar Mohd Nizam 
Published: March 2015

Introduction
Outcrop work on deepwater deposits often shows mass-flow systems are more complicated and heterogeneous than generally accepted. However it is difficult to recognize the different architectural elements and subsystems in the subsurface at reservoir scales. At a reservoir scale, the finer details of heterogeneity are important for accurate reserves calculation, completion strategies and development well placement.
This paper describes how high-resolution resistivity borehole images are able to identify deepwater subsystems and architectural elements in the subsurface. The study sections consist of four wells located offshore Beiwuban Basin in the South China Sea (Figure 1). Borehole images were recorded in all these four wells. Detailed observations from borehole image logs reveal the occurrence of turbidites, slumps, and debrite facies in a deep-lacustrine setting. Openhole logs could not resolve the heterogeneity and different facies in the reservoir.
Integrating Digital Image Processing and Artificial Neural Network for Estimating Porosity from Thin Section
Authors: Wardaya Pongga Dikdya , Khairy Hilfan , Sum Chow Weng 
Published: March 2015

Abstract
Porosity estimation from thin section image using digital image processing is critical for petrography study since it gives a brief description on the 2D porosity of the sample. The standard routine uses the binarization process that converts the colour (RGB) image into a binary image using pixel value treshold. The idea is that the treshold value must accomodate all the blue regions correlate to pore and turns it into white in the resulting binary image. Errors come from mis-conversion when the matrix is converted into pores and yields larger pore spaces. This error can be larger when dealing with samples having high blue variation, for example; stained carbonate or polarized microscope captured thin section.
To address this issue, an integration of neural network and image processing is proposed to estimate accurately the porosity from a thin section. The neural network, based on color pattern difference between pores and matrix is assigned to segment them by addressing their original pixel value with a targeted code value, e.g.; 1 for pores and 0 for matrix. After the segmentation, pixel counting is then used to calculate the porosity. This method requires the training data which is the cropped region of pores and matrix. In the training process it uses the Lavenberg-Marquadt learning method.
Synthetic samples and bonafide thin sections of sandstone and stained carbonate are used for testing. For each sample the computation time is less than 10 seconds and the error, which is caused by mis-segmentation, is less than 1%. Results from standard image processing technique are also evaluated for comparison. The algorithm can also work for the grey scale image and binary image as such it is suggested that it can work for estimating microporosity in carbonates or coal from SEM image. The proposed method brings new advance in digital petrography and can be an accurate and fast tool for porosity estimation from thin sections. Furthermore, as the neural network algorithm can also segment the multi mineral matrix present in the sample (stained carbonate thin section), the fraction of each mineral constituent can also be estimated.
Architecture and Implementation of an Optimization Decision Support System
Authors: Gobel Derek , Briers Jan , Chin Yee Men 
Published: March 2015

Abstract
This paper describes the implementation of an optimization advisory system by Sarawak Shell Bhd. on the integrated gas production system in Sarawak, to help monitor and optimize in real-time the more than 100 wells on 30+ facilities of the system, governed by different Production Sharing Contracts. We highlight how multiple disciplines are part of the solution, how the solution has been embedded to provide real-time advisory to planners and operators, and the challenges faced. The technology described in this paper provides real-time advisory on flow rates for individual wells and platforms to network coordination operators to achieve a gas supply that meets overall gas demand for the onshore LNG plants, maximizes revenue from condensates production and CO2 blending, and transparently shows the business value impact of giving preference to short- or long-term optimization objectives. It takes into account existing commercial and contractual constraints, as well as financial and economical elements. The optimization approach is data-driven and features multiple, mutually dependent objectives and constraints. The data-driven approach has proven significantly faster and more practicable than prior physical model-based approaches. Field trials have proven a condensate production increase of up to 7,000bbl/d while at the same time improving Ultimate Recovery of the sweet and sour gas blend of the production system by up to 2 months per 'year of applied optimizer advise'. At the same time, gas nominations are met as they were, and commercial and quality constraints are adhered to. The Return On Investment of this solution has been less than a month. This is one of the first successful attempts to implement truly-real-time optimization in a production environment of this size and complexity, including a complicated set of commercial and contractual constraints. The approach opens the door to application to a wide variety of real, complex, mixed-integer non-linear optimization problems, and their organizational application, such as emissions management and decision support systems for integrated IOR/EOR systems.
Evaluation of True Formation Resistivity Derived from the Dual Laterolog-Rxo and the Induction-Spherically Focused Log
Authors: Mohammed Akram F. 
Published: March 2015

Abstract
The problem of determining whether a Laterolog or an Induction is better suited to measure true formation resistivity (Rt) according to prevalent conditions is reviewed. The question of which deep resistivity device (Laterolog or Induction) should be run in a given well is investigated. To aid with this decision, examples are shown that cover a wide range of cases in both oil-bearing and water-bearing zones.
True resistivity values derived separately from the Dual Laterolog-Rxo (DLL-Rxo) tool2 and from the Induction-Spherically Focused (ISF) Log3 are compared. The comparison helps determine the accuracy of the measurements made by each tool with respect to Rt. This also provides the capability to correct the resistivity values for the invasion to obtain Rt,leading to a more accurate evaluation of water saturation.
Practical applications of both tool types, recorded over a limestone formation in three Middle East wells, are shown for a variety of situations in both fresh and salt saturated mud systems. The responses of the basic deep resistivity devices, deep Laterolog (LLd) and deep Induction log (6FF40), are shown for cases of shallow invasion, moderate invasion, deep invasion, and very deep invasion.

Introduction
Rt (resistivity of the non-invaded formation) is the basic parameter that allows the determination of water saturation (Sw) and formation-water resistivity (Rw). Various types of Laterologs and Induction logs are currently in use to measure the value of Rt. No single logging tool has yet been able to measure Rt under all logging conditions. The deep Laterolog and deep Induction log are both affected in different ways by borehole fluids and the invaded zone. A comprehensive understanding of tool responses is therefore needed prior to processing logs for automatic computation of Rt.
Characterization of Coalbed Methane Reservoirs: A Unified Geoscience and Engineering Approach
Authors: Le Turdu C. , Laver R. , Koley M. 
Published: March 2015

Abstract
Once considered a dangerous nuisance in the mining industry, coal seam gas (CSG), or coalbed methane, is now seen as an abundant clean energy supply that will help replace other diminishing hydrocarbon reserves. The nature of the coal-bearing sequences, however, makes them difficult to drill and produce profitably. Major challenges include multiple thin-bedded zones, strong variations in quality of coals, and large volumes of formation water that must be removed before the gas can flow to the surface.
This paper describes a new technology- and knowledge-driven approach to address these challenges in the exploration and development stages of a CSG field. During exploration, combining multiple data types in a single model reduces dramatically the uncertainty around coal seam distribution and gas-in-place estimation. In field development planning, the unification integrates static and dynamic data to enable a better understanding of the field's producibility.
The exploitation of CSG requires analyses of many scenarios and uncertainties. In addition, it requires hundreds of wells to be drilled in a short period of time. Consideration of the high levels of uncertainty and the integration of large volumes of newly acquired data can be achieved efficiently only in a unified software environment that is associated with a strong knowledge management system. In fact, one of the key benefits of this new unified approach includes the ability to update models and test multiple scenarios at any stage of the field life cycle, and track the processes with a strong audit trail.
Data used for demonstration in this paper are from the Surat basin in Central Queensland, Australia.
Qatar LNG Terminal Flare Gas Reduction Project - JBOG
Authors: Mirza Bashir 
Published: March 2015

Abstract
Qatar produces 77 million tonnes of LNG per annum, and is the largest provider of this clean energy in the world. The world's largest man made harbor in Ras Laffan City, located 80km north of Doha, has six LNG loading berths. During loading of the liquefied natural gas in the special LNG ships, a portion of the minus 160oC liquid boils off as it comes in contact with the warmer ship tank. This boiled off gas is currently being flared at the berth because there is no outlet for this low pressure gas. The average flow rate of the boil-off gas is 100 mmscfd, which has the potential to produce around 750MW of power.
In line with Qatar's National Vision to produce and supply clean energy to the world, Qatar Petroleum and the Ministry of Environment decided to recover the flared gas at the LNG berths to the maximum extent practical. This intent gave birth to the Jetty Boil-off Gas Recovery Project in 2007. A Pre-FEED design had been done by RasGas, and the project was handed over to Qatargas in June 2007.
The JBOG Project when fully implemented will save the emission of 1.6 million tonnes of carbon dioxide into the atmosphere. One trillion cubic feet of gas will be saved for the State of Qatar over a period of 30 years.
The design of this project encountered many challenges.
The gas is discharged from the ships at a pressure of less than 1 Bar Gauge Pressure (BarG).The volume of the gas to be recovered is several times higher than at any other similar facility in the world.Gas is discharged at -100oC, making all facilities cryogenic.No provision had been made for space allocation at the harbor for Boil-off Gas Recovery facilitiesCheck valves and buckling pin valves' design and operating experience was not available for the large flow rates, low pressures and cryogenic temperatures.No space was available at the berths to locate the compressors, as designed in the Pre FEEDLimited space available inside the port for JBOG main facilities.Most of the facilities were going to be in brownfield areas, in close vicinity of live hydrocarbon-n carrying lines.Lack of accurate and up to date as -built drawings for brownfield facilities.
The Qatargas JBOG Project Management Team (PMT) brought in experts from the shareholders and addressed each of these challenges through innovation, extrapolation and a strong determination to succeed.
The Front End Engineering Design (FEED) was awarded to Fluor Daniel in Houston, USA in late 2007. The FEED teams from Qatargas and Fluor produced a basic design package by Q3 2008. In the days of $150 per barrel oil prices, the cost estimate ballooned. Qatar Petroleum took a wise decision, and delayed the final investment decision by a year to let the markets cool down.