bluuebunny/crossref_metadata_2025_split huggingface dataset:
Use of Liquid Resin to Enhance and Maintain Conductivity in Fractured Wells Better Than Use of Curable Resin Proppants: A Case from Burgos Basin
Authors: Araujo Oscar , Rodriguez Levi , Lopez Elias , Bailon Leonel 
Published: May 2012

Abstract
Burgos is the first major unassociated gas basin in Mexico. It covers an area of 50,000 km2 and contains complex, sandstone reservoirs, which are highly compartmentalized and made up of several small, independent blocks characterized by low permeability. This basin is considered a tight-gas reservoir. Sustaining a high production level in this area requires a large number of wells to be drilled and hydraulically fracture stimulated. Historically, the initial well productivity is high, but declines quickly. This phenomenon seems as if it could be associated with the loss of fracture conductivity shortly after the well is put on production.
Proppants that are factory coated with a partially cured resin, generally referred to as resin coated proppants (RCPs) have been used in the industry to reduce proppant flowback and to improve fracture conductivity. A more recent methodology is to coat proppants on location using liquid-resin systems (LRSs). This method uses a specific type of hydrophobic material to resin-coat proppants, and has often been used in the industry specifically to prevent post-frac proppant flowback. The proppant is coated on-the-fly on location with the LRS material. This technology has also proven to both initially increase and also to better sustain fracture conductivity over time. The use of liquid resins for proppant coating in the Burgos basin to enhance and maintain conductivity in several fields has shown to lead to better well performance than when using the factory-coated RCPs.
Production data from a LSR treated well after almost two years of production is presented and compared to a well with similar petrophysical characteristics completed in the same productive block in the same formation using the same volume of a RCP type proppant.
The similar conditions initially present in these wells will forcefully support the superior behavior of LRSs when compared to conventional RCPs when placed using identical treatment designs.
How to Meet "Zero Discharge" Goal in a Sensitive N. Azadegan Field Wetland Environment?
Authors: Rong Li , Yaping Feng , Yunzhang Zhou , Deyin Yang , Zhi Jiang , Guoqiang Bi 
Published: May 2012

Abstract
North Azadegan field with more than 4,886MMSTB reserve to drill 58 wells in less than 3 years, operation area with average about 2.5m water depth, belongs to one of International Nature Reserve Conservation Zones faced with a huge environmental challenge. Traditionally onshore operations in Iran, water based drilling mud and its cuttings have been disposed of directly on the ground in unlined pits, because disposal of drilling wastes poses no serious threat to the environment. However, a Zero-discharge goal is required for this sensitive wetland of N.Azadegan field.
This paper shares an overview of how to achieve a zero discharge goal in a remote, rural, sensitive wetland, accompanied with the below applicable methods: 1)Cluster well pad design and construction including waste treatment layout; 2)Generic waste management stream for minimizing contamination; 3) Treatment of drilling cutting waste as pavage for other pads or road construction; 4) Reuse of waste water for mixing mud etc. While contractor's waste management equipment and personnel daily rates add to the drilling operation cost of the project for higher cost ceiling under Buy-back contract, cutting treatment and mud reuse techniques actually reduce total N.Azadegan project cost, combined with careful planning, advanced equipment and services. This paper will report the past experiences and lessons of these waste management methods in N.Azadegan. In details, the waste treatment and management technologies integrated with well pad construction will be evaluated feasibly and economically.
An Innovative In-situ Natural Gas Lifting Approach to Produce High Pour Point Oil with High Output: A Case Study
Authors: Tang Xueqing , Li Guocheng , Yu Keqiang , Cai Bo , Wang Ruifeng 
Published: May 2012

Abstract
This paper demonstrates an innovative in-situ natural gas lifting approach, which has been successfully applied in AG pool of FN field, Sudan. AG pool is a series of edge water driven stacked sandstones with light oil and natural gas pools, and mostly natural gas zones are below oil zones. AG oil is typical of high pour point, ranging from 37 to 57 Celsius degree. Possibility of wax deposition posed great production and operational challenges at 27 Celsius degree surface temperature. Gas below oil pool could serve as in-situ gas lifting to boost production and reduce wax deposition. This process undergoes tubing produced natural gas flowing simultaneously into annular to lift oil production in the same wellbore. This process has been optimized by following approaches: 1) establishing screening criteria of qualified gas and oil zones for lifting; 2) Partial completion and reduced perforation density in gas zones for controllable gas rate; 3) Separators deployed to remove portion of gas for smooth transportation to facilities.
4 producers have undergone in-situ gas lifting since 2009, average well output achieved 2 to 4 times of DST rate, amounting to 2000 to 4000 BOPD with low water cut. Up-efficiency has been above 85% without wax deposition problems. Operational costs were greatly reduced. Conclusions drawn from successful in-situ gas lifting application were:1) selected oil and gas zones fully qualified for gas lifting; 2) optimized in-situ gas lifting brought high output and low water cut; 3) innovative wellbore structure and facilities design replaced the use of pumps and saved costs.
Sudan is abundant in stacked oil and gas pools with high pour point, therefore in-situ gas lifting has wide applications.
Successful in-situ gas lifting in this paper highlighted significant oil rate gain without oil gelling problems, cost-effective wellbore structure and facilities design, give a staircase for future wider applications.
Journey of Hydraulic Fracturing Improvement to Increase Oil Recovery from Sandstone Formation in Rimau Block
Authors: Priyantoro Tri A. , Prakoso Noke F. , Kahfie Rizky M. 
Published: May 2012

Abstract
A hydraulic fracturing stimulation campaign has been successfully conducted in Rimau block. The stimulation was applied in tight KTLS sandstone formation with permeability within the range of 5-10 mD and also conducted in medium permeability multilayer LTAF sandstone (&gt;10 mD) to bypass nearby wellbore damage.
The purpose of this paper is to share best practices and lessons learnt from the hydraulic fracturing campaign, which commenced in 2003. The campaign was divided into three stages, with the aim of continuous improvement. The first stage was conducted in 2003, when a trial with a generalized design was conducted. Later, the second stage was conducted during the period 2004-2009, when a hydraulic fracturing campaign with improved design was carried out. Finally, the third stage was conducted from 2010-onwards, when the campaign was improved by emphasizing operational excellence and technological diversification.
Beginning with Stage 1, hydraulic fracturing was performed in 13 wells in KTLS using typical fracturing design. An increase in production from each characteristic of formation was observed. Following the success story of Stage 1, a campaign was conducted in Stage 2 by proposing a plan of development for 50 wells to generate an optimization of the fracturing design. Stage 3 consisted of performing further optimization through technology diversification to overcome pressure depletion and operational collaborations. Furthermore, fracturing was also applied to higher permeability sandstone formations to bypass nearby wellbore damage.
The continuous improvement during all stages resulted in an increase in oil recovery of 10 to 25% in tight formation and 30% in higher permeability formation, with an oil gain ranging from 80-500 BOPD and a typical yearly decline of 40%. In the future, hydraulic fracturing will be applied to face further challenging conditions, such as tight gas, tight oil and shale gas.
Simulation and Visualization of Near-Well Flow
Authors: Valsecchi Pietro , McDuff Darren , Chang Dar-Lon , Huang Hao , Burdette Jason , Long Ted , Karmonik Christof 
Published: May 2012

Abstract
The ability to understand and optimize the exact circumstances by which fluids enter the wellbore is increasingly crucial to achieving effective and economic production. The well completion, the connection to the reservoir, must be designed and operated in accordance with the true physics of the near well flow environment. The ability to visualize such flows, then parameterize and extrapolate the results with realistic simulation models, affords a powerful advantage in creating well completions that are simple to install, reliable to operate, and, of course, deliver all the flow the reservoir is capable of yielding. This paper illustrates the use of advanced visualization in this process. Two examples are presented, featuring detailed images of flow through complex sand control completions hardware (gravel pack) and of flow through wormholes in acid-stimulated carbonate rock.
For the first case, a new approach is presented for the non-invasive visualization of flow patterns in a modeled a gravel pack completion using magnetic resonance imaging (MRI) with a whole-body clinical 3-Tesla scanner. Advanced MRI pulse sequences for structural imaging and for flow visualization were utilized to measure flow velocities in the gravel pack model. Its geometry was then visualized by three-dimensional surface reconstruction methods and the highly resolved three-dimensional velocity field allowed for the calculation of flow streamlines through the entire completion. Thus, the effect of each component of the completion can be fully characterized and a redesign of the completion hardware targeting flow optimization can be envisioned. Beyond the importance of opening a novel window on the fluid dynamics research of completion hardware, this application also demonstrates a successful technological synergy between the energy industry and the medical research, as well as a recognition of the value of the Pumps and Pipes workshop with the Methodist DeBakey Heart & Vascular Center, under which this interdisciplinary collaboration was originated.
For the second case, a combination of experimental, imaging, and computational modeling techniques is employed to better understand the structures and fluid flow impacts of wormhole networks formed during carbonate matrix acidizing. Large-scale acidizing experiments have been conducted on quarried carbonate rock samples including variation of several system characteristics such as completion type, saturating fluid, rock type, and acid injection rate. Here, a subset of these experiments are referenced to explain the process of obtaining detailed digital visualization of the internal void space structure formed during acidizing. The discussion then extends to utilization of this digital image data for Computational Fluid Dynamics (CFD) modeling of fluid flow associated with the wormhole networks.
Study of Kinetic Hydrate Inhibitor Removal Efficiency by Physical and Chemical Processes
Authors: Hussain Altaf , Gharfeh Samir , Adham Samer 
Published: May 2012

Abstract
Kinetic Hydrate Inhibitors (KHI) is added to the produced fluids in oil and gas fields. Hydrate formation is a major flow assurance issue and the petroleum industry spends millions of dollars annually in this area. Kinetic inhibitors act as anti-nucleator and delay the formation of gas hydrates. The advantages of these chemicals that they are more economical and added at a low dosage without disturbing the pipeline flow. Globally, different proprietary KHI compounds are used in various locations. One specific KHI was used in the present work. Considering that produced water containing KHI may have negative impact on the environment during discharge, efficient treatment solutions to remove KHI are needed. The objective of the present laboratory investigation is to address the various treatment methods, namely membrane process and advanced oxidation process for removal of KHI. These treatment processes have huge potential to be implemented in the oil & gas industry for environmental sustainability.
Membrane processes based on Ultrafiltration (UF), Nanofiltration (NF) and Reverse osmosis (RO) were investigated using synthetic produced water containing KHI. The experiments were carried out using a bench scale membrane unit. The removal efficiency of KHI was found to be greater than 99%, 99%, and 83% for RO, NF & UF membrane, respectively.
The chemical process based on ozonation was also investigated. The ozone effectively degraded 75% of KHI polymer with ozone dosage of 0.73 g/h. The extent of oxidation of KHI is dosage/time dependent. To the author's knowledge, this is the first work reported in the literature regarding KHI removal by membrane technology and advanced oxidation.
Integrated Production Operation Solution applied in Brown Oil Fields - AIATG Asset PEMEX
Authors: Diaz G.. , Mena E.. , Mota M.. , Yañez J.. , Castrejon R.. , Lombardo L.. 
Published: May 2012

Abstract
This paper presents the advances in the Integrated Production Operation Solution applied in Brown Fields from Activo Terciario del Golfo (AIATG) Asset PEMEX, located in The north-east of Mexico. AIATG has about 3377 wells, 2112 are producing, 948 of them in natural flow, 1164 in different artificial lift methods, and the remaining are closed. The total production is about 65004 BPD of oil and 149 MMFCD.
Operational issues like, lack of well test event, poor well test by well, facilities constrains, production measured in conjunction with others sources, in combination with dispersion data the problems create a not trusty environment to detect abnormal conditions and events that impact directly in the production.
In order to improve this process, AIATG has raised a new approach which allows consolidate the operational data base, to implement workflows for capturing from different sources daily production and operational data along the entire production network and facilities, and which will include engineering and smart validation rules and alarms notification across web environment, which this will permit to act in advance before a potential issue become in production loses.
Additional features for trend analysis, visualization and management of key performance indicators will be integrated with engineering workflows, which the automatic recognition of issues and behavior of wells using calculated rates at the well level and their reconciled production compared to the measurement at the gathering station level. With this automatic workflow we can then identify any condition that has drastically affected well productivity.
Conquering Complexity And Human-Centred Design
Authors: Dennant Andrew , Perry Dale 
Published: May 2012

Abstract
All of our lives are becoming more complex. We are expected to deliver more, more quickly, and more accurately, and technology is claimed to be the enabler for us to achieve this. Nowhere is this truer than in the process industries, where there are additional pressures such as increasingly large plants and retiring workforces. The authors believe that the key to meeting ever-raising expectations is to reduce complexity, and that this can be done in two major ways. First of all, Process Operators must implement modern technologies that are inherently simpler. And Secondly, Vendors must design the complexity out of their devices and user interfaces.
Plants are getting larger all the time. What would have been a complex a few years ago is not a single plant. And a plant that would once have produced a single product is now expected to produce a variety of products to a variety of quality specifications. At the same time the expertise that has learned how to run the process, to understand root causes of production problems; the people who can look at a few indicators or simply listen to a pipe or column and understand conditions, is retiring at an increasing rate. They are being replaced by the "Google Generation" – a generation of graduates who believe that anything can be learned in ten minutes via the internet. These people do not understand the complex interactions between control loops and process conditions and, in many cases, do not even understand the fundamentals of process automation. Why learn how a PID works and how to tune it when there are function blocks and auto tuning routines that can do it for you? And even when new workers are hired, there tend to be fewer of them than there were before. Why is this? Because we rely more and more on technology to optimise our plants, to replace the tribal knowledge that is being lost to retirement, and provide us with insight that allows us to tighten up our control loops for quality or optimization purposes. And there's nothing wrong with that. So long as the vendors make sure that the technology really delivers that optimisation and insight.
The answer is to reduce complexity in the first place, so that we spend less time doing complicated work that adds no value. The way to do this is to apply the right technology to the problem in hand, and we will go through three examples of how technology can help with this. The next thing to do is to remember that we are people first, and people who have specific tasks to perform. Therefore we must ensure that the tools we have to perform a given job are aimed at simplifying the tasks that make up that job. We must wrest control of the user interface from the engineers and hand it to the ergonomists.
Flawless Turnaround
Authors: Roebers Jacob 
Published: May 2012

Abstract
Flawless Turnaround© complements existing optimisation elements (such as: scope & schedule optimisation and Turnaround Assurance Reviews) and facilitates continuous Quality delivery improvement by bringing increased rigour and emphasis to both, the operations and maintenance function. It is a fully integrated and proactive method designed to reduce the occurrence of all potential turnaround flaws.
The main elements are: SystemisationSystemisation is the process of breaking down the asset in smaller pieces. This process goes deeper than breaking down to a unit based approach, which is quite common in the industry. The unit will be cut in smaller pieces (systems). The systems will be identified prior to the event and all systems will become part of the integrated Turnaround schedule. System handover (from operations to maintenance and v.v.) will become part of the fully integrated schedule, that includes all activities; operations, maintenance execution and projects.FlawlistingTo help the organisation capture potential flaws that might take place during the execution of the Turnaround, a strict process will be put in place to try and prevent these flaws from happening. Specific Key success areas, e.g. Tightness and Cleanliness, will be identified prior to the event and focal points will be assigned for these areas. The focal points then take a leading role to identify and capture possible flaws and find mitigating actions to prevent these flaws.Rigorous Quality Assurance ProgrammeTo ensure that the execution of the work has been done ‘right first time’ a comprehensive QA/QC process will be put in place. This process will be a joint activity, both by client as well as the contractor. Inspection and Test Plans (ITPs) will be developed with proper hold and witness points.
Flawless Turnaround© is a programme designed to help you achieve sustainable steady-state performance safely, quickly and within budget.
Evaluation of Membrane Processes for Acid Gas Treatment
Authors: Jahn J.. , van den Bos W. A. , van den Broeke L. J. 
Published: May 2012

Abstract
An overview is given of different membrane processes that are used for acid gas removal from natural gas. The main characteristics of selective membranes and membrane contactors for gas separation involving mixtures with acid gases are discussed.
The removal of carbon dioxide from gaseous streams and solvents at elevated pressures is relevant for a number of applications. This includes processes like pre-combustion capture, with the main focus on the separation of CO2 and H2 mixtures, and natural gas treatment, where CO2 is removed from CH4.
A comparison is made between the CO2 flux obtained for different types of membrane processes. A comparison is made between values for the CO2 flux obtained for the regeneration of absorption liquid diethanolamine (DEA) using a gas-liquid membrane and values for the CO2 reported in the literature for selective membranes.
Experimental results for the regeneration of a chemical absorption liquid loaded with CO2 using a gas-liquid membrane contactor are presented. The absorption liquid DEA has been loaded with pure CO2 for three different CO2 pressures. The CO2 flux from the pressurized liquid phase to the gas phase has been determined for different pressures at the gas side of the membrane contactor.
Acid Placement: An Effective VES System to Stimulate High-Temperature Carbonate Formations
Authors: Gomaa Ahmed M. , Cutler Jennifer , Qu Qi , Cawiezel Kay E. 
Published: May 2012

AbstractThe gelling performance of VES acid systems dramatically weakens at high temperature. Therefore, these fluids are typically limited to placement in relatively low-temperature carbonate formations. This study was conducted to introduce a new VES system that can gel and maintain useful viscosity up to 300F.The new surfactant system is completely compatible with HCl, brine, and even high iron contamination. Rheological studies defined the operational temperature limit where viscosity was sufficient for the new VES system to be used successfully as diversion agent. It was found that initial acid concentration and the degree of acid neutralization were critical parameters affecting the new VES system diversion performance at elevated temperatures.The effects of four corrosion inhibitors were examined. One is recommended for use with this system because it minimizes negative effects on the operational temperature range. Also, it enhances the values of elastic modulus, which enhances the VES system's diversion performance.Coreflood studies using limestone and dolomite cores confirmed that the new VES system increased differential pressure sufficiently to achieve diversion. For limestone cores, the pressure drop increased by a factor of 10 during VES acid injection; for dolomite cores, the pressure drop increased by a factor of 100. The pressure drop changed in a cycling manner, where the crest and trough of each cycle increased with time. Cycling of the pressure drop indicates that the acid was able to change its direction inside the core. Coreflood testing also indicated that there is no need for a breaker, as 18% permeability enhancement was observed with CaCl2 brine flowback. This paper will discuss the results obtained and recommend the conditions under which the new system is most likely to be successful in the field.
Material Selection for Threaded Instrument Fittings in Topside Offshore Service in the Arabian Gulf
Authors: Barker Peter A , Bech Hans H 
Published: May 2012

Abstract
Austenitic Stainless steel UNS S31600 is used for instrumentation items on topside production facilities worldwide. Stress corrosion cracking and chloride pitting have caused failures of such items and solutions to prevent leaks and material failures must be found. This paper will detail inspection results, failure analysis, including measurement of stress and strain induced by tapered fittings and make recommendations for material selection and remedial actions.