bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pipeline Corrosion: Its Remote Detection and Corrosion Management
Authors: Sinha Manish Kumar 
Published: December 2007

Abstract
The recent failure of a buried onshore 18C" refinery pipeline coated with FBE recites the ferocious consequences of corrosion problem. Situation will be even worrisome in case of marine environment where the entire aquatic life will be endangered. The critical zone prone to severe corrosion in offshore is transition area between riser thick coatings & atmospheric paint system where accelerated corrosion may occur.
ISO 13623 established by ISO TC 67/SC2 deals with the design, construction, inspection and maintenance of pipelines used in oil industry. Corrosion management includes evaluation of corrosion, corrosion prevention, corrosion monitoring, periodic inspection & re-qualification of the pipeline& tubing.
Intelligent Pigs and Remote Sensing Equipments can be used for estimation of corrosion. Intelligent pigs give the inner profile of the pipeline and run from one end to the other, however are costly affairs and are avoided. Remote sensing equipment essentially consists of infrared camera, video camera, laser spectrometer and global positioning system. Simulation of the readings gives the insight of the pipeline corrosion status and location of leakage. Working principle is temperature diminution, transmittance and thermal contrast of oil spot.
Comparison of Various Approaches to Near-Surface Impact Correction for Seismic Data Obtained in Permafrost Environment
Authors: Kuznetsov V. I. 
Published: December 2007

Abstract
The main gas condensate and oil bearing fields are concentrated within the polar area of Western Siberia. The target depth varies from 900 m for Cenomanian gas deposits up to 4000 m for Upper-Middle Jurassic oil, gas and gas condensate sediments. The target structure is very complex that is why 2 and 3D seismic survey is required to explore the fields. However, seismic survey is complicated by environment.
Efficiency of Bottom-Hole Heaters for Gas Hydrate Dissociation
Authors: Bondarev Edward , Popov Vasili 
Published: December 2007

Abstract
Studies presented in [1] show that during gas production from the fields located in the permafrost regions intensive hydrate formation occurs in the bottom-hole zone. The process begins from the moment of bringing well into production, and approximately in 100 days all free water transforms into a hydrate. As a result, well productivity within this period reduces to about 20%. One of the ways of well productivity recovery is the use of different types of heaters. The paper presents the evaluation of the above method efficiency. To study the dynamics of hydrate formation and dissociation the modified mathematical model proposed in [1] has been used. During the computational experiment the effect of heating intensity, gas well production rate and permeability of gas-bearing reservoir on dynamics of the formation and dissociation of natural gas hydrates has been studied.
The results of calculations for the intensive heating show that regardless of the distance from a well, rate of hydrate saturation growth and its absolute magnitude significantly depend on permeability and production rate and that hydrate formation occurs in a comparatively narrow zone near wells where all pore water transforms into a hydrate. But this hydrate-free zone is stable during successive gas extraction for a long time. If the heater temperature only slightly exceeds the equilibrium temperature of hydrate formation but its active period is much longer, then its influence is more localized than in the first variant. Moreover, here the size of the hydrate-free zone depends both on gas flow rate and bed permeability.
Efficiency Evaluation of Non-Uniform Upgridding Method Based on Streamlines Approach: Western Siberia Field Example
Authors: Kurelenkov Sergey Kh. , Ryazanov Andrey V. 
Published: December 2007

Abstract
In this work we present the comparative analysis of uniform and non-unifrom upgridding techniques in combination with upscaling methods currently included in commercially available software. Also the efficiency of the new Streamlines-based upgridding method1 as one of the non-uniform upgridding technique was estimated. In the context of the project it was realized (coded). The effectiveness of these techniques is evaluated by their application to the revision process of the reservoir model of the part of "Kp" field of Western Siberia, Russia.
Considered reservoir is highly heterogeneous in vertical direction (permeability ranges from 0.01 to 500 mD). The existing geological model has low vertical resolution (about 1.3 m). The simuation model was upscaled by uniform simple (algebraic averaging) method.
The new geological model (finer in vertical direction) was constructed with the resolution closer to well logs. Several simulation models were constructed by the combined application of different upgridding and upscaling techniques. The model which was the most adequate to geocellular one was chosen.
After that the history matching of the chosen model was carried out. As a result of well done upscaling it was done easier and less time consuming in contrast to the previous model.
The Problem of Scaling and Ways to Solve it in the Oilfields of Rosneft Oil Co.
Authors: Ragulin V. V. , Markelov D. V. , Voloshin A. I. , Matyash S. E. , Mikhailov A. G. 
Published: December 2007

Abstract
Rosneft oil production experience indicates that scaling is one of the most significant factors leading to a fall in the well production rate and to a shorter mean-time-between-failures of well pumps. Deposition monitoring indicates that the share of ECP failures due to scale varies from 12 to 25%.
The various intensity of scaling in wells is related to a different saturation of produced waters with scale-forming ions, water-cut of the recovered fluid, and conditions of submersible well pump operation. In Rosneft wells, sulphate (barite) and carbonate (calcite) scales have been observed.
To efficiently develop most oil fields, it is necessary to select scale inhibitors and preventing technologies taking into account peculiarities of individual wells. Analysis of ionic composition of reservoir and produced waters allowed to determine their saturation with scale-forming ions and to draw up recommendations as to the usage of chemicals, the effectiveness of which must be not lower than 90%, from a wide range of scale inhibitors.
Pilot-field testing and a following large-scale application of scale preventing technologies, i.e. adding an inhibitor to the kill mud, permanent chemical feeding into the annular space of wells, application of submersible well feeding containers, and inhibitor injection into the water injected into the formation allowed to overcome the growing tendency of ECP failures due to scaling in the biggest oil production enterprise of Rosneft – OAO "Yuganskneftegas", and to increase the mean-time-between-failures of submersible pumping equipment by more than twice.
Optimization Development of Sugmut Oil Field Using Horizontal Wells
Authors: Gaponova Larisa M. , Karnauhov Michael L. 
Published: December 2007

Abstract
In the given work the estimation of efficiency of practice of wide application of horizontal drilling on Sugmut reservoir, one of the largest in Russia is presented.
The reservoir is in development of 10 years, significant reserves of oil are concentrated in a water-oil zone. At the first stage of drilling, at realization of three-row system of development by vertical wells there was a problem of nonuniform development of reserves with formation of the centers of active movement of fluids and stagnant zones, effects early water cut wells, annulus overflows were showed.
Monitoring and Optimization of Well Performance in Rosneft Oil Company-The Experience of the Unified Model Application for Multiphase Hydraulic Calculations
Authors: Khasanov Mars , Krasnov Vitaly , Pashali Alexander , Khabibullin Rinat 
Published: December 2007

Abstract
This article presents the experience of the application of the unified mechanistic model for multiphase flow hydraulic calculations in the wellbore for the means of monitoring and optimization of producing wells performance in Rosneft Oil Company.
Development of Multiparametric Geophysical Formation Models for Devonian Deposits in the Romashkinskoye Oil Field
Authors: Diyashev R. N. , Khisamov R. S. , Saveliev A. A. , Agliullin M. Ya. 
Published: December 2007

Abstract
In the paper published by us [1] we set forth the methods and results of multivariate formation classification using the data base of geophysical parameters.
Four types of formations have been identified with a 87–94% accuracy presenting non-reservoirs, water saturated and oil saturated reservoirs and one class which we called intermediary or mixed which judging by the results of standard conclusions on well-logging data, includes in various proportions the formations of all the above-mentioned classes. The present paper illustrates the results of classification with identification of other 6 or 8 groups of formations with the purpose of their detailization according to lithology and fluid saturation.
The used data base included 6 geophysical parameters characterizing 14,546 formation intersections in 1,707 wells. The classification method lies in building of a ‘Tree of Classes’ according to the Ward method and appropriate classifying equations of discriminant analysis, and in determining the position of classes on the ordination plot in compliance with canonical equations.
The classification results in the delivery of: –Borders of classes identified implicitly by means of discriminant analysis and described by classifying functions;–Tables with the results of classification quality on the training subsets, including the percentage of correct attribution of the interval to the class;–Statistical description of classes.
Even though interpretation results were not used when making up classifying equations, the comparative analysis of classification results with standard interpretation data points to possibility and practicability of including the generated classifying and canonical equations into the active software for interpretation of well-logging data. This will increase accuracy and unambiguity of issued conclusions on the lithology of formations and their fluid saturation, which is very important for building geological and hydro-dynamic models of oil fields and estimation of reserves and designing of development.
Intraformational Bed Influence on Remaining Oil Distribution and Tapping Potential Technology with Horizontal Well in Extrahigh-Water-Cut Reservoir
Authors: Liu Xiantai , Liu Zhihong 
Published: December 2007

Abstract
The main pay of Guantao Formation in Gudao Field is a large-scale thick positive-rhythm channel sand oil layer. At the extra high water-cut stage, the thick oil layer is waterflooded seriously, but the top remaining oil is still enrichment due to influence of reservoir heterogeneity. The research shows that the development effectiveness of tapping the potential with vertical well is bad and the economic benefit is low [1]. If horizontal well is used, the producing degree and the recovery of the remaining reserve can be improved effectively. Among various factors of affecting development effectiveness of horizontal well, the influence of intraformational bed development is much more important. The development of intraformational bed and its control on remaining oil distribution should be understood first, then the technology policy research of tapping the potential with horizontal well was conducted in order to ensure the good development effectiveness with horizontal well. In this paper, the remaining oil distribution features under the different developmental conditions of intraformational bed are expounded in detail, the intraformational bed was divided into two kinds, developed and undeveloped; according to its developmental conditions, the technology policies of horizontal well were studied respectively, and the commensurate design criteria of horizontal well was proposed. The application of the achievements in tapping the potential of remaining oil in thick positive-rhythm oil layer during the extra-high water cut period has achieved preferable effectiveness, which provides reference for that in the same type of reservoir.
New Technology for Raising the Production in Injecting Steam Well by Using SEPA
Authors: Xie Jianjun , Shi Buqian , Zhou Jianhua , Li Jiang , Liu Guosheng , Yao Yiming 
Published: December 2007

Abstract
High cycle stimulation in Henan heavy oilfield has been suffering the problems such as low formation pressure, much accumulated water which deadly influence the steam thermal efficiency, leading to a bad production recovery. In high temperature, SEPA solution can decompose out gas that can increase the elastic flooding energy, compounding with special surfactant and alkaline, SEPA can develop steam conformance and flooding efficiency. Laboratory tests show that the recovery of non-homogeneity core has been increased by 16.5 percent point. This technology has been used more than 120 wells in Henan oilfield and effective rate reach 92.5percent. It has been proved that the injecting well has a bigger peak daily outputs longer valid period and a significant increment of production.
Efficient Technology Following Cyclic Steam Stimulation for Thick, Massive Heavy-Oil Reservoirs
Authors: Liu Shangqi , Gao Yongrong , Liu Shuangmao 
Published: December 2007

Abstract
With high temperature and high pressure 3-D physical simulation and reservoir numerical modeling, the gravity assisted steam flooding process with the combination of vertical and horizontal wells was investigated, including its production mechanism and feasibility, the influence of key parameters and the process optimization. The results indicated that there are 3 phases: pressure-drive dominance, the combined effects of pressure-drive and gravity drainage, and gravity drainage dominance for this new technology, compared with SAGD process in oil sand. In each phase, the pressure differential and production performance have different character. The heat communication between injection and production wells has great impact on pressure difference. Using this new technology, the recovery factor can increases by 35% with cumulative oil steam ratio of 0.188 after CSS.
SAGD as Follow-Up to Cyclic Steam Stimulation in a Medium Deep and Extraheavy-Oil Reservoir
Authors: Li-qiang Yang , Da-sheng Zhou , Yu-huan Sun 
Published: December 2007

Abstract
Guan-tao oil layer of Shu 1 Block in Liaohe oilfield is a medium deep and extra heavy oil reservoir, which has high porosity and high perm with edge water. In 2001, cyclic steam stimulation was applied with square well pattern and well-space 70m. After 9-10 cycles the stimulation development effect deteriorated and the degree of reserve recovery was only about 15%. To seek development method of extra heavy oil reservoir and improve the entirety recovery ratio of this block, after the feasibility research on SAGD technology in Guan-tao oil layer was finished, horizontal wells were infilled between vertical wells and 4 SAGD pilot test well groups combining vertical wells with horizontal wells were conducted Three cycles of cyclic steam stimulation to preheat the formation and decrease pressure were proceeded and the 4 well groups had produced for 1 year after converted to SAGD. Daily oil production capacity of single horizontal well increased from the initial 20-40t/d to 70-80 t/d after the multiple adjustment of the injection-production parameters. Preferable period effect was accomplished and the test provides good guide for same medium deep and extra heavy oil reservoir to change their development methods.
The Chaos and Its Complexity Degree for Petroleum Price Sequence
Authors: Jian Wang , Guangxue Cui 
Published: December 2007

Abstract
The paper takes Brent oil price as an example to study the nonlinear characteristic of oil price sequence. The original price data is processed first, then the chaos and its complexity degree is studied systematically, based on which the chaos cause of oil price is analyzed. Thus, the variation of oil price sequence is opened out, which can be used to forecast and regulate the oil price.
Research and Application of Reverse Circulation Drilling Technology
Authors: Li Lichang , Ru Dajun , Li Kefu , Yishan Wang 
Published: December 2007

Abstract
The reverse circulation drilling technology is that drilling fluid is pumped down to the annulus, through drill bit and inside of the drilling tool, comes back to the ground. It has many advantages, such as reducing the formation leakage, protecting the oil and gas formation, and cutting sample very clear etc. It includes air lifting, air and pump sucking reverse circulation drilling. Air lifting reverse circulation drilling needs air compressor, air tank, air box, double wall drill tool, air mixer and reverse drilling bit etc. By applying the original drilling rig, these equipments are connected to drill string and carried out the drilling work, after finishing drilling work, these equipments can be removed totally, and have no influence to the normal drilling work. Through testing and on-site application, these equipments are coordinative, drilled 400m in the leaking formation and got a better effect.
Pilot Test of Weak Alkaline System ASP Flooding in Secondary Layer With Small Well Spacing
Authors: Xinde Wan , Mei Huang , Huiyu Yu , Yingzhi Zhang , Weidong Chen , Ershuang Gao 
Published: December 2007

Abstract
ASP flooding is an important EOR technique currently. five pilot tests have been conducted in Daqing oil field, obtaining good results whose incremental recovery is over 20%OOIP higher than water flooding[1,2], strong alkaline system is mostly adopted which is harmful to oil formation, leading to severe scaling and difficulty in treating produced fluid[3]. Taking advantage of weak alkaline ASP system that is developed newly in laboratory, small well space and fast effect show in pilot area, the representative SII12 formation was selected for weak alkaline ASP flooding pilot test in 2004, and evident result has been obtained. In this paper, the dynamic varying regularity of oil and water wells was analyzed systematically, the result and understanding were introduced, and some technical problems were discussed.
Technology of Plugging Long-Interval High-Pressure Channeling Wells by Cement with Overburden Pressure During Curing
Authors: Yan Wang , Demin Wang , Jun Wan , Jiangtao Luo , Ping Zhong , Zengyou Dong , Yingzhi Liu 
Published: December 2007

Abstract
With the prolonged time of development and increased interlayer pressure difference, there is numerous cement channeling problems between isolated zonal intervals in production and injection wells in Daqing Oilfield. The cement channeling problems, especially in long intervals, change the original layers developed and make the interlayer interference more severe. Furthermore, all kinds of chemical treatment methods that are used to remedy channeling cannot meet the needs of plugging long interval channeling wells in the field because of the disadvantages of complex process, high cost, low success rate, safety concerns, high risk and etc. Therefore, a new method has been developed specifically for plugging long interval high pressure channeling wells by cement curing with an overburden pressure and the results are encouraging.
Application and Study of Acid Fracture Technique Using Novel Temperature Control Viscosity Acid in Carbonate Reservoir, Tarim
Authors: Zhou F. , Liu Y. , Zhang F. , Xiong C. , Peng J. , Yang X. , Liu X. , Lian Y. , Qian C. , Yang J. , Chen F. 
Published: December 2007

Abstract
This paper will present the development novel temperature control viscosity acid (TCA) technique that uses for acid fracturing in Ordovician formation in TZ region of TARIM, China. The Ordovician formation in TZ field is extreme heterogeneous carbonate with naturally fractures, that locates in deep underground of 5000-6300m, the reservoir temperature is around 120°C-145°C, and the reservoir close-fracture pressure The above 90Mpa. During the past decade, many acid fracturing techniques (such as gelled acid technique and emulsified acid technique) have been applied, but the results were not satisfactory. Under these difficult circumstances, in order to gain perfect acid fracturing effectiveness, we have succeeded in developing TCA acid fracturing technique.
A new TCA system is presented in this paper that has unique viscosity-temperature characteristic, the TCA viscosity is the same as gelled acid at room temperature, and increase rapidly while under high temperature reservoir conditions, the TCA viscosity can come to over 200mPa.s. It is a preferable retarded and little leakoff acid system, at 120°C, TCA's rock/acid reaction rate is 6.3 times and 2.4 times slower than straight acid and gelled acid respectively.
This paper also provides two TCA acid fracturing cases in the Ordovician formation in TARIM, the results are remarkable. one of the wells (well A), The production was used with choke of 12.7mm after acid fracturing. The tubing pressure was 37MPa. Production was 72.7×104m3/d of gas and 485m3/d of oil. That demonstrates that TCA can generate longer etched fractures in heterogeneous carbonate reservoir.
Application and Its Extension of Autocontrol Management Technology in Oil Production
Authors: Wang Jixin 
Published: December 2007

Abstract
Several auto-controlled oilfields with more than one million tons oil production capacity per year respectively have been build in the deserted area in Junggar basin in Xinjiang, China since 1994. Advanced SCADA (Supervisory Control and Data Acquisition) systems have been used to gather the information (such as pressure, temperature, flow rate etc.) of oil wells, gas wells, and water injection wells, and transmit the data wirelessly to a central control room so as to realize the supervising of the production process and the controlling to some of the device(valves on a metering manifold) or equipment (beam pumping units on site). After the data processing, some kinds of services could be provided such as to print daily production reports, to analyze or inquest the production data and so on. A higher efficiency and lower production cost of oil production in these oilfields have been realized compared with the ones managed with conventional means. With the development of automation technology and petroleum engineering, advanced management and better efficiency could be achieved if some improvement about the auto-control system would be done, including installing some devices to collect the input power of a motor and the producing liquid level of pumping wells, developing the necessary software for the monitoring of the gear net torque, the balance state of unit load and the motor power of pumping units. The running condition of a pumping unit and its energy efficiency (surface, down hole and the whole system efficiency) could be supervised, diagnosed and improved. This paper brings a brief introduction to the application of auto-control technology in Xinjiang oilfield, and from the view of oil production engineering, offer an upswing plan for auto-controll system to pumping wells.