bluuebunny/crossref_metadata_2025_split huggingface dataset:
Improved Hydraulic Fracture Modeling Based on Geomechanical Correlation Functions to Optimize Development of Priobskoe Oilfield
Authors: Nadeev A. , Yudin A. , Sudeev I. , Pestrikov A. , Nikitin A. , Sitdikov S. , Timonov A. 
Published: October 2012

Abstract
Conventional low-permeability sandstone formations with strong shale barriers require hydraulic fracturing (HF), a classical approach to fracture geometry optimization, which is needed to enhance oil production of each well and oil recovery from such fields overall. Unfortunately, in most cases there are insufficient resources to acquire the information to create precise fracture modeling for every suggested well. Rock elastic properties and distribution of in-situ stresses have the greatest influence on fracture geometry. HF modeling without proper understanding of these parameters usually results in loss of the relationship between log or core data and zone properties in the model.
A new, innovative approach provides the ability to extract mechanical rock properties for each well from a standard log dataset. This was achieved by introducing correlation functions based on multiple wells with an advanced log dataset including density and acoustic logs and core analysis to correlate dynamic and static rock properties. Correlation functions were built into a Geomechanical (GM) software module referred to here as the GM Module.
The module can be used with any commercial fracture simulator to automate and link the process to log data during each step of the HF modeling and evaluation workflow. Although a majority of studied wells produce from several separately stimulated layers, an adjustment in the GM Module for one HF treatment allows a continuous model of geomechanical properties and stress distribution to be built along the entire logging interval.
As a first step, the module was integrated into a standard modeling workflow for 60 HF treatments; comparative study of the improved versus conventional approach was performed. Second step will be to introduce the GM Module to a stimulation service company operating in Priobskoe oilfield, one of the world's largest oilfields, which will ensure uniform and reliable control over the fracture optimization process to enhance overall field development and oil recovery.
Extensive Optimisation Analyses of the Piping of two large Underground Gas Storage Ariel compressors
Authors: Eijk A. , Heyer D. , Tenbrock A. 
Published: October 2012

Abstract
Two large identical 6-cylinder Ariel JGB/6 reciprocating compressors each of 7.5 MW, are used for an underground gas storage system in (UGS) plant located in Epe, Germany.
The compressors can be operated at a wide range of operating conditions, e.g. variable suction and discharge pressures, 2-stage mode during gas storage, 1-stage mode during gas withdrawal, capacity control by speed variation and valve lifters.
The system should operate efficient, safe and reliable for the complete range of the operating conditions, which can be guaranteed by an extensive optimization analyses during the design stage of the project. For that purpose TNO has carried out different dynamic analyses according the API Standard 618 to be sure that the system can operate efficient, safe and reliable for the long term. In the present paper a summary of the underground gas storage system is given and the different steps in the optimization process of the system have been indicated. Finally, the results of vibration measurements after start-up of the system are presented, conclusions and remarks are given.
Prediction and Dynamic Operation of Gas Distribution Networks
Authors: Ligterink N. E. , van der Linden R. J. 
Published: October 2012

Abstract
In the Netherlands a dense gas distribution network delivers gas to the majority of households. Traditionally only a few big suppliers deliver gas to the network, but currently there is a growing number of new small green gas suppliers in an increasingly flexible and competitive gas transport market. The gas transport providers, responsible for delivering gas to their customers, are confronted with a much more challenging task in operating the network, especially when confronted with fast changes in supply and demand and during maintenance and incidents. This complexity asks for operator support operating the network. In this paper we show, based on physical models of a typical network, involving hundreds of kilometers of pipelines and thousands of nodes and branches, how a fast and versatile simulation model, can predict the pressures and flows in the network. This gas transport simulation: predicting pressures, flows and mixtures at every location in the network, is the basis of controlling a less robust gas network, through periods of high and low demand. We will simulate a real network with the physical relations between flow, pressure, pressure drop, time-delay and mixing. Due to the nonlinear relations between pressure and flow, the standard techniques of dynamical (electrical) network simulation cannot be applied. They lead to instabilities, numerical inaccuracies and slow convergence. We will show how we solved these problems. We further show how this prediction model fits in an operator support environment that helps network operators in real-time management of operations.
Channel Fracturing in the Remote Taylakovskoe Oil Field: Reliable Stimulation Treatments for Significant Production Increase
Authors: Sadykov A. , Yudin A. , Oparin M. , Efremov A. , Doctor S. A. , Vinohodov M. A. , Chebykin N. V. , Garus I. V. , Katrich N. M. , Rudnitsky A. A. 
Published: October 2012

Abstract
The channel fracturing technique changes the concept of proppant fracture conductivity generation by enabling hydrocarbons to flow through open channels instead of through the proppant pack. The new technique is based on four main components: proppant pulsing at surface with fracturing equipment and software, a customized perforation strategy, a fibrous material to deliver stable channels, and a set of models to optimize channel geometry.
The Taylakovskoe oil field is located in western Siberia—430 km away from the nearest settlements. The Jurassic reservoir in Taylakovskoe field is a sandstone formation with significant net pay (average 25 m) and middle-range permeability (3 to 20 mD). Bottomhole temperatures range between 85°C and 90°C. Fracturing gradient is typically 14 kPa/m. The majority of the wells are stimulated immediately after drilling. Sufficient fracture conductivity and effective fracture length are essential for adequate well performance. The optimization of hydraulic fracturing treatments conducted in recent years was based on improved fluid chemistry and pumping "aggressive" fracture designs; this yielded high-quality results. The new channel fracturing stimulation technique, which allows significant increases in fracture conductivity, became the next technological progression. With channels inside the fracture, fluid and polymer residue flow back faster than with a conventional proppant pack, improving cleanup and increasing effective fracture half-length.
One of the most important advantages of the new technology is a very low risk of screenout events. The fibers make fluid more stable, while the presence of clean pulses around proppant structures promotes bridging-free flow. Reduced risk of premature treatment termination is even more important in remote operations such as in the Taylakovskoe field because of the higher costs of nonproductive time and deferred oil production.
Candidate selection criteria were developed specifically for local conditions. Ten channel fracturing treatments performed in Taylakovskoe wells have already showed significant increases in incremental oil production—average 44% beyond expected production as shown by well performance analyses. We describe the performance evaluation of wells completed with this technology and future plans for applying channel fracturing methods in the Taylakovskoe field.
Addressing Wellbore Position Challenges in Ultra-Extended-Reach Drilling in Russia's Far East
Authors: Poedjono Benny , Rawlins Sheldon Andre , Singam Chandrasekhar Kirthi , Van Den Tweel Alexander , Dubinsky Alexey , Rakhmangulov Rustam , Maus Stefan 
Published: October 2012

Abstract
Drilling in Russia's Far East has always been associated with industry-defining ultra-extended-reach drilling. With the emergence of more powerful drilling rigs and advances in measurement- and logging-while-drilling (MWD and LWD) tools, these wellbores can be designed to reach farther. Therefore, accurately penetrating and exploiting distant reservoirs have resulted in critical dependence on high-accuracy surveying techniques.
Successful target penetration and meeting anticollision requirements without the need for shutting production in nearby wells are key proponents for a geomagnetic referencing service (GRS). Geomagnetic referencing is the technique to minimize the lateral position uncertainties when using MWD. This is particularly important for wellbores that extend the boundary of the drilling envelope with stepouts greater than 13 km. The wellbore azimuth accuracy is highly dependent on the quality of the magnetic data used to produce the geomagnetic reference model. This model characterizes the absolute magnitude and vector direction of the natural magnetic field for every point along the wellbore. Representation of the local crustal magnetic contribution is key to the process since it constitutes a significant error in the lateral wellbore position.
Since 2011, a new, highly accurate geomagnetic referencing methodology has been used in Russia's Far East. Global contributions are accounted for by a high-definition geomagnetic model (HDGM). In addition, the local crustal magnetic anomaly is represented by 3D ellipsoidal harmonic functions tracking the shape and depth of the Earth, thereby providing seamless integration with HDGM and avoiding distortions faced by conventional plane-Earth approximations. A comparison with the previous industry standard shows improvements of 0.5° in azimuth determination. This high-degree geomagnetic technique will serve well for a number of upcoming developments in Russia's Far East, continuing to push the drilling envelope and providing essential, accurate wellbore positioning, while offering significant time and cost savings.
Deliverability Modeling of West Siberia Gas-Condensate Wells
Authors: Dobkine S. , Dewenter W. , Yushkov I. , Nesterenko A. 
Published: October 2012

Abstract
Deliverability of low permeability gas-condensate wells decreases when the flowing pressure falls below the saturation pressure. To some extent the deliverability can be mitigated by high matrix gas velocity. Condensate is stripped off next to the well reducing the fluid saturation and improving the well inflow properties. Non-Darcy turbulence flow in turn decreases the well capacity. With well flowing data only, it is difficult to differentiate between the two effects that act in the opposite direction. Gas condensate relative permeability measurements were designed to distinguish between the Velocity Stripping and Non-Darcy flow effects. The experiments were modeled with the Eclipse compositional simulator and the velocity dependent parameters were adjusted to match the experimental data. With the core experiment derived parameters it was possible to uniquely match the well test results of a gas condensate well. The test interpretation is in accordance with the lab results. In the case investigated the Velocity Stripping effect is very significant and fully compensates the adverse Non Darcy flow effect. A sensitivity analysis has shown that both effects are important for an un-fractured well, but insignificant for a fractured well.
Multi-fracs in horizontal well in Tumenskoe formations of Em-Egovskoe field Krasnoleninsky play Western Siberia
Authors: Platunov Andrey , Nikolaev Maxim , Leskin Fedor , Kaluder Zdenko , Masalkin Yuri , Davidenko Igor , Fedotov Vladimir , Murzinov Alexey 
Published: October 2012

Abstract
For the first time in horizons of Tumenskoe formations of Em-Egovskoe oilfield in Krasnoleninsky play of Western Siberia to achieve the maximum wellbore contact with heterogeneous multilayered formations the technology of multistage fracturing in horizontal well was used. It was a three staged fracturing job with use of coiled tubing to prepare well in between stages followed by well kick off and production start up.
Paper describes the experience of challenges overcoming during the different stages of horizontal well architecture, principles of equipment selection and fracturing design. This particular work was in 2010 and originated the first brief into the time of multifracturing horizontal wells of Tumenskoe formations in Em-Egovskoe field, Western Siberia. Multistage fracturing in horizontally drilled well is one of the effective technological solutions for Tumenskoe formations in Em-Egovskoe field. Remoteness and not yet confident knowledge of pay zones at current stage of described field wittingly made the preconditions for selecting the cost effective well design to suit the productivity of the well. That pilot multistage fracturing project presented itself as practical and reliable method to stimulate the production in horizontal well in Tumenskoe formations of Em-Egovskoe field Krasnoleninsky play. With more experience in further use of this technology will allow keeping this drilling and completion method as economically effective in field of this subject. This paper showed the problems occurred during the well drilling stage those also some affect on the followed completion and fracturing operations. Technological solutions have been offered based on study in this paper for future wells. As result of the analysis and gained experience the recommendations are made to ease the construction of well as for example to use the liner wellbore design. A number of recommendations are made for fracturing and coiled tubing design, preparation, equipment availability and technological processes.
Presented work preforms the hot topic of glimmering entry into massive multistage fracturing in formations of Bazhen-Abalak and Tumenskoe horizons in Western Siberia. The specifics of drilling and completion in horizontal wells are brought out based on described in paper geological conditions. Some trends and backgrounds were determined in study to achieve better efficiency in fracturing and coiled tubing operations for targeted formations.
Application of Active Temperature Logging at Oilfields of Russia
Authors: Sharafutdinov R. , Valiullin R. , Ramazanov A. , Fedotov V. , Sadretdinov A. , Zakirov M. 
Published: October 2012

Abstract
Nowadays in the process of investigating oil wells at the Russian oilfields there are still unsolved problems, such as evaluation of distinct production rates for separate layers in multi-layer system, diagramming the profile of the inflow from the layer in low rate wells, evaluation of the intervals of behind-the casing flows. In practice various methods are used to solve these problems. The most informative and widely used is temperature logging. A great amount of temperature logging is carried out at well completion, i.e. at a short-term fluid inflow from the beds due to operating compressor, swab, or jet pump. These processes are characterized by short time period of well operating and the presence of non-static thermal fields in the beds and well.
Recently, in Bashkir State University there has been done work in the use of artificial thermal field in well temperature logging, particularly, a thermal field made at inductive casing heat. In the report the results of theoretical, laboratory experiments are discussed, and the data of the first results of applying the new method, named ‘the method of active temperature logging’, to the fields of Bashkortostan, Tatarstan and Surgut region are given. The method presents investigation of transitional thermal fields created by local inductive heat of a metal casing after the well starting up. The main informative features are the value of temperature change, direction and velocity of the created "thermal mark". The second aim of the technology of inductive heat is heating of the bottom hole formation zone in order to both intensify oil production and control the efficiency of the processing.
The kinematic modeling for exploration of oil and gas prospects in fold-and-thrust belts
Authors: Gayduk V. V. , Kuksov S. V. 
Published: October 2012

Abstract
Intricately dislocated fold-thrust objects are the reserve of the geological exploration. Key problems for their preparation for the drilling are associated with poor quality of seismic material and ambiguity of the structural model. The structural kinematic modeling technology and geometric balancing make it possible to decrease the ambiguity of geological models and mitigate the risks of drilling under the circumstances. This Report covers the experience of kinematic structural modeling to solve the problems associated with the identification and preparation of exploratory prospects as well as for definition of the structural model of the deposits being developed.
Experience in Geology Study and 3D Modeling of Achimovka Formations of the Urengoy Field based on 3D Seismic Survey Data
Authors: Grechneva O. , Malygina O. , Ignatyev A. , Zakrevskiy K. 
Published: October 2012

Abstract
The Urengoi field (Novo-Urengoiskiy license area - NU LA) is used in this article as an example to review available knowledge on the Achimov deposits based on seismic, geological and field development data, as well as reservoir-scale geological simulation. A comprehensive approach is required for detailed characterization of the deposit structure to enable forecast of best prospects and differentiated treatment of individual areas of the field as development efforts are planned for the future.
Three geological bodies were distinguished at the Urengoi field (NU LA) in the Achimov formation each having its own turbidite fans simulated in the 3D reservoir model.
Development and Application of Small Esp'S for Efficient Development of Remaining Reserves in Poorly Drained Parts of Reservoirs of Samotlor Field
Authors: Akopyan B. , Svidersky S. , Liron E. , Prudnikov A. , Vetokhin E. , Martyushev D. , Khudyakov D. , Komarov O. 
Published: October 2012

Abstract
The article describes issues of achieving optimum underbalances while operating wells with small-diameter sidetracks and discusses approaches to developing small and very small sized electrical submersible pumps (ESP).
In the recent years, the sidetracking technology has been actively developed to reactivate flooded and damaged wells and to optimize the development system. It is sometimes difficult to implement the sidetracked well production potential due to small diameters of sidetracks (liners). The ESP running depth in such wells is limited with the production string sidetrack window location depth since standard pumps have bigger sizes than the sidetrack internal diameter, so they cannot be run to the design depth.
The article presents technical solutions that helped build unprecedented small-size ESP serviceable under complicated conditions as well as results of their pilot application in the Samotlor field being developed by TNK-BP.
Predictions of Cyclic Water Injection on Urnenskoe Oil Field
Authors: Rublev A. B. , Khuzeev Yu. A. , Ishimov I. A. , Fedorov K. M. 
Published: October 2012

Abstract
Cyclic water injection belongs to the group of EOR methods but the incremental recovery from its impact is poor and is comparable with accuracy of the total production measurement. So application of such treatment we call advanced waterflood.
Physical mechanism of oil recovery increase by cyclic water injection is a well-established phenomenon although the theory does not define the location of wells with periodical injection, amplitudes of injection variation and duration of cycles. In this paper the authors describe the framework of investigation for determination of the unknown parameters on the basis of streamline reservoir simulation.
The streamline calculation gives comprehensive visualization and quantitative description of the process and makes apparent the search of effective variant of the technology. The calculations were performed on the South-Usanovskoe formation of Urnenskoe oil field.
The Use of Block Permeability Fractured Reservoir Model for Engineering Horizontal Well Bores
Authors: Kiselev V. M. , Kinsfator A. R. , Antonenko A. A. , Chaskov A. V. 
Published: October 2012

Abstract
The permeability of fissured reservoirs is characterized by a pronounced spatial anisotropy, which must be taken into account during the field exploitation [1-10]. Data on the anisotropy permeability can greatly assist in the interpretation of the results of well interference testing and hydrodynamic studies.
Earlier, we introduced a new (bloc) permeability fissured reservoirs model [11–12]. The equation for the directional permeability as a function of spherical coordinates and the two constants, determined according to the distribution of the incidence angles and trending azimuths of fissures and linear dimensions of impermeable blocks was established. The principal difference between our model and the earlier one is that, firstly, statistical distribution of orientation and the linear dimensions of the blocks were taken into account. Secondly, we examined a system of hydrodynamically interconnected fissures.
According to geophysical studies of well bores, 3D seismic measurements and core analysis, a database of spatial orientation and size of the blocks much of the productive Riphean deposit of Yurubcheno-Tokhomskoye oil field were established. This data is used to identify the directional anisotropy of permeability. In addition to the previous studies, blocks, which cross-sections at the bottom was not square, but rectangular, was examined. The ratio of the rectangle bores were determined by the number of orthogonal fissures within the reservoir studied interval.
An algorithm for the calculation of the average directional permeability, which characterizes the flow of fluid to the horizontal bore, was established. Calculations have shown that this quantity depends strongly on the azimuth of the horizontal bore. If there will be a deviation from the optimum azimuth of the bore lines, even in the (5–10)0, flow of fluid to the bore may be reduced by more then ten percent. Another practically important result that follows from the calculations, is that the optimal direction of the horizontal bore must be oriented not perpendicular to the preferred fissure (as it is currently in the engineering of horizontal well bores), but at the angle other than 900. The value of this angle depends on the anisotropy of permeability and can be calculated.
Analysis of Multiple Fractured Horizontal Wells Application at Priobskoye field
Authors: Afanasyev I. S. , Timonov A. V. , Sudeev I. V. , Musabirov T. R. , Stepanov M. A. , Kolonskikh A. V. , Galeev R. R. 
Published: October 2012

Abstract
Analysis of opportunity of multiple fractured horizontal wells application in low-permeability zones of Priobskoye oil field is considered. Geological and engineering issues of area selection for horizontal wells drilling and features of multi-staged fracturing design are discussed. Brief description of completion technology applied is observed. Comparison between fractured horizontal wells and fractured vertical wells performance based on detailed flow simulation is presented.