bluuebunny/crossref_metadata_2025_split huggingface dataset:
Tackling of a Complex Carbonate Field Through a Dedicated History-Match Scheme and Software
Authors: Pauget Luc , Pignot Benjamin , Dzhafarov Denis 
Published: September 2014

Abstract
Kharyaga Object 2 is an oil bearing reservoir with a gross thickness of 160-250m deposited on a rimmed shelf system. Two domains can be distinguished: the platform margin (the barrier domain), highly fractured and karstified, and the platform interior (the back-barrier domain), almost fault and fracture-free, non-karstified, and which shows a matricial behavior. Both domains are developed.
As per current vision, flow behavior in the barrier part is mainly controlled by different dissolution features and a complex secondary porosity network. Field development started in 1999 and significant amounts of data were acquired (extensive use of down-hole gauges – MDT – PLT, well tests, interference tests, etc.). Integration of new data into the dynamic model required a rigorous history match process and an efficient workflow with a permanent link to the geological vision. A progressive match by steps (conductivity Å static pressure Å watercut Å vertical inflow performance Å well interference) helped to avoid being overwhelmed by the amount of data to be matched.
This elaborated matching scheme permitted, as a result, to distinguish and reveal the impact of all types of heterogeneities on the matching process (matrix, karst or fracture dominated) and calibrate a complex representation with a dual medium (matrix and secondary media, the latter merging various types of karst, faults and fractures).
Representing properly the field complexity required a significant number of cells, as well as the use of specific mechanisms (imbibition with hysteresis and gravity drainage). To simulate such sophisticated representations in a reasonable time, a new powerful software and high computational power were required.
As a result of the smart use of acquired data for the calibration of the dynamic model, a powerful tool for reliable production forecast and business management was developed.
Field Studies of Spontaneous Growth of Induced Fractures in Injection Wells
Authors: Davletbaev A. , Baikov V. , Bikbulatova G. , Asmandiyarov R. , Nazargalin E. , Slabetskiy A. , Sergeychev A. , Nuriev R. 
Published: September 2014

Summary
Development of low-permeability reservoirs (less than 1 mD) is carried out with intensive flooding. Injection is performed at pressure above the formation fracturing pressure that is why in almost every well a spontaneous growth of (injection) induced fractures takes place.
The main problem of pressure transient analysis in a low permeability reservoir with spontaneous fracturing is a long linear regime flow observed in the log-log plot and the absence of a basis to achieve a pseudo-radial flow. To increase the accuracy of well testing in spontaneously fractured injection wells, certain field tests were developed and run. While testing, an injection well with spontaneously induced fractures was shut-in before the bottom-hole pressure went below the fracture closing pressure, then injection resumed for a short period of time, and then the well was shut-in again to record the pressure fall-off curve. The second pressure fall-off curve shows that the pseudo-radial flow developed, because the close of the part of the fracture without proppant occurred.
The paper shows field examples of interference well tests exhibiting fracture growth up to 1700 m diagnosed in injection wells. Examples of successful restriction of injection well operation and application of correlation relationships of fracture closing pressure vs. formation pressure to lower water-cut in production wells with water breakthroughs are described.
Efficient Engineering Method for Creating Adequate PVT-Model of Natural Gas Condensate Mixture Using Equation of State
Authors: Yushchenko T. S. , Brusilovsky A. I. 
Published: September 2014

Abstract
The article is considering a new engineering method for creating PVT-models of natural gas condensate mixtures. The method is based on the reproducing of the results of field measurements and basic laboratory studies of representative samples in thermodynamic modeling using equation of state.
The procedure of equation of state parameters consequent setting was developed. It can be performed without regression analysis, which is traditionally used in the PVT simulators (Eclipse PVTi, Roxar PVTx, PVT-VIP, PVTsim etc.). As a result, the created PVT-model precisely reproduces the key properties: initial condensate content in the reservoir gas;z-factor of the reservoir gas;gas-oil ratio of gas condensate studies;density of stable condensate;dew point pressure;results of constant volume depletion (CVD) test.
PVT-models created on the base of the proposed method, provide reliable information on the properties of a reservoir fluid in development of flow simulation both using a reservoir simulation compositional models and using pseudo models "black oil" with "wet gas".
The method is illustrated by the example of creation of the adequate PVT-models of various regions of Russia reservoir condensate field's mixtures.
Modeling Experience Giant Oil and Gas Fields of Integrated Sectoral Models
Authors: Kostyuchenko S. V. , Tolstolytkin D. V. , Chuprov A. A. , Smirnov A. S. 
Published: September 2014

Summary
Modern reservoir simulation models of oil and gas fields become more detailed, calculated cells become smaller, and the number of these cells avalanche grows. For large and giant oil fields the number of cells in such models can reach up to 109. The authors have developed and tested computing technology that removes the constraints on the size and detail of reservoir simulation models. This technology is based on the decomposition of large models for sector models and on separate calculations. Algorithm of iterative integration of sector models-Iterative Fitting Boundary Conditions (IFBC) restores the integrity of the full model. This algorithm is more general than option Flux Boundary Conditions (FBC) of reservoir simulators. IFBC algorithm was tested for several sector models of large oil and gas fields. The field size is 50 * 80 km, 4 objects of development with the gas cap, more than 15000 wells, and 44 years of development. 125 regions selected for modeling. Uniform requirements are defined for all sector models. Sector models built for multiple regions of field. The total number of calculated cells is from 7 up to 700 million cells for different implementations of the models. Modeling was done for full model of oil field, for integrated sector models and for non-integrated sector models. Modeling without the integration of sector models leads to errors more than 150% of the accumulated gas cap gas production (FGPTF, WGPTF) and more than 200% for accumulated oil wells (WOPT) in comparison with the full model. Using the algorithm IFBC reduces errors before 2-3%. Computing technology is based on an algorithm IFBC that allows you to create a giant model, "stick together" full of sector models, "implant" sector models in full. Each of the sector models can be created by individual simulator and can have an independent grid.
Visco-Elastic Flow Impact in PTA Interpretation
Authors: Iktissanov Valeri A. , Ibragimov Nail G. , Goncharov Alexander M. 
Published: September 2014

Abstract
Numerous studies show that the widely used diffusivity equation is a significant simplification of real fluid flow in reservoir. One of the underinvestigated phenomena is viscoelastic behaviour of liquid in porous media described by relaxation flow equations.
The objective of the work is to study features of viscoelastic flow. Choice of this topic was primarily determined by the fact that none of the existing non-linear flow models (with initial pressure gradient and permeability/pressure dependency) describes the observed decrease of absolute value of DD derivative compared to pressure derivative at shut down.
To solve the formulated problem, results of petrophysical and PTA studies were used; a number of viscoelastic flow methods were developed. The optimal method was chosen; its distinctive feature is simultaneous consideration of stress relaxation and deformation delay as well as taking into account deformation sign during loading (DD) or unloading (PBU). It was found that usually stress relaxation time is close to zero while deformation delay time ranges from half an hour to several hours.
The proposed model allows increasing interpretation accuracy of PBU and DD initial segments and long term pressure data, and also determining deformation delay time.
New Way of Individual Evaluation of Tight Comingled Reservoirs
Authors: Kremenetsky M. I. , Panarina E. P. , Kokurina V. V. , Melnikov S. I. 
Published: September 2014

Abstract
Paper presents production logging (PL) problems in tight comingled reservoirs. Quantitative evaluation is possible when PL is done with JET pump or ESP & T-tool or naturally flowing wells.
Authors have made series of numerical simulations to determine temperature distribution in producers and optimize production logging and interpretation procedure.
Simulation illustrates traditional temperature interpretation technique with comparing well temperature logging curve with geothermal gradient is useless in case of tight reservoirs due to high influence of previous production and unstable flow. New way can handle that problem.
New way of temperature interpretation to individual evaluation of tight comingled reservoirs can be used even in difficult for traditional temperature logging cases: horizontal wells, inflow control valves (ICV) presence in the wellbore, etc.
Author’s method is based on mathematical simulation and on production logging case studies. In high rate producers temperature logging were compared with spinner and results were the same.
Technology implementation on comingled wells of Western Siberia oil fields gives each formation rate and pressure. That results in production and injection optimization to increase sweep efficiency and recovery.
Complex Research of Reservoir Properties on Cores From Achimov Deposits
Authors: Dmitriev N. M. , Kravchenko M. N. , Dmitriev M. N. , Tsybulsky S. P. 
Published: September 2014

Abstract
The ventricular formation structure, hydrodynamic isolation interlayers, low porosity do not allow to develop the field by traditional methods. Creating of new field development, methods requires a lot of analytical work, a comprehensive laboratory analysis and mathematical modeling, taking into account features of the Achimov deposits.
In this paper the of complex experimental research results on cores of Achimov deposits for anisotropic porous media is given and theoretical model is described for correct interpretation of the results. Due to new laboratory technique, authors showed that Achimov deposit characterized by anisotropy of reservoir properties
Laboratory measurements were made with using four specially oriented samples which was cut from full-size core of standard size. Two samples were oriented in the direction of the stratification along the principal directions of the coefficients of permeability tensor one - perpendicular to bedding, and another - at an angle of 45 degree to the bedding plane. The last fourth core was a control sample. It was used for testing of theoretical model and proof of tensor nature of mathematical objects for describing of real anisotropic deposit. In addition this fourth core was used for evaluation of the measurement error.
The experiment showed that the layers deposits Asimov have pronounced anisotropy. In addition to porosity, absolute permeability there were also constructed distribution function of pore radius and capillary curves. The experimental results have allowed defining the characteristic linear dimensions of capillaries (effective diameter), luminal values. Measurements on the fourth sample showed that the permeability characteristic linear dimensions of capillaries, luminal, capillary pressure jumps define by the symmetric tensor of the second rank.
The experimental results were processed using theoretically derived formulas. Established a good agreement between theoretical and experimental results that allows us to recommend for engineering calculations, as proposed formula and co to conduct laboratory methods of reservoir properties investigation for anisotropic reservoirs having orthotropic filtration properties, including the definition of the functions of relative permeability, limiting pressure gradients nonlinear filtration laws, etc.
Oshskoye Oilfield as an example of Well Construction Optimization in the Timano-Pechora Region
Authors: Kutlashov Anton , Nasretdinov Ilmir , Bogdanov Sergey , Kuznetsov Anatoliy , Zhevna Viktor , Tenishev Vladislav 
Published: September 2014

Abstract
The report outlines key solutions for well construction optimization at the Oshskoye oilfield located in the Komi Republic.
Together with LUKOIL, Halliburton implemented a number of engineering solutions for successful project execution and took a modern approach to integrated project management based on Halliburton's standards. The project management structure was developed to allow for a new operational approach, including:Detailed planning of operations, with risk probability and severity assessment; determination of responsibilities and development of risk mitigation measures prior to the project start and operational corrective action during the projectInvolvement of all well construction project participants, from workers to managersEnhanced interaction between project members to improve well construction management and controlEngineering support for the project, including: comprehensive analysis of the current well conditions; provision of real-time calculations; development of process solutions; support for development and implementation of proposals for well construction optimization; in-depth analysis of the findings and lessons learned.Drilling mud composition for directional wells was fully optimized.An optimal combination of a mud motor – drill bit was selected.Well paths were optimized.Well design was optimized.
As a result, within the space of 1.5 years well construction time was reduced by more than 30 % compared to the schedule.
Managed Pressure Drilling Advances Well Construction with Enhanced Hazard Mitigation
Authors: Kulikov Stanislav , Veliev Gurban , Chumachenko Alexey , Shilkin Pavel 
Published: September 2014

Abstract
Formation overpressures have traditionally forced operators to weight-up mud systems in order to advance drilling operations while preventing formation fluids invasion. As a result, drilling rate of penetration (ROP) is reduced, additional casing seats/strings are required and risks associated with kicks are increased. This drilling hazard is a major source of invisible non-productive time (NPT) and increased operational costs.
Today's drilling environments present many challenges, such as high-temperature/high-pressure (HPHT) with mud losses and fluid or gas influxes that require a lot of time and resources to address. Inaccurate or late detection of an influx can result in costly nonproductive time, or in some cases, increase the likelihood of a well control incident. Improper mud weight management to control a kick can result in increased of differential pressure and mud losses if the reservoir frac gradient is exceeded. This in turn will cause fluid kick and mud loss cycles that will cost weeks of rig time and millions of dollars. These operations result in reservoir damage, reduced flow rate, minmized production or even the need to sidetrack.
This paper will further explain MPD techniques and its unique ability mitigate today's toughest challenges related to a wellbore's pressure profile. We would like to discuss the possibilities of the system to indicate the kick and losses on early stages and address them accordingly to the automatically controlled system. The system will allow to separate the kick from such events as ballooning and breathing, run dynamic FIT and LOT tests, will let to determine the actual pore pressure figures throughout the intervals of interest, simultaneously control influxes and losses before they get built into the well control events. Using the MPD can be the key for most of the applications to enhance safety, improve drilling efficiency and to get a better understanding of the fields nowdays and further on.
Network Test Instruments Use for Verification of Subsea Control Networks
Authors: Shchepetilnikov Alexey , Golledge Nick 
Published: September 2014

Abstract
Control networks in new subsea processing projects are growing and coming to new level of complexity compared to solutions in existing production projects. The IP-based control network in Åsgard subsea compression project consists of more than 500 network hosts and include network-enabled equipment from 15 different vendors. Due to complexity of solution, it is impossible to assemble all components for verification prior to SIT.
Delivery of reliable network solution for signal transmission require extensive verification of interfaces, network equipment and application behaviour. Network test instruments were used to perform several layers of functionality verification:
Protocol compliance – OSPF and RIP routing protocols, IPv4, DHCP client/server.
Functionality test – QoS policing, IP routing, DHCP configuration.
Load simulation – traffic from individual controllers and applications has been recorded and replayed to simulate behaviour of entire network assembly.
Performance measurements – industry-standard RFC2544 and RFC2889 benchmarking tests; network and application recovery for redundancy switchovers, and recovery from non-redundant failures.
Stress tests – network traffic overload, excessive IP/MAC address load, routing tables overload; application behaviour in impaired network environments – reduced bandwidth, excessive network delay and jitter, packet loss, duplication, reordering and corruption.
Description of test instrument applications and test scenarios is provided in this paper for the reader.
Closed-loop Production Cycle - A New Paradigm of Hydrocarbon Resources Development in Remote Areas of Siberia
Authors: Muravyev A. V. , Nikonov A. L. , Tyrina L. A. , Zhukov S. I. , Kruptsev A. V. 
Published: September 2014

Abstract
Economical and environmentally friendly waste-free production of petroleum products (arctic fuels and lubricants) in the closed production cycle is a key prerequisite for the integrated development of remote and inaccessible regions of Siberia. Closed-loop fuels production system includes the following processing chain: Production of hydrocarbons from the wells - Flow control and separation of oil/ water/ gas mixture - Additional preparation of oil (if necessary) - Cathalytic desulfurization (if necessary) – Production of fuels in thermo-cathalytic cracking system. All elements of this chain are represented by relatively compact and modular units are designed for autonomous operation in harsh environments.
The main benefits that will apply the concept of a closed loop: Economic efficiency - from the production of finished products for the consumer on the ground, rather to build costly export pipelines from remote areas.Reduction of environmental risks in ecologically sensitive regions.Creating conditions to develop local infrastructure by provision arctic fuels through all the seasons, local workforce involvement.Use of natural resources in the interests of not only the present but also the future generations.Energy security of the country - saving a significant part of the strategic resources of oil and gas in country.
Method of Well- Killing Operation by Using Visco-Elastic Gels with Controllable Destruction Terms
Authors: Okromelidze G. V. , Garshina O. V. , Nekrasova I. L. , Iljyasov S. E. 
Published: September 2014

Abstract
Process fluids used for operations with productive formation are considered to be a decisive reason of decreased well productivity. Application of special-purpose fluids allows eliminate the negative effect of the process fluids; these fluids don't make through a formation during operations of wells completion and workover and could be easily removed after the operations have been finished. Well- killing operation with process fluids without tunable properties is a standard well- killing technique during workover operations. Such method doesn't protect a formation from liquid penetration, and oftentimes after such workover operations it is getting rather difficult to reach the process stabilization of the well.
Visco-elastic gels (VEG) act as a "flexible packer" and are designed for temporary protection of productive formation on the stages of wells’ completion and development, during workover and insulation operations. Over 350 well- killing operations by using VEG have been carried out in the territory of Perm region within 2012-2013. Application of this technique provides specified effect concerning decrease of well- killing liquid volume and saving time needed for the process stabilization. However the well pumping equipment failures have been registered due to fouling with VEG residues. Noted problems could be eliminated by applying the proposed well- killing technique by using the composition with specified destruction time.
Cross-linked polymer systems gain widespread acceptance in formation fracturing operations. Provided that a considerable amount of breakers are offered at the market, they include "encapsulated" breakers designed to destruct fluids after proppant has been injected into formation. By that the induction period prior the breakers start action doesn't exceed 2-3 hours upon they have been injected into the system. For well- killing operations by VEG application it's typical to provide retention of the fluid bridging properties at least 2-3 days. In this regard conceptually new approaches are required to reach such conditions in order to control VEG "lifetime".
This study presents the results of laboratory research on VEG development with controllable service life. Introduction of this technique will allow reducing the likelihood of equipment failures and accelerating the process of reaching design basis conditions of the wells.
A Mathematical Model of the Process Output Mode Wells Equipped with ECPU
Authors: Balandin L. N. , Astafev V. I. , Gribennikov O. A. 
Published: September 2014

Abstract
This paper considers the output mode wells equipped with electric centrifugal pump units (ECPU). The inference process is a complex task in unsteady hydrodynamic work, as most of the well and the reservoir. Process occurring in the reservoir in the derivation of ECPU mode, described by the differential diffusion equation. In this paper, to solve this equation for small times a mathematical model of hydrodynamic processes occurring in the well in the derivation mode. The resulting model accounts teamwork bottomhole formation zone, the well and pump.
Theoretical dependence of the decline curve in the well was compared with practical ones obtained at the well number 16 of West-Shirochenskoe field of JSC "Samaraneftegaz." It has been found good agreement between the theoretical and practical curves. The resulting mathematical model was used to determine reservoir parameters (permeability, diffusivity coefficient, skin factor) for several wells of JSC "Samaraneftegaz." Next to this model is planned for full forecast output process well in the regime, i.e. determining the value of the maximum reduction value of dynamic level and time of its occurrence.