bluuebunny/crossref_metadata_2025 huggingface dataset:
ESP Monitoring and Control System Implementation in Western Siberia Brownfield
Authors: Haberer Sven , Krasikov Anatoly , Lavrinenko Andrey
Published: September 2014

To improve production in a partly depleted western Siberia brownfield, the field was partly upgraded using digital oil field technology to monitor and analyze electric submersible pump (ESP) conditions. The data from downhole and surface sensors was transmitted in real time to a central server and analyzed using modelling and diagnostic software. The results of this analysis enabled the ESP experts, located in the control center, to detect anomalies and prevent potential failures – as well as to remotely adjust the operating points of the ESP to optimize production. Wells monitored using this system showed a significantly increased ESP run life compared to ESP run life before implementation of this system, increasing the productivity of the field despite harsh operating conditions and the remote location. This paper discusses the results and lessons learned during the first phase of the project as well as the next steps planned.
The Study of Remaining Oil Location in Multi-Pores at Micro and Nano Scale
Authors: Yang Shu , Dong Pingchuan , Cai Zhenzhong , Ji Xiaoyu , Lei Gang , Wu Zisen , Dong Ruitao , Zhang Zhenghong
Published: September 2014

This paper analyzes pore-throat geometry characterization using 2D micro-CT and field scanning rock images of Tarim basin sandstone and presents the oil droplet flow model in real pore-throat network based on Navier-Stokes equations and Finite Element discretization to study remaining oil location at micro and nano scale.

Using the Gray-Level Histograms and mathematical morphology, the real pore-throat geometry network characterization is extracted from images as logic matrixes using our imaging progressing program. The porosity, pore-throat radius and representative elementary unit are calculated to the simulation model. According to the result of pore-throat network at micro and nano scale, the pore-throat hybrid grid model and the two-phase simulation are built up. It includes the continuous water phase and the single oil droplet. Furthermore, the study takes the additional resistance caused by capillary pressure, shear stress caused by boundary effects and droplets breakup model into consideration. The simulation is verified by an accuracy of approximately 20% with the experiment results. This paper is aim to predict the remaining oil location under different pressure differences and oil drop radiuses, and study the influence of these factors by the analysis of calculated oil droplet concentration and fluid streamline of the simulation.

The paper reveals the vortex flow exists in the pore-throat network and the remaining oil is likely to gather in the high tortuosity and strong vortex regions, especially at the edge of pores connected to the outlet branch throats, dead pores and the center of pores. In addition, the paper shows as the oil droplet size and pressure difference increase, the displacement efficiency decrease and the remaining oil concentration change. Overall this paper provides a fast methodology for pore-throat geometry characterization quantitative study and a pore-scale oil droplet flow model to predict remaining oil location under different conditions.
Saturation Evaluation of Low Permeability Condensate Reservoirs in the Presence of an Oil-Rim with Wireline Formation Testers
Authors: Novikov S. , Weinheber P. , Charupa M. , Rudenko D. , Filimonov A. , Blinov V. , Yazkov A. , Shadchnev N. , Milushkin A. , Piana M.
Published: September 2014

The determination of saturation and therefore fluid contacts can be challenging in certain low permeability reservoirs of the Yamal peninsula. The low water salinity and high shale content make contact determination with traditional petrophysical methods difficult. The low permeability also complicates contact determination using pressure gradient analysis. Downhole fluid analysis seems a logical choice, but it too is fraught with difficulties in low perm, near saturated reservoirs.

In this paper we show how to apply DFA for contact determination and how to mitigate, by interpretation and hardware configuration, the various challenges. Additionally we investigate the quality of the obtained samples with respect to their suitability for PVT studies.
Oil in Non-Conventional Reservoirs of Tatarstan
Authors: Khisamov R. S. , Bazarevskaya V. G. , Timirov D. A. , Bazarevskaya N. I.
Published: September 2014

This paper presents the results of research programs performed by OAO TATNEFT aimed at additions to reserves and increased production from non-conventional reservoirs found in Tatarstan. It is worth mentioning that TATNEFT has been studying non-conventional reservoirs since 1950s.

To date, most of Tatarstan's oil fields have entered their closing stage of development with 86% cumulative production of OOIP and increase of hard-to-recover reserves share from 33% to 80%. A considerable part (36%) of TATNEFT hard-to-recover reserves falls on carbonate low-permeability sediments with low-thickness fractured reservoirs.

Aiming at study of shale, or tight, oil in the territory of Tatarstan, TATNEFT has concentrated its efforts on the search for oil accumulations and study of low-permeability reservoirs and source rocks in the Tournaisian-Sargaevian formations.

Prospecting of nonconventional hydrocarbon reserves and nonconventional reservoir study is a challenging, still, a very promising line of activity associated that can add value and yield good returns, considering that the Tournaisian-Sargaevian formations are widespread in Tatarstan, the domanikites are source rocks with high organic matter content, and proved oil potential of these deposits.

A certain tight oil potential is also associated with the Samara, Ulyanovsk, Orenburg, Nenets Autonomous District, and Kalmykia leases. It is worth mentioning that evaluation of shale plays is not based on conventional methods involving seismic survey, logging etc., but rather on analysis of chemical-mineralogical and mechanical rock properties.

Analysis of available well data has been performed; underway are large-scale core recovery projects, including oriented core and quick capture. Considering geologic environment of the domanikites and the domanikoids in the Volga-Ural oil-and-gas province, petrophysical properties of these rocks, fluid composition and properties, G&G information is analyzed to design hydraulic fracturing treatment in wells targeting the domanikites and the domanikoids. Candidates for hydrofrac jobs have been selected. Dedicated drilling and reservoir management technologies are developed.
Vertical and Horizontal Integration to Overcome Extreme Operational Challenges for the Achimov Tight, Gas-Condensate Formation
Authors: Graf Thomas
Published: September 2014

The production focus has shifted from the easy-to-access, shallow, gas-bearing deposits in the Cenomanian and Valanginian of the Urengoyskoye Field to the deeper, tight, gas-condensate formations in the Achimov. Several different operators have started to develop the Achimov formation with different development strategies on over eleven license blocks; however, with the common objective to maximize liquid and gas production from their license. Based on a couple of pilot projects with extensive testing, a unified development plan over the entire Achimov formation had been devised before the development start-up to guarantee hydro-carbon recovery and guide the operators through the development. Due to the enormous challenges encountered in the Achimov formation such as high pressure, low formation quality and deviated well stability challenges, the initial unified development plan foresaw the drilling of simple production pattern with a large amount of vertical wells. However, since the instigation of the unified strategy, the technology has advanced to overcome most of the challenges encountered in the Achimov formation with the potential of improving the sub-optimal, original development plan.

This paper discusses the general challenges of the Achimov development from well construction, production operations to reservoir management encountered by the various operators and attempts to define integrated solutions chains to overcome those. The operational and financial impact of the various technologies of the solution chains is defined and a possible roadmap for field development is devised. Several different operators have started to develop the Achimov formation with different development strategies on over eleven license blocks.
Single-Size-Ball Interventionless Multi-Stage Stimulation System Improves Stimulated Reservoir Volume and Eliminates Milling Requirements: Case Studies
Authors: Yuan Feng , Blanton Eric , Inglesfield Jamie
Published: September 2014

In the last decade, there has been a tremendous growth in multi-stage fracturing for unconventional plays employing stimulation sleeves with open hole (OH) packers or cementing. Standard ball-activated frac sleeve systems with graduated ball seats have primarily been used because they can significantly save completion time and cost by facilitating the performance of multiple stimulations in a single continuous process compared with the conventional Plug and Perforate (P-n-P). However, traditional ball-activated frac sleeves have limitations in the number of stages that can be handled, the pressure drop and friction loss each one creates and the need to mill through the ball seats after stimulation. As the number of frac stages increases, the ball seat sizes become dramatically smaller leading to large increases in the surface treating pressure and hydraulic horse power (HHP) needed to generate a given net downhole pressure or injection rate.

To solve these limitations a revolutionary ball-activated fracturing system has been designed. This system behaves in similar fashion of activation to the traditional graduated ball seat frac sleeve in that the ball locks into place on the seat, but all the ball seats are the same size and retract, allowing the first ball to pass through all sleeves until it reaches the lowermost one. Similarly the next ball, which is the same size, lands on the next seat up and so on, allowing a virtually unlimited number of zones to be treated for either OH or cemented application. With this new system, there is no milling operation involved and the completion string maintains full drift inside diameter (ID) ready for production after stimulation operations have been completed.

In this paper the authors will describe in detail the operational mechanism of this new frac sleeve and present case studies of its use which illustrates the effect of this new technology in optimizing fracturing operations both in horsepower requirements and overall completion time and cost.
Professional Adaptation of Shift Workers in Oil and Gas Companies in the Arctic
Authors: Degteva G. , Simonova N. , Korneeva Ya.
Published: September 2014

Shift work in the Arctic has high requirements for the adaptation capabilities of workers. As a result of the shift workers professional activities four major types of adaptation strategies are formed. Determinants of their formation are the enviromental and personal resources in the context of the negative environment impact. The article the empirical adaptive startegy determinants of shift workers in Arctic analyze. It determined that shift workers of oil and gas production employ economical stereotyped adaptation strategy.
Well Placement and Reservoir Characterization Advancement in VTSM Field With New Multiple Boundary Delineation Technique
Authors: Lutfullin A. A. , Bregida A. A. , Tomchik M. V. , Kozlov V. N. , Shabalinskaya D. D. , Belyaev A. S. , Makhambetov A. S. , Shirshov A. Y. , Kim V. E.
Published: September 2014

The planned production attainment, and correspondingly economical feasibility of hydrocarbons production in BP16 suite in Vostochno-Tarkosalinskoe (VTSM) field directly depends on successful placement of horizontal section. The reservoir is highly heterogeneous and Well Placement is utilized not only to maximize the reservoir exposure, but also for supplementary exploration and understanding of the complex geological settings. The information obtained in the process of Well Placement is used with the purpose of detailed geological modeling, which defines further field development plan.

BP16 suite is represented by turbidites, which dictates application of modern logging while drilling (LWD) technologies and Well Placement techniques. However, all previously utilized technologies have reached their limit in their capability of formation description. More specifically, significant lateral variations make utilization of standard triple combo measurements (Gamma Ray, resistivity, density and neutron) insufficient. Multiple unconformably deposited layers and localized bodies create a considerable challenge for interpretation of azimuthal data (images) and pose some limitations on the inversion of directional electromagnetic (EM) measurements, obtained while drilling with the bed boundary mapping tool.

The new multiple boundary delineation technique was used while drilling to improve understanding of the layers extent, apparent dip and unconformable bedding. This technique is based on the stochastic inversion of extended set of deep EM measurements. The inversion resolves for formation electrical anisotropy, formation dip and allows for mapping of multiple boundaries in real time.

This paper is describing the experience of drilling horizontal wells in the VTSM field, where the multilayer inversion technology was used for Well Placement for the first time in Russia. The new technology was utilized not only for Well Placement, but also to obtain detailed information on geological settings around the wellbore. Geological modeling was later rectified based on this information and used for field development plan justification and formation pressure maintenance (FPM).
An Approach to Tight Paleokarst Zones Identification Based on Integrated Use of 3D Seismic Surveys, Core and Well-Log Data and Implication to Reservoir Quality
Authors: Skvortsov Anton , Kuleshov Vladislav , Ajiboye Moses , Agafonova Olga
Published: September 2014

Paleokarst system structures form an important type of carbonate reservoir, and are product of surface karst processes, further sediment compaction and diagenesis, all of which can contribute to the heterogeneity development and compartmentalization of a carbonate reservoir. One of the most important conditions is when the cave is filled by solid minerals such as anhydrite. Filling of the cave by Minerals and further compaction during area subsidence can destroy much of the original cavern porosity and significantly decrease the reservoir quality of the formation. For this reason, during the design stage of exploration and production drilling, it is necessary to pay attention on the pattern and distribution of paleokarst systems, make an assessment of their impact on reservoir properties which might affect the reservoir quality.
Digital Core Analysis for Flow Process Evaluation is Myth or Reality?
Authors: Shandrygin Alexander N.
Published: September 2014

Digital core analysis (DCA) based on 3D tomography of core samples is widely used for study and description a internal structure of rocks. At present time we can observe a lot of attempts to implement DCA for solving of special problems of multiphase and multicomponent fluids flow in porous media, especially for estimation of relative permeability and oil displacement efficiency by various agents for EOR tasks. But there are some restrictions for replacement of real special core analysis data (SCAL) by DCA results. This paper is devoted to the answer on the question: "can the DCA results reflect the real processes going in scale of core sample. A difference between results of flow parameters measured by DCA and SCAL are demonstrated, especially for value of efficiency displacement and phase permeability.
Use of Channel Fracturing Technology Increases Production and Reduces Risks in Horizontal Wellbore Completions - First Experience in Russia, South-Priobskoe Oil Field
Authors: Doctor Sergey A. , Tolmachev Alexey , Chebykin Nikolay , Yudin Alexey , Roukhlov Valery , Gromovenko Alexander , Mathur Anil
Published: September 2014

South-Priobskoe field is in process of active development for over 10 years at the moment. Main producing horizons are low-permeable sandstone formations AS10-AS12 of Neocomian age. Hydraulic fracturing in the vertical wells proved to be effective way to increase oil production and provided profitable development of the oil field for several years period. Many wells had commingled production from 2 or 3 layers; each of the layers was stimulated separately. However, recent shift of drilling and development activity towards edge areas of the field led to reduction in formation quality and seldom well intersects more than one productive interval nowadays.

Most effective way for such geological conditions is combination of horizontal well drilling development and multi-stage fracturing. This concept was successful applied worldwide for number of years and recently fulfill expectation at South Priobskoe field in Russia as well. Enhancement of oil production jointly with drainage scheme optimization allowed to decrease amount of wells and associated costs for infrastructure and well completion. Main weaknesses of this approach are increased screenout risks during fracturing operation and additional costs for horizontal wellbore cleanout in such a case.

Implementation of channel fracturing technology became the next step of production optimization and well completion cost reduction. New method allows increasing reliability of proppant placement while improving fracture conductivity. These results are obtained by pulsing proppant on surface in conjunction with specialized equipment and fibers. New technology was implemented in 110 vertical wells over Russia including positive experience of channel fracturing campaign in 3 wells in South-Priobskoe field.

This article describes Russia's first project of multistage stimulation (MSS) combined with channel fracturing technique applied in horizontal well. New approach allowed minimizing screenout risk, reducing completions costs and at the same time improving conductivity of hydraulic fractures. First production results showed increase in well productivity of over 15% compared to the neighboring horizontal wells stimulated by conventional MSS technique.
Hysteresis of Relative Permeabilities in Water-Gas Stimulation of Oil Reservoirs
Authors: Kokorev V. I. , Karpov V. B. , Darishchev V. I. , Akhmadeyshin I. A. , Bugaev K. A. , Shchekoldin K. A. , Dedechko V. A. , Polischuk A. M. , Shelyago E. V. , Yazynina I. V.
Published: September 2014

The paper presents the study of the water-gas stimulation process with alternate injection as applied to the core samples from the Vostochno-Perevalnoye oil field located in West Siberia. The test data analysis showed an increase of oil displacement efficiency due to gas displacement of oil and the dependance of relative permeabilities not only from the saturation history (hysteresis) but also from the number of water-gas stimulation cycles. The authors noted the hysteresis of relative permeabilities to be a significant factor requiring consideration when conducting experimental studies of relative permeabilities and computer modeling of the water-gas stimulation process.
Dynamic Modeling of Samotlor Field Using High Resolution Model Grids
Authors: Tolstolytkin D. V. , Borovkov E. V. , Rzaev I. A. , Bogachev K. Yu.
Published: September 2014

Effective field development planning for giant fields as big as Samotlor in Western Siberia faces a number of challenges. Samotlor field has almost 50 years of production history, and is known for its complex multi-reservoir geology, active gas cap, sophisticated waterflood program of giant proportions, and has more than 14 thousand wells. The field of such complexity and magnitude cannot be developed without a full-field hydrodynamic model covering the entire reservoir.

Historically, due to extreme complexity, only highly upscaled models have been used. These models were primarily used for calculation of the remaining reservoir energy, material balance analysis, gas cap migration, but never had enough spatial resolution to allow for simulations at the well level.

To make plans for infill drilling and various workovers, the most production units were relying on sector models, which did have necessary spatial resolution, but had obvious limitations in the areal coverage of the field. As a result, due to the differences in grid resolutions, the results obtained from history matching of sectors were rarely used for full-field model causing frequent inefficiencies and redundancies in simulation workflows.

In a course of planning work to develop the remaining oil reserves of Samatlor field, a new "unified model" concept has been developed. In this concept, one and the same model is being used both for global optimization of full-field model as well as for making decisions at the level of individual wells. To determine optimal grid resolution, models with 5, 40, 160 and more than 400 million active grid blocks were selected, and simulation results compared. For the first time, a new hydrodynamic model based on un-upscaled geological grid of AV1-5 reservoir group of Samotlor field was simulated. By taking into account the number of wells and the length of the production history, this is probably the most complex simulation of reservoir dynamics ever attempted in the oil&gas industry.
Tackling of a Complex Carbonate Field Through a Dedicated History-Match Scheme and Software
Authors: Pauget Luc , Pignot Benjamin , Dzhafarov Denis
Published: September 2014

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

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

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

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

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

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

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

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

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

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

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

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

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.
On the Importance of the Quality of Conceptual and Engineering Design of Marine Structures used in the Development of the Russian Arctic Offshore Petroleum Resources
Authors: Zolotukhin A. , Papusha A.
Published: September 2014

It is known that one of the characteristic features of operating facilities in marine oil and gas fields in the Russian Arctic seas is their interaction with ice formations (icebergs, hummocks, their fragments, ridges, etc.). This kind of exposure is accompanied by plowing (gouging) the seabed, leading to significant damages of its surface in the form of grooves and plowmarks. Generated static and dynamic loads on the infrastructure facilities such as artificial islands, gravity and fixed platforms, subsea pipelines, elements of port facilities etc. can pose a real threat to their operation.

The paper presents different, in terms of hardware implementation, methods of investigation of the following interactions: of artificial island built on extremely shallow Arctic shelf with sedimentary rocks, including permafrost rocks;of subsea gas pipeline with ice formations (fields) in Arctic conditions.

The first part of the report covers the following issues: construction of artificial gravel island on extremely shallow Arctic shelf with seabed sediments;strength and stability of the seabed rocks, taking into account the permafrost substrate under the island;permafrost thawing due to operation of the Arctic field using an artificial island, and includes the relevant design calculations.

The second part deals with the analysis of the stability and strength of large diameter subsea gas pipeline, laid in sedimentary rocks of the shallow Arctic shelf while seabed is plowed by hummock or iceberg keel and keel collides with the pipeline body. Here, we also consider the possibility of underwater pipeline "sweep" by hummock or iceberg.

The paper also describes the basic design decisions, such as artificial islands and underwater gas pipelines, safety of which is confirmed by analysis of exposure to ice formations. As a result of our studies, a map of the Russian Arctic offshore area is plotted with marked zones characterized by increased risk of exposure of the studied facilities to potential hazards. This map takes into account the depths of the seas of the North-Western Russian Arctic zone, publicly available data of the Arctic and Antarctic Institute (AANII), as well as publications of researchers in the region.

We note that the developed method for assessing the strength and stability of underwater gas pipelines in junction areas of onshore and offshore segments, as well as the stability of artificial islands on the shallow Arctic shelf may be used as the basis for developing regulations to design oil and gas infrastructure facilities in the Arctic.
Integration of Methods for Forecasting and Identification of Rock Faults and Fracture Zones to Reduce Risks at their Crossover during Extended Reach Drilling of Long Horizontal Sections (6000 m) in Yuri Korchagin Field
Authors: Golenkin M. , Shtun A. , Khaliullov I. , Sadykov L. , Zakharov I.
Published: September 2014

This article is based on results of drilling wells in Yuri Korchagin field. Interpretation of the obtained data derived the conclusions that will help to stake future wells in better geological conditions and minimize risks during construction of wells.