bluuebunny/crossref_metadata_2025 huggingface dataset:
Assessment of the risk of accidents and hydrocarbon spills on the offshore facilities of the Shtokman gas condensate field development in the Barents Sea
Authors: Jouravel Valentine
Published: October 2012

The report presents the state and results of hazards and risk assessment for the development of the Shtokman gas condensate field (SGCF) in the Barents Sea.

The harsh natural conditions, significant amounts of hazardous substances and the complexity of the project make the necessary detailed assessments of hazards and risks to the identification, understanding, consideration, elimination and/or mitigation the risks as well as the demonstration of the achieved project safety to the public, the authorities and the international partnership. Understandable lack of experience of Russia's offshore oil and gas developments makes hazard and risk assessment and management a significant area of international cooperation.

The report focuses on the risk assessments of major accidents during the construction of offshore facilities, including the drilling of wells with newly-built drilling rigs, operating subsea production system (SPS), ice-resisting floating process unit (FPU), subsea infield and trunk pipelines, shipping and transport of liquid hydrocarbons. Attention is paid to the identification, evaluation and application of international data on failures and accidents during drilling, offshore construction, gas and condensate production and transport.

The report identifies the main sources of probable hydrocarbon spills, specify their character and volume. Hydrocarbon spills behavior and spreading is investigated by modeling with a due account of the observed region specific meteorological, sea and ice conditions. By this zones of potential impacts of spills and the threat of pollution of shorelines and coastal protected areas is identified.

The basic data for planning for hydrocarbon spill response and coast protection (OSR) are obtained with recommendations on the organization and dimensioning parameters of the spills combating system.
Production Monitoring System Application Development in TNK-BP
Authors: Muslimov E. Ya. , Medvedev P. V. , Pchelnikov R. L. , Strugov A. A. , Rekov S. V.
Published: October 2012

The current problem related to poor-quality control of artificial lift operational parameters can be solved by means of development and application or real-time monitoring, control and analysis systems.

As one way to solve this problem, TNK-BP has implemented the real-time SRP monitoring system.

The SRP monitoring system is a specialized SCADA and expert system for SRP. The system displays and analyzes the information from the controllers, gives a possibility of remote control by means of controllers on the wells. SRP controllers are installed on the well sites in order to gather and analyze the data received from the transducers for SRP monitoring and operational control. The controller technology is based on processing a dynagraph for each pump jack stroke, which enables to ensure SRP control as per the rated parameters settings, diagnose the SRP condition, change the operational mode depending on the influx from the formation.

To date the flow rates are measured periodically (once or twice a day), which is not enough.

The monitoring and diagnostics system enables to receive real-time pressure data from the submersible transducer and use this information for automatic calculation of "instantaneous" flow rate. For this purpose the Company carries out pilot projects to try out the submersible telemetry systems (Russian-made) with additional transducers that record pressure and fluid temperature at the submersible pump discharge end and their transmittal to the external devices. Russian manufacturers of submersible telemetry are taking initial steps in producing telemetry systems with additional transducers.

Also, in field development the oil companies face the problem of solids flow-back from the wells.

The use of ultrasonic transducer to evaluate amounts of solids flown back from the well and their type is the most advanced practice. Ultrasonic transducer for solids detection has the following technological advantage: it enables to ensure optimal rate for the complex wells stock by means of data-based control and prompt real-time response to changes.

In this paper the authors described application of such systems.
GIS Technology - A Modern Tool for the Implementation of Environmental Monitoring Programs of JC "Rusvietpetro" LLC in the North-Hosedayuskiy A. Slivki Oil Field: Integrated Environmental Management at the Enterprise
Authors: Glad`ko A.
Published: October 2012

Joint Russian-Vietnamese Company "Rusvietpetro" was established in 2008 to develop oil fields in Russia, the founders of the Company are "Zarubezhneft" PC and "Petrovietnam" OGC.

The operating area is located on the north-eastern section of Bolshezemelskaya tundra (eastern part of the Pechorskaya lowland), which is a hilly plain, cut by a dense river network, with numerous morainal hills and ridges. Natural zone - sub-arctic tundra. The area is virtually unpopulated.

Being aware of its responsibility to preserve a favorable environment and rationally manage natural resources, Management of the Company regularly and systematically fulfills all the requirements of licensing agreements. Significant amounts of funding for environmental programs are considered by the company to be great investments in the future and the guarantee of the environment quality of the regions in which it operates.
Problems and Solutions for Shallow Heavy Oil Production
Authors: Ibatullin R. R. , Ibragimov N. G. , Khisamov R. S. , Zaripov A. T.
Published: October 2012

To-date, more than 450 heavy oil fields and deposits have been identified in the Republic of Tatarstan with oil-in-places ranging between 1.4 and 7.0 billion tons, according to different estimates. Thermal recovery has proved itself as a reliable method and seemed a logical solution however it did not work properly in vertical wells. Building on the experience of development of the Yaregskoye field (the Komi Republic, Russia) and oilsands in the Canadian province of Alberta, the focus was shifted on working out of recovery methods involving horizontal wells. Engineering solutions accounting for concrete geologic environment and the steam assisted gravity drainage method used for production of heavy oil aim at high-quality casing, leak control in the interstring space, sand control, etc. In shallow heavy oil reservoirs with variable oil saturation of utmost importance are production control practices to ensure profitable oil production, to maintain optimal steam-oil ratio and safe operating pressure to ensure cap rock integrity.
Technique and Results of Complex Laboratory Researches of Anisotropic Filtration and Capacity Properties in Cores
Authors: Kadet V. V. , Dmitriev N. M. , Kuzmichev A. N. , Tsybulskiy S. P.
Published: October 2012

In recent years the fields with hard recoverable reserves of hydrocarbons are increasingly involved in the process of developing. Problems of hydrocarbons extraction are often associated with a complex structure of the reservoir which tending to exhibit anisotropy of the filtration properties. Therefore, while researching filtration flows consideration of the anisotropy has both practical and scientific interest. The main source of information about the structure formation and properties is a core material extracted from drilling wells.

In this paper a laboratory technique for determining the absolute permeability tensor in the core has been presented for different types of anisotropy. Technique for determining the lateral anisotropy and further permeability tensors from core is based on propagation of ultrasonic waves velocities being measured through the lateral surface of the core. While using this method at first the existence of the lateral anisotropy is established, and then the type of anisotropy in core is determined. Further according to type of anisotropy established the required number of cores for the hydrodynamic and possibly other researches is sawed from the sample rock.

In this paper the results for determination of the absolute permeability tensor and capillary pressure obtained with the technique proposed have been presented. These results confirm the tensor nature of the absolute permeability, effective diameter and luminal. Determination of phase permeability tensors, limiting gradients and non-linear filtration laws are also possibly within the frames of technique described.

Allowance of the anisotropy of reservoir properties gives more adequate picture of the distribution filtration flow in the reservoir. It allows you to optimize the direction of horizontal drilling, to rationalize development system (placement of wells) and eventually to increase oil recovery.
Project Approach to Staff Training for Divisions, Performing Design and Survey Works on Development of Oil and Gas Fields
Authors: Latyshev Andrey Sergeevich
Published: October 2012

The analysis of problem modern oil engineers training is carried out. On the example of scientific research project institute, approaches to implementation of effective development programs and staff training are considered.

The author expresses appreciation and gratitude to: Andrey Yuryevich Dmitriev, PhD in Technical Sciences, Vice-rector Director of the Institute of Natural Resources of NR TPUMikhail Olegovich Pisarev, Director of the DI PP of NR TPUKonstantin Yuryevich Maksyutin, Deputy Director for Professional Development of PLC of the INR of TPU
Integrated Reservoir Modeling of Two Urengoy Gas Fields
Authors: Mustaeva S. , Vasilev V.
Published: October 2012

The paper presents the integrated reservoir simulation and optimization results of two onshore gas fields. The fields are tied to common separator node, and have the similar gas in place volumes and production potentials. The optimal production plan for each field is the goal of the simultaneous development planning. Usually, separate field development plane does not consider surface facilities constraints, so overestimates the gas production amount and project lifetime. However, integrated "reservoir-well-pipeline".model allows to optimize the production system and reach the maximum gas production from each field. This paper presents the two gas field production optimization algorithm, also several development strategies with common production facility constraints are discussed with results. The optimal two-field simultaneous development plan is calculated on integrated computer model taking into account production system constraints.
Geant4 for Solving Nuclear Geophysics Problems
Authors: Velker N. N. , Banzarov B. V. , Inanc F. , Simonov N. A.
Published: October 2012

The results presented in this paper are based on computational experiments aimed at modeling nuclear well-logging tools. Well-logging services require not only development and characterization of nuclear logging tools but also development of algorithms for interpreting measured data with inclusion of various environmental corrections. With nuclear tools, the only feasible way of accomplishing those tasks is using computer simulations based on the radiation transport theory and Monte Carlo methods. Commonly, nuclear well-logging community uses the Monte Carlo N-Particle transport code (MCNP) for such modeling. However, MCNP is not universally available. Therefore, as an alternative, we consider the Geant4 platform developed under the auspices of European Organization for Nuclear Research (CERN) for modeling high-energy physics experiments. The results of various benchmarks of the amended version of Geant4 against MCNP5 are presented. These results clearly indicate that the modified version of Geant4 is capable of solving nuclear geophysics problems with the same accuracy as MCNP.
Applicability Appraisal of the Multiphase Transport Technologies of Associated Petroleum Gas in the Arctic Shelves of the Russia
Authors: Levin I. V. , Glazkov O. V. , Malyshev S. A.
Published: October 2012

In this paper is given an estimate to the resource potential of the Artic shelf of the Russia and prospects of its development. The comparative analysis of multiphase technologies of wellstream gathering, applicable for conditions of Arctic shelf on an example of fields of the Barents and Kara Seas, is carried out. Various aspects of the joint transport system application of gas hydrates and oil on one pipeline for solving the problems of associated petroleum gas utilization on an example of the Artic shelf fields are considered.
Well Test for In-Situ Determination of Oil and Water Relative Permeabilities
Authors: Zakirov S. N. , Indrupskiy I. M. , Zakirov E. S. , Anikeev D. P. , Vasiliev I. V. , Severinov E. V. , Gaidukov L. A. , Rodionov A. E. , Lachugin D. S. , Tsagan-Mandjiev T. N.
Published: October 2012

Relative permeability data are very important for reservoir engineering, because these parameters highly influence waterflooding efficiency, oil/liquid production forecast and therefore economics of an asset.

Core experiments for determination of relative permeability curves are point-wise and do not completely reconstruct formation conditions. Application of core relative permeabilities on field scale may lead to inadequate modeling of real flow conditions and result in actual production not complying with forecast during commercial exploitation.

Current structure of Russian Federation oil resources is such that most of the promising oil and gas regions are at full autonomy conditions, with lack of year-round road connection and infrastructure for production transfer. Thus, new techniques are required for acquisition of parameters important for reservoir engineering (including in-situ relative permeabilities), which are well-suited to production limits during pilot field study program.

A promising approach to in-situ determination of flow parameters is well testing. A well test technique for determining oil and water relative permeabilities developed at OGRI RAS is based on generation of multidirectional two-phase flows and provides data for determination of an extended set of formation characteristics. Interpretation includes special algorithms and software with application of numerical methods for direct problem solution and optimal control methods for inverse problem solution.

Well test for determination of in-situ relative permeabilities described in the paper has been performed at an oilfield in Western Siberia at conditions of arctic climate and full autonomy.

Results of the well test led to: ♦correction of relative permeability data earlier obtained from core analysis,♦establishing higher water mobility in full range of water saturations and probably no increased threshold of water mobility (critical saturation);♦adjustment of oil and liquid production plan for full field development project, which resulted in more reasonable estimation of asset investment attractiveness and optimal decision on recovery strategy.
Selection of the Optimal Type of Fractured Well Completion Based on Simulation of Highly Heterogeneous Reservoir
Authors: Gataullin T. I. , Eliseev P. I. , Zavalin F. S. , Lutfullin A. A.
Published: October 2012

The basic method for oil-saturated, low permeability, anisotropic reservoir is hydraulic fracturing. Currently, the technology of a multi-stage fracturing in horizontal wells (hereinafter - the Multifractured HW) is rapidly developing, allowing the creation of several fracs in several areas of the horizontal well within the one workover.

In this paper the sequence of actions designed to calculate the targets of development with the Multifractured HW and for comparison with grids of vertical fractured wells. The main problem of calculating the field development plan with the system of the Multifractured HW on full field simulation model is the lack of reference to both the input flow rates of wells, and the dynamics of decline. To set up a simplified representation of such wells in the full simulation model the detailed sector model was created for different types of completions: Multifractured HWFractured vertical well

The sector simulation was run for different reservoir properties, and the dependence of the flow rates ratio in the pseudo-steady state flow was calculated.

The paper presents the results of Multifractured HW drilling, comparison of design and actual performance, the lessons learned.
Computation of Reservoir Properties Based on 3D-Structure of Porous Media
Authors: Korost D. V. , Gerke K. M.
Published: October 2012

Pore structure is one of the main factors defining reservoir properties of rocks. Conventional estimations of such properties using only limited 2D data from thin sections using different approximations are usually inaccurate.

In recent decades different numerical methods were developed to quantify flow and other physical properties on micro-scale. Each method has its own advantages and drawbacks, so utilization of more than one of approaches is reasonable, depending on the study case.

Recent progress in X-ray micro-tomography and some other techniques allow precise determination of three-dimensional structure of rocks, however, a trade-off between resolution and sample size is usually unavoidable. Some amount of porosity (we call it "under-resolution") is usually not visible on X-ray scans or thin-section low resolution images. Unlike permeability, it may play an important role in resistivity, capillary curve shape and other properties.

The main aim of this contribution is to verify petrophysical modeling approach on a collection of sandstone samples with wide range of pore space configurations. At first, our 3D structure obtaining method using X-ray microtomography is justified via detailed laboratory vs. tomography porosity measurements comparison. Next, permeability is determined for all samples using network-model extracted from 3D structure scans. Calculated formation factors and capillary curves in many cases deviated from experimental values, especially for samples with high under-resolution porosity. The influence of invisible porosity is also supported by coordination number correlations with other physical properties for sample within the same group (same reservoir type). To account for under-resolution pores invisible on X-ray scans different approaches can be utilized based on artificial addition of under-resolution porosity into numerical sample: NMR measurements, mercury porosimetry, or stochastic reconstructions from high resolution 2D cuts.
Effective Management of Pilot Projects
Authors: Alekseeva V. A. , Karfunkle J.
Published: October 2012

Each year, the market offers new technologies and approaches, which, provided they are properly introduced, can make a positive contribution to business development of oil companies in depleting brownfields and greenfields with complicated conditions. Production increments supported with conventional technologies have been on decline from year to year.

This work offers approaches to managing the process of searching, introducing, and monitoring optimum technologies providing for economically feasible access to reserves, oil recovery enhancement, and cost reduction, which can be used by oil and gas companies to improve their performance.

In view of current and future field problems, the following technological priorities have been defined: oil recovery enhancement techniques, effective drilling, seismic surveys, water flooding, etc.

Key instruments of technology strategy implementation include methodology, process regulations, and information systems for assessing efficiency of decisions taken.

In order to develop the innovational culture, it would be desirable to hold regularly regional and corporate Technology Forums, develop knowledge bases that would ensure exchange of experience and development of personnel competencies.

To evaluate pilot project results, information systems should be introduced, which would provide for monthly monitoring of pilot project performance evaluation criteria.

If a technology is successfully tested in the course of the pilot project, broad-scale scaling-up of this technology is started. It implies updating the technology scaling-up potential, general forecast of economic results, and scaling-up program monitoring during the year.

Risk mitigation and success of the new technologies program depend on managing the initiation, monitoring, and personnel motivation process.

Introduction of proposed methodologies, processes, criteria, and information systems for prompt evaluation of pilot project results during wellwork operations helps take timely and high-quality management decisions in the course of implementing the new technologies program, which is important for companies holding a balanced portfolio of oil brownfields and greenfields, gas fields, and fields with unconventional hydrocarbon reserves.
Geosteering: Experience in Practical Use at the Ust-Tegusskoye Field, Analysis of Efficiency
Authors: Ustinova Larisa , Makarova Ekaterina , Sokolov Artem , Osepyan Suren
Published: October 2012

The paper reviews practical applications of geosteering to horizontal well drilling and evaluates its efficiency for horizontal drilling. On Ust-Tegusskoye filed more then 30 horizontal wells were steered using 3D geological model.

One of key problems in geosteering process is limited ability to understand the location of the wellbore relative to the target object (productive layer, sand interval). The traditional set of data – structural maps build from seismic and pilot wells does not allow building fine structural capable to ensure successful drilling. But building the modeling workflow allows to simulate many possible locations of horizontal wellbore between top and bottom of reservoir, find the most probable location and minimize risk of unsuccessful drilling. Local update of the geomodels in the relatively small regions containing newly drilled wells helps getting production forecasts from flow simulator in reasonable time.

Recently large attention is paid to developing innovative approaches to the steering of horizontal wells.

The key requirement to the geosteering process today is landing well trajectory not only into pay part of productive layer, but into most efficient part of reservoir with minimal penetration of dense sub layers. For that the whole set of technological solutions exists ranging from optimization of pilot wellbore locations and finding best possible well profiles on geological and flow simulation models to the real time geosteering.

On Ust-Tegusskoye field the number of drilled horizontal wells grows every year: in 2009 there were 3 wells, in 2010 - 5 and in 2011 - 15. At the first half of 2012 9 horizontal wells were drilled (Figure 1). Minimal thickness of target layer for horizontal wells is 2.5 m. Maximum length of horizontal part is 832 m.

In spite of continuous improvements in drilling technology the problem of finding borehole position within top and bottom of target layer is still actual. Standard set of G&G information – seismic based structural surfaces and pilot wells does not allow building geomodel with reliability required for successful steering of horizontal well. Wrong positioning of well trajectory make cause it to deviate from target layer – so effective length of the well will be significantly reduced.
Electromagnetic sounding in deviated and horizontal wells: mathematical modeling and real data interpretation
Authors: Epov Michael I. , Suhorukova Carina V. , Nikitenko Marina N. , Gorbatenko Aleksey A. , Arzhantsev Vitali S.
Published: October 2012

The features of numerical VEMKZ data interpretation in deviated and horizontal wells entering oil-saturated and water-saturated formations are observed. On the basis of mathematical modeling of VEMKZ signals for typical hole path of horizontal wells the effects caused by crossing bed boundaries and thin layers with high resistivity are shown. The influence of electrical anisotropy on signals has been investigated. The influence of borehole rugosities and tool eccentricity was studied. The programs of numerical modeling have been developed at Institute of Petroleum Geology and Geophysics (IPGG) Siberian Branch of Russian Academy of Sciences.

Algorithms and methodological procedures are used for numerical interpretation of VEMKZ data (including SKL set data) in case of thin reservoir, electrically contrasting shoulder beds and thin interlayers. The eccentricity, borehole rugosity, sine-shaped and spiral well bore influence on signals was investigated in case of typical hole and tool diameters, the programs of numerical correction have been developed. The fact that influence of electrical anisotropy in deviated well causes apparent resistivity increase is demonstrated. Numerical inversion VEMKZ data obtained in well entering terrigenous reservoir under-lied by thin layer with high resistivity have been processed. Starting model for inversion is generated by taking direct current data into account. Examples of real VEMKZ data interpretation are demonstrated.

For investigations in deviated and horizontal wells the approach for finding true formation resistivity in thin reservoir using high-frequency induction measurements was proposed. This approach based on numerical signal modeling for deviated tool in horizontally-stratified earth. Algorithms for electrical anisotropy evaluating and thin-layer parameters estimating are observed.
Geological Modeling of Fractured Carbonate Reservoir of Paleozoic Basement in Western Siberia with Application of 3D Seismic Data
Authors: Pylnik S. V. , Shaporenko S. N. , Babov V. N. , Shtokolova M. N.
Published: October 2012

The methodology of geological modeling of fractured carbonate reservoir of Paleozoic basement in Western Siberia with application of 3D seismic data is described. The construction algorithm of three-dimensional seismic trends and the using methods of these trends for modeling are presented. The facies model of the reservoir and the structural-tectonic analysis methodology are described. History matching results which are presented at the end of the paper show the correctness of the used technique.
Uncertainty analysis as decision making tool for green fields of Yamal region
Authors: Biryukov S. D. , Zakirov I. S. , Severinov E. V. , Gaidukov L. A. , Miroshnichenko A. V. , Kudlaeva N. V. , Endalova Y. V. , Chameev I. L.
Published: October 2012

The new green fields of Yamal region and Eastern Siberia today is one of the important areas for oil production during next 10 years. One of the key problems of field development in these regions is poor infrastructure and lack of input data of geology, target formations and fluids properties. For decision making during field development preparation stage its necessary to carry out estimation of possible scenarios.

Analysis of uncertainty will provide a range of changes in reserves and oil production profiles which can help to estimate economical part of field development project. Also these results can be used for design pipe lines and surface facilities.

Authors of paper suggested the approach how to estimate uncertainties in cases of lack input data of formation based on data of Russkoye oil field.
Accounting VTI Anisotropy in the Performance of Pre-Stack Depth Migration On West Siberian Data
Authors: Khromova I. Y. , Grechishnikova T. A. , Nadezhkina D. Y.
Published: October 2012

These days "simple" oil fields and reservoirs are well researched and oil companies face a complex task of improving the accuracy of the study of small capacity collectors, or fractured reservoirs. These new challenges require new methods for processing and interpretation of seismic data.

Significant velocity anomalies are usually observed in areas with complex geological structure, e.g. in the presence of faults, salt-dome tectonics, or steep dips of the reflecting horizons. Time migration in such environments can not get a reliable image of the complex geological structures. Its resultis distorted due to underestimated lateral velocity changes. Successful method of restoring the correct structure of the environment in complex geological conditions is a pre-stack depth migration. During depth migration seismic data are transformed to depth image of the geological structure, with correctly positioned reflecting boundaries and correct dips due to rightful consideration of seismic-wave refraction/. Comparison of the results of time and depth prestack migration is presented in Figures 1 and 2.

These days, we are using a large number of algorithms to perform pre-stack depth migration, whether based on ray tracing methods or the wavefield restoration: classical Kirchhoff migration, migration of full-wave solutions on the basis of the wave field (WEM), reverse time migration (RTM), different variations of Gaussian Beam, etc. Which algorithm is used usually depends on the geological structure of the area and processing goals. One of the determinants for pre-stack depth migration performance for each algorithm is the quality of deep-velocity model.
Salym Petroleum Development: Experience and Lessons in WRM on Salym Group of Fields
Authors: Alexeyev A. , Volokitin Ya. , Karnaukh D. , Domnin E. , Bydzan A. , Pickles M.
Published: October 2012

Reservoir monitoring in the course of current field development is the key factor for continuous short-term production optimization and achievement of best economics throughout the lifecycle of the field. Therefore, Salym Petroleum Development (SPD) carries out a set of actions focused on controlling current development parameters.

The report describes the processes of planning, geological and downhole logging data acquisition and methods of interpretation thereof during the active development phase of the Salym group of fields. Key emphasis is assigned to analysing the efficiency of different methods for solving the key tasks of development control.
A Robust Method to Quantify Reservoir Connectivity Using Field Performance Data
Authors: Krasnov V. , Ivanov V. , Khasanov M.
Published: October 2012

An improved method of well-to-well connectivity evaluation is proposed. The method is based on combination of two approaches developed by now - capacitance model (CM) and Multiwell Productivity Index (MPI). Multiwell productivity index is evaluated independently of production data basing on well location geometry and average reservoir properties. Connectivity coefficients, derived from MPI are used as constrains when searching for CM solution. Following the physical meaning of the problem the capacitance model is improved by adding a constraint which was possibly overlooked by previous researches. These improves convergence of optimization problem which is inherent part of CM algorithm and enables to apply it to evaluate waterflood for real reservoir with more than 60 wells.

An injection and production rates as well as bottom-hole pressure data can yield a lot of valuable information about well interaction and therefore, reservoir characteristics, if they are analyzed properly. For example, such analysis can reveal a preferential flow direction throughout the field or quantify interaction of injector to surrounding producers that enables to reduce ineffective water circulation. Proposed method combines CM and MPI approaches which both got their own advantages and drawbacks. Capacitance Model provides quite detailed analysis and quantifies the well interaction. Thus, it allows us to learn more about the reservoir structure as well as to optimize the waterflood, but it turns out to be unstable when applied to real data. Also it misses an important constraint connected with a physical meaning of CM parameters. The stability of CM can be increased by using an MPI approach. To this effect, we use analytical MPI values in construction of a regularizing functional within the CM's algorithm.

The method was applied to one of Rosneft fields to establish well interaction pattern. Recommendations were given to improve waterflood efficiency.
Memory Magnetic Imaging Defectoscopy
Authors: Arbuzov A. A. , Bochkarev V. V. , Bragin A. M. , Maslennikova Y. S. , Zagidullin B. A. , Achkeev A. A. , Kirillov R. S.
Published: October 2012

This paper presents downhole magnetic imaging defectoscopy (MID) in memory mode, its key principles, differences from other corrosion logging technologies, and some results of its application in oil wells.

The MID technology is designed to check the integrity of magnetic and non-magnetic tubing and casing strings in oil and gas wells. It can be used to detect various defects, corrosion and mechanical wear, and to assess the quality of perforations.

The MID tool contains two high-sensitivity sensors: a short generator/receiver coil and a long one with short relaxation times to analyse responses even at early times of 0.1 ms. The short coil generates a short, low-amplitude electromagnetic pulse and records a response from the first metal barrier, normally tubing, where as the long coil generates a long, high-amplitude electromagnetic pulse and records a signal travelling a much longer distance of up to 13 inches to record the total response from tubing and casing. Mathematical processing of these responses can determine the thicknesses of the first and second metal barriers.

An independent power supply allows logging to be performed on slickline, which substantially reduces operating costs and enables the use of magnetic imaging defectoscopy for well monitoring to prevent leak and corrosion related incidents and thus increase environmental safety in the field. The wide use of memory magnetic imaging defectoscopy will substantially reduce the number of well incidents and expenses for remedial jobs.
Improving the efficiency of oil and gas field development by optimizing the operation of injection wells
Authors: Ridel A. A. , Margarit A. S. , Garifoullina R. A , Mazhar V. A , Almukhametov M. A. , Petrov I. A.
Published: October 2012

Synopsis

Optimization of flooding - is a package of technological solutions, which includes analysis of operation of injection and production wells,."performance" of the flood front in combination with the analysis of geological view of fromation and remaining recoverable reserves.

Accurate choice and optimization of technologies of flooding defines the success of the effective development of fields.

In spite of to the state of knowledge of this process, its importance in oil extractio, makes its developers to pay more efforts for better understanding of pecularities of the flooding and improvement of the efficiency of the process. One of the issues, which require more detailed study, is forming of man-induced unsteady fracttures (auto-fracturing) during injection wells operation and their influence on the efficiency of the displacement processes.
First Russian Underground Oil Pipeline with "Skin-Effect" to Transport Jellying Oil
Authors: Grishagin A. V. , Kologreeva T. I. , Smirnov A. V. , Shashel V. A. , Vakulenko S. N. , Savinova I. V. , Kamashev R. A.
Published: October 2012

Following the problems related to transportation of high paraffine content oil at one of the fields of OAO "Samataneftegas" we have investigated rheological properties of well products with abnormally high temperature of solidification (+36°C).

The essential dependence of viscosity vs temperature in the interval of velocity gradients from 20 to 300 sec-1 was determined: at 20°C - from 2799 up to 356 MPa*sec; at 30°C - from 177 up to 67.8 MPa*sec; at 40°C – 14.1 MPa*sec (Newton); 50°C – 7.8 MPa*sec (Newton).

Thus it was revealed, what at temperatures lower than 25°C it is possible to face the issue of paraffin fraction depositions into a solid phase, as well as the jellying of the product. This has been proved by numerous complete shutdowns of 159 x 6 mm operating pipeline and significant expenses for its rehabilitation.

The results of rheological tests have predetermined the search of means that allow resolving this problem. The only acceptable strategy in this case (in view of connecting new licensed areas) was the one to use the system of pipeline heating.

Such systems provide maintaining the temperature of transported product by compensating the heat losses from pipeline surface to the environment.

The problem is in the following, that 210 x 6 mm oil pipeline (having the overall length of 13.5 km of which 12.8 km should be heated) planned for construction, should be laid in a trench at the depth of not less than 1.6 m to the upper surface of the pipe.

The designing of such an object and its commissioning was done in Russia for the first time. To heat the underground sections of the oil pipeline they have used SKIN-system based on "skin-effect" principle. The construction was carried out between December 2010 and October 2011. Pipeline was constructed between December 2010 and June 2011; installation of "skin-effect" system was done between June 2011 and October 2011.

Oil pipeline with skin-system (mainitaining the temperature of 40°C) was commissioned on 11.14.2011 and tested in extremely cold period of the year. Till now it has transported around 75 thousand cubic meters of well products (860 m3/day in average).
Using aerospace information for monitoring green fields in the Russian Arctic region
Authors: Sevastyanova K. K. , Shmakov V. V. , Nekhaev S. A. , Konygin A. E. , Stolbov S. A.
Published: October 2012

The article presents the concept of building and developing a corporate system of Earth remote sensing (ERS). Remote sensing from space has a significant advantage over the traditional information support technologies for existing business processes in most russian industries, including oil and gas industry, by reasons of high efficiency, productivity, operability and low cost materials.
Experimental Studies of Oil Recovery After Alkali-Surfactant-Polymer (ASP) Flooding with West Salym Cores
Authors: Skripkin A. G. , Kuznetsov I. A. , Volokitin Ya. E. , Chmuzh I. V.
Published: October 2012

Chemical EOR project in Salym Petroleum Development (SPD) aims to increase oil recovery factor by applying a mixture of alkali, surfactants and polymer (ASP). In West Salym field it is expected to gain increase in oil recovery of 10–20%. A successful ASP pilot was conducted by Shell in 1989 in several wells of White Castle field, LA, where 38% of oil left after water-flood was recovered by ASP flooding.

ASP method was first developed in early 80s in Shell, in Bellaire Research center, Houston, as a result of field testing of different chemical methods. Surfactant in the mixture reduces interfacial tension between oil and water, which leads to mobilization of resudual oil in porous medium of the rock. For efficient mobilization of oil the value of interfacial tension should be lowered down to extra-low values of 10-3 mN/m. Alkali is added in order to reduce adsorption of surfactant into the formation, which helps to bring down consumption of expensive surfactants. Polymer increases viscosity of the mixture, which helps to stabilize flow, improve sweep and displace viscous emulsion created in the formation.

Several companies are involved in the SPD project: surfactant selection is done by research department of Shell, core experiments are conducted in the Laboratory of Reservoir Physics in JSC TomskNIPIneft, Salym Petroleum Development N.V. manages and coordinates the project. Recently GazpromNeft Research Center joined the work on surfactant selection. The objectives of the experiments conducted in JSC TomskNIPIneft were: Determination of the optimal salt concentration for creation of the maximum volume of micro-emulsion in the mixture of oil and ASP cocktail based on phase behavior tests.Modeling of reservoir conditions of West Salym field and expected technological operations during injection of ASP solution in the core flood experiments.Determination of residual oil after ASP flood and its distribution along core column at various volumes of ASP slug, various concentrations of salt and alkali, and various polymer viscosity.
Causes of Decreased Condensate Recovery from Low-Permeable Formations and Ways to Increase it
Authors: Shandrygin A. N. , Yushkov A. Yu. , Glumov D. N.
Published: October 2012

The paper investigates the processes of condensate recovery from low-permeable formations during depletion-driven development of gas-condensate deposits. The studies were based on simulating multi-component flow of various gas-condensate mixtures in reservoirs with a large range of permeabilities. As a result, the key causes of decreased condensate recovery from low-permeable formations compared to "regular" reservoirs have been established. It was shown that for low-permeable formations, due to large pressure drawdown cones, the additional condensation of C5+ components because of an "non equilibrium" effect is possible, where the flowing gas phase is out of equilibrium to the retrograde condensate.

The main technological factors influencing the condensate recovery from low-permeable formations were identified, as well as possible ways to increase condensate recovery.
Approaches for Estimating Carbonate Fractured Reservoir Property Cutoffs
Authors: Kolganov V. , Kovaleva G.
Published: October 2012

In Russia, since 1972, core correlation relationship between connate water saturation cw and porosity αwc=f(m) is used for porosity cutoff estimation based on methods which have been generated to find property cutoffs: 1)method of effective porosity me=m(1-αwc)2)method of dynamic porosity md=m(1-αwc-αor), where αwc and αor–connate water and residual oil saturation

Estimation method of property cutoffs is as follows: plot petrophysical correlation relationship me=f(m) and md=f(m), which are usual as line functions with high correlation coefficient. Find graphically or analytically cross points of porosity axis and functions me=f(m) and md =f(m). Sections on this axis intercepted with points me=0 and md=0 are accepted numerically as porosity cutoffs.

Judging by foreign publications, correlation relationships me=f(m) and md=f(m) are used only in domestic practice of estimating hydrocarbon reserves and thus this method can be considered as Russian know-how.

Oil reserves estimated by the method me are in-place reserves, by the method md – producible reserves. Both options of correlation methods estimate matrix cutoffs for carbonate fractured reservoirs.
Memory pulsed neutron-neutron logging
Authors: Arbuzov A. A. , Alekhin A. P. , Bochkarev V. V. , Minakhmetova R. N. , Chukhutin D. V. , Zakirov A. N.
Published: October 2012

This paper describes the MINK tool which is based on pulsed neutron-neutron (PNN) logging technology, its key principles and differences from other logging and data interpretation methods, and illustrates its applications to estimating oil saturation in wells.

The principal feature of the MINK tool is its data recording technique in which all neutron-count decays are saved to memory and processed separately. In conventional PNN logging, 100 decays are initially accumulated and then averaged before processing, which results in information loss.

Theoretical considerations and available experimental data have indicated that the probability distribution of neutrons is governed by Poisson's law [1] and allows the use of the maximum likelihood method (MLM) for experimental data fitting [2] with a substantial advantage over the conventional least-square method (LSM). This was particularly important for reservoir characterisation, as the rock's response is mainly recorded at late times. Neutron count rates at late times are small, and the least square method becomes a hit-and-miss technique. The authors have developed algorithms and software for the efficient and reliable determination of single- and double-exponential approximation parameters using the maximum likelihood method.

The processing of data from three selected wells has shown that Sigma profiles determined by the least square method are noisier than those determined by the maximum likelihood method. Moreover, some thin reservoir units were not seen in Sigma profiles obtained by the least square method, in contrast to those obtained by the maximum likelihood method.

Statistical modelling has been performed to validate the developed algorithms. Decays with experimentally determined decay times and Poisson's distribution of neutron count decays have been generated. Modelling data processing has shown that the maximum likelihood method provides 1.7 to 2 times higher accuracy than the least square method under equal conditions or 3 to 4 times smaller data collection volumes.

The MINK technology is expected to determine the oil content in dense reservoirs and low-salinity wellbore fluids.
Refinement of a Geological Reservoir Model by Detailed Correlation
Authors: Mubarakova A. , Sudakov V. , Sidorov S.
Published: October 2012

It is very important to understand sedimentation in detail, both from the aspect of geological or petrophysical modelling and field development.

The correctly inferred distribution of a stratigraphic layer's boundaries pre-determines the fluid flow produced by the model to be close to the actual flow. Activities to enhance residual oil recovery are more effective if planned according to the detailed stratification, which means understanding of the geologic aspects of a single area.

The entire knowledge of region's geology and stratigraphy, and any available field data are applied during the correlation and almost all applicable open-hole logging techniques are useful for the purpose of correlation.

The correlation itself is optimised, split into stages and sub-stages to save time and minimise errors.
Spectral Noise Logging Data Processing Technology
Authors: Maslennikova Yu. S. , Bochkarev V. V. , Savinkov A. V. , Davydov D. A.
Published: October 2012

Rational development of oil and gas reservoirs is possible only with efficient monitoring by various well logging techniques. This paper presents algorithms for processing data acquired by spectral noise logging (SNL) in memory mode. The SNL technology is designed to identify flowing reservoir intervals, cross-flows behind casing and tubing and casing leaks by spectral analysis of recorded noise signals.

While moving through a reservoir, fluids and gases create turbulence and rock vibrations that in turn generate noise. This acoustic noise is recorded with a noise logging memory tool consisting of a high-sensitivity piezoelectric hydrophone sensor and an amplifier and data collection module. The tool records acoustic signals in the frequency range of 15 Hz to 60 kHz. The existing SNL technology excludes intense broadband noise created by the movement of the tool in the well.

Useful information is extracted from background noise using a technique based on wavelet thresholding. Spectral noise density in the depth-frequency plane undergoes a wavelet transform. At each measurement depth, several tens of noise signals are recorded to determine mean wavelet coefficients and their typical variance. Then, they are analysed to remove statistically insignificant details from the signal spectrum and to suppress noise components that are present throughout large depth intervals.

The processing of data acquired in tens of wells from various fields has show that the noise features identified by wavelet filtering correlate with open-hole data and are confirmed by conventional well logging techniques.