In order to enhance technology management model and planning, Gazprom Neft PJSC formulated technological strategy. This strategy focuses our efforts in taking a step further from ‘Smart buyer’ approach to ‘Strategic goal-setter’ that significantly influences industry’s technological development through partnerships. The company focuses now on fast search, adaptation and adoption of new technologies that are of priority to the company. To gain that, it is necessary to realize our technological challenges in order to expand resource portfolio access and maximize invested assets. The efforts are based on the fundamental principles that enable upstream technological planning. Technological strategy as itself is a critical component of Technology Management System which covers the entire technological chain, from a search phase, selection, testing and up to the full scale roll out.

To achieve the target effects of the technological portfolio it is vital to develop and configure the supporting processes, which are critical when transit to the "Intelligent customer" approach. Today, about 80% of the project portfolio is carried out through the purchase and adaptation of technological solutions of high readiness level. Knowledge and partnership management is the key processes to maximize the effects of technological project implementation. The development and implementation of these tools lead to flexibility in the formation and updating of the technological portfolio according to the changing external environment.

This article presents results of the development of integrated geomechanical modeling technology by means of the example of projects realized in Gazprom Neft. Current technological development along with transition to new sophisticated objects, require solutions which are based on multidisciplinary approaches to assessment of production uncertainty. Geomechanical modeling integrates geological data, data of geophysical surveys, seismic data in order to meet challenges at each stage of field life. As examples of successful implementation of Company’s geomechanical projects are Palyanovskoye, Novoportovskoye, Vostochno-Messoyakhskoye, Tsarichanskoye, Vyingayakhinskoye, Zapadno-Salyimskoye oilfields.

In particular, techniques of geomechanical modeling for conditions of the field Palyanovskoye have enabled to estimate drilling mud density, necessary for maintenance of well bore stability. Three-dimensional geomechanical models has enabled to define an arrangement of conducted faults leading to catastrophic absorption on the field Tsarichanskoye. Taking into account a data acquisition from drilling the results of modeling have led to reduce the time of well construction and increase the economic indicators of the project. Considering textural anisotropy and zones of abnormally high reservoir pressure enabled to optimize zones of initiation of hydraulic fracture and to avoid water breakthrough from overlying or underlying layers for the Vyngayakhinsky field. The fields of reorientation of tension predicted by geomechanical model for the field West Salym near tectonic violations and adjustment of an arrangement of hydraulic fracture enabled to estimate geometry and the direction of growth of the fracture, with the maximum scope of a productive interval.

The article presents that results of detailed geomechanical modeling enable to predict behavior of specific geological systems and optimize technological parameters. As a result, it is achieved a maximization of positive economic effect from specific wells operations and the field in general.

This article is about developing operational costs model. It is possible to use operational cost model on the different stages of project with differing degrees of uncertainty and risks. Strong correlation of capital and operational cost models gives opportunity to make comprehensive cost assessment with high degree of detalization.

Methodology analysis shows substantial deficit of multivariable evaluation of operational costs at the concept stage. There is no special software of operational cost evaluation in the market, which takes into account special aspects of oil and gas industry. Current methodology and cost tools can be characterized as labor-intensive process or inadequate level of accuracy. Thus Gazpromneft develops operational cost model with methodological recommendation and structured database of cost and technical parameters.

Today Gazprom Neft develops unique approaches and tools in the industry. New methods and tools give opportunity to make cost estimation with high level of detalization. Implemented operational cost model in close cooperation of the capital cost model allows comprehensive assessment of the technical and technological solutions during concept design.

In order to carry out cost model in the relevant condition, there is necessary to achieve a high level of automation. For this reason, Gazprom Neft decided to implement cost model on special IT platform. For now the future product framework has already selected. It will be web-application with cloud storage. This solution allows working with this software in online access.

References

1. Khasanov M.M., Sugaipov D.A., Ushmaev O.S. et al., Development of cost

engineering in Gazprom Neft JSC (In Russ.), Neftyanoe khozyaystvo = Oil Industry,

2013, no. 12, pp. 14–16.

2. Khasanov M.M., Sugaipov D.A., Zhagrin A.V. et al., Improvement of CAPEX

estimation accuracy during early project stages (In Russ.), Neftyanoe

khozyaystvo = Oil Industry, 2014, no. 12, pp. 22–27.

3. Ismagilov R.R., Maksimov Yu.V., Ushmaev O.S. et al., Integrated model for

complex management of reservoir engineering and field construction

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2014, no. 12, pp. 71–73.

4. Khasanov M.M., Sugaipov D.A., Maksimov Yu.V. et al., Cost engineering in

Gazprom Neft PJSC: current situation and future development (In Russ.),

Neftyanoe khozyaystvo = Oil Industry, 2015, no. 12, pp. 30–33.

In this article shown a workflow for developing own prototype of software program for well cost estimation at stages “Evaluation” and “Selection” of oil project in Gazprom Neft PJSC. According to the concept of prototype software development it was divided two basic parts in well cost estimations, they are technical and cost estimation. In technical part of prototype are included model of physical indicators calculation, database of general and typical technical designs and database of actual drilled wells on company’s assets. Software prototype provides different options of calculation depending on volume and quality of initial data for the possibility of its use on different project stages. Software prototype was developed based on VBA in Excel and technical specification for programming. In close collaboration of software developer and technical specialists modules was developed and programmed which are allow to predict physical volumes of well construction. Cost estimation part includes cooperation with cost database and algorithm of service rates determination. As a result estimation is formed with well cost forecast based on determined and specific parameters in technical modules. Today it is tracked ability to use this algorithm in brownfields for business planning of current activities for one to five years. Using a developed tool ‘limit in well cost’ was calculated.  The modeled result shown that actual minimum cost of well is higher than ‘limit in well cos’.

References

1. Khasanov M.M., Sugaipov D.A., Maksimov Yu.V. et al., Cost engineering

in Gazprom Neft PJSC: current situation and future development (In Russ.),

Neftyanoe khozyaystvo = Oil Industry, 2015, no. 12, pp. 30–33.

2. Pogadaev S.V., Sobolev A.O., Karsakov V.A. et al., Technical Limit: a

way to improve drilling efficiency (In Russ.), Neftyanoe khozyaystvo = Oil

Industry, 2015, no. 12, pp. 28–29.

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in understanding and performance, SPE 51181, 1998.

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This article covers the problem of identification of labor cost norms for implementation of engineering projects in oil and gas industry in the modern world. Complex approach to implementation of such projects requires systematic planning of labor, time and financial resources and lies at the intersection of two knowledge areas: Economics and HR. Such multifunctional interaction results in a new approach to resource planning which enables flexibility both in projects implementation and evaluation of their efficiency. This article describes theoretical aspects of labor costs planning and monitoring and proposes a stage-by-stage approach to labor norms calculation for each type of work. This approach is based on regression analysis which enables retrieval of average labor norms based on actual statistics from previous projects and considers external factors that impact labor costs as well as soft skills of personnel involved in project work. This approach not only enables appropriate workforce planning and anticipation of professional qualification of the company personnel but also allows proper prioritization of project activities and distribution of workload between project team members which in its turn results in reduction of costs and time. The authors of this article see further development in introduction of performance management system that could be calculated for each team member as well as for the entire company, provided that the planned labor norms and actual execution time data are available. This approach to resource planning is explained based on an actual labor norms calculation at one of the engineering projects implemented in Gazpromneft NTC LLC.

References

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shagom (Project management. Corporate system - step by step), Moscow:

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References

1. Patent no. 2428723 RF, Method of searching for hydrocarbon deposits in bituminous

argillaceous deposits, Inventors: Korobov A.D., Korobova L.A.

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approach of the reserves estimation for source rock formations (In Russ.),

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and gas bearing area formations for unconventional reservoirs Bazhenov

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5. Slepak Z.M., Gravirazvedka v neftyanoy geologii (Gravity prospecting in

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According to the authors, one of the important processes that have made their contribution to the formation of secondary porosity in the Bazhenov rocks are the epigenesis processes. Keeping in mind that these processes are related to the development of high reservoir properties of productive rocks, their importance for the prediction of promising areas where free oil may occur is significant. Unconventional reservoirs with mobile hydrocarbons are confined to weakened zones of the sedimentary mantle where oil generation is caused by conditioned heating related to certain hydrothermal-metasomatic processes in the basement rocks and structural features of the sedimentary mantle while boundaries of non-structural traps are defined by decompression zones. The exploration methods that can be used in a license block should be in accordance with the amount of geologic information available and determine target parameters for further more detailed and expensive explorations such as high-resolution 3D seismics and exploratory drilling.

The paper analyses the relevance of the obtained exploration results as well as the applicability of high-precision geophysical methods, such as detailed gravimetric and magnetic surveying and areal geochemical surveying, to identify unconventional and non-structural traps. The reason for integrating potential field data with seismic data is determined by the fact that information obtained by each of these methods has its specific characteristics. Anomalies of potential fields related to magnetic and density properties of rocks reflect, first of all, their composition and superimposed processes (tectonic impacts, hydrothermal-metasomatic changes, etc.) which allows obtaining data on physical characteristics of the geological environment in addition to seismic data that are crucial, mainly, to study structural features. Second, gravitational and magnetic fields anomalies are caused, primarily, by high-angle boundaries while the seismic method, in contrast, is focused on tracking low-angle boundaries. It means that these two methods may complement each other helping identify subvertical tectonic and subhorizontal lithological and stratigraphic boundaries.    

Nowadays oil industry is often faced with the following question: which development strategy is preferable? The matter is that the best development scenario is important both in the initial and the development final stages of the hydrocarbons field. The most important criteria while choosing the development scenario is the process of maximizing the profit by raising the NPV value. This estimation parameter can be determined in terms of Value of Information approach (VOI).

The authors carry out the usage of VOI approach in various seismic scenarios included all steps which are field survey, processing and interpretation in order to reduce risks and uncertainties. The new seismic data leads to changes in uncertainty distribution, key parameters and thus in NPV distribution. Consequently the new data can change the investment decision. Generally the project risks are closely connected with the lack of precise information about the geologic genesis, which creates the range of uncertainty and consequently leads to increasing the “dry hole” drilling risks and its expenditures. Conducting the seismic survey helps to decrease the standard deviation in forecasting parameter (to narrow of the forecast deviation). As a result knowingly non-commercial wells can be expelled from the project and thus can lead to the profit maximization and the development program correction. Economic rationalization due to cutting the non-commercial wells drilling allows to obtain the benefit and to form the VOI of the event. The operations called successful in case of VOI values are higher than its expenditures. Otherwise, the benefit is implicit and the operation has no practical usage.

References

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shoot it, SPE 56446-MS, 1999.

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rekomendatsii po ispol'zovaniyu dannykh seysmorazvedki (2D, 3D) dlya

podscheta zapasov nefti i gaza (Guidelines for using seismic data (2D,

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An engineer is often faced with uncertainty in the value of parameters required for engineering calculations on the basis of which the decision must be made.

In the company "Gazprom Neft" a project is being implemented to improve the efficiency of business planning, including planning drilling of new wells. During the project a tool has been developed which calculates potential production characteristics of planned well and allows a probabilistic assessment of potential indicators, taking into account the geological uncertainties. Probabilistic assessment is based on the Monte Carlo method with a set of geological and physical uncertain characteristics of a reservoir. To choose the most optimum variant of an asset development several algorithms are offered, each satisfying the pursued goals: maintenance of the level determining parameter, pessimistic case, minimizing loss of benefits and choices based on EMV.

On the basis of proposing probabilistic assessment approach the parameter with the higher uncertainty is identified and possible methods of decreasing the uncertainties by conducting the necessary investigation. Also it carried out the description of the algorithm makes it possible to assess the economic feasibility of an offered research.

References

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(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2012, no. 4, pp. 13–17.

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The problem of sand production has existed for oil field development is often the cause of failures in the downhole equipment and leads to a decrease in productivity. The growth of soft sand zone is the root of sand production problem. Wells drilling and operation leadleads to a change in the stress state of rock. Near wellbore strains can cause the collapse of the wellbore walls under certain conditions, it leads to remove of sand from the well. In this paper we describe the geomechanical modeling algorithm for wellbore stability analysis and completion selection for soft sedimentary rocks. Algorithm consists of few stages: 1D geomechanical modeling; its application to minimizing risk of drilling fishbones; calculation of depression for cost-effective rate and minimizing sanding. 1D wellbore stability model gives a first approximation of the stresses. The next step is the finite element modeling for calculation near wellbore stress state. This paper proposes an integrated approach to sand control. The algorithm includes wellbore stability analysis for drilling horizontal and fishbone wells, 3D geomechanical modelling for near wellbore zone. The proposed algorithm allows determining the critical depression in order to reduce the volume of sand carried out of the well. We consider the geomechanical modeling for wells Vostochno- Messoyakhskoye oil field. A horizontal well in Vostochno- Messoyakhskoye oil field was drilled with a multilateral fishbone shape. Geomechanical modelling was used to determine the stable intervals for cutoffs sidetracks. Based on a complex analysis of the proposed program for the well output mode to achieve maximum period of well operation. A geomechanical approach includes research of elastic-strength properties, diagnostic fracture injection test, caliper and images of the wellbore before and after the fracturing, the finite element modeling of near wellbore space. Its application allows controlling sand production at formations with similar geological conditions.

References

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the New Mudweight Window concept; A case study of well KTY 02, KTY 03

and KTY 04, SPE 184279-MS.

2. Xinpu Sh., Case studies on 3-Dimentional numerical prediction of critical

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Major oil reserves of considered oil-gas-condensate field are concentrated in the oil rim of Lower Cretaceous and Jurassic deposits. The classic approach to the development of this type of oil reserves is drilling long horizontal wells, in view of the need to create a small depression in the producing wells. At the same time, as a rule, the development of oil rims complicated breakthroughs "languages" of gas from the gas caps and water from the aquifer. Under these conditions, to obtain information about the formation, monitoring and control of development is extremely actual and complicated problem at the same time. Among the methods of obtaining such information there are well test analysis and production log tests for wells. Prolonged well-bore storage effect (due to the length of the horizontal sections of 1000m and over) at the trunk holding covers well testing flow regimes, allowing reliable determination of important parameters, such as producing part of  the horizontal trunk, the mechanical skin factor and vertical permeability (anisotropy of the formation). The most reliably determined parameters are integral horizontal permeability and skin factor.

References

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of horizontal wells in low unstable inflow. Problems and solutions

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Oil rim reservoirs are the main assets for new oil production regions. The oil rim development is associated with significant challenges. Among these are the primary methods of reservoir penetration, long-term development under solution gas, gas cap and drive support, decision of effective gas usage (associated and gas-cap). The paper is concerned with basic elements of integrated development concept of Novoportovskoye field, which was involved in the development in 2016. This paper presents current development trends and prospects of experience replicating for other development projects with oil rims. The world experience analysis revealed that 50-70% of oil rim reserves are recovered by primary methods. The main criterion of primary oil recovery efficiency is the ratio between well productivity and well cost. On the other hand the project success depends on accepted development strategy, especially the gas injection duration for pressure maintenance and beginning gas transportation for selling. The one of the effective approaches of project management is an integrated modelling, which includes the calculation of the reservoir, wells and surface infrastructure models simultaneously.

References

1. Khasanov M.M., Sugaipov D.A., Ushmaev O.S. et al., Development of cost

engineering in Gazprom Neft JSC (In Russ.), Neftyanoe khozyaystvo = Oil Industry,

2013, no. 12, pp. 14–16.

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2013.

3. Khasanov M.M., Ushmaev O.S., Samolovov D.A. et al., Estimation of cost effective

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Broad application of hydraulic fracturing techniques in oil industry since the 1950s led to the emergence of a large number of studies devoted to both production forecast methods and reservoir performance evaluation techniques to interpret the results of various well testing procedures. It is remarkable that analytical investigations devoted to the postfracturing analysis are focused primarily on the early-time unsteady flow regime, while for the production forecast it is commonly used the approximation of steady-state or pseudosteady-state flow models. The focus in oil engineering has recently turned towards unconventional reserves. Unsteady-state flow plays crucial role for reservoirs with low-mobility oil by making a major contribution to the cumulative oil production. With the appearance of the available computational techniques, the emphasis has shifted to the numerical simulation of flows, and the search for analytic approximations gone by the wayside.

A number of articles is devoted to discussing the critical issues associated with numerical simulations. Among others, it should be noted that the large-scale grid cannot adequately simulate transient flow regime of the fluids with low mobility owing to the fact that the cell size is much larger than the characteristic scale of the variations of physical parameters, particularly pressure. Changing the sizes of cells, including local refinement, always results in time-consuming model and adversely affect the convergence of the numerical scheme.

The study presents an approach to the analytical modeling of the production rate of the fractured vertical well during the unsteady flow regime. Asymptotic Laplace space solution based on trilinear flow model is developed to describe the flow at early times. The authors propose an asymptotic solution, which describes the flow rate towards vertical fracture under the assumption of an infinite reservoir, using the desuperposition concept to couple the trilinear and pseudoradial flow solutions.

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Computational considerations and applications, SPE 18616-PA, 1991.

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a better reservoir management, SPE 25604, 1993.

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to model hydraulically fractured well performance in coarse grid

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The authors sum up Gazprom Neft field experience in the area of long-term distributed temperature sensor (DTS) studies in horizontal wells. First steps in information capacity analysis were made on vertical multilayer well studies. Obtained results approved thermosimulator calculations and allowed to determine future conditions of representative studies in horizontal wells. The following periodical DTS measurements during multi-fracturing and 6 months stationary monitoring showed high information capacity of both stable and dynamic temperature field. The next steps in method effectivity enhancement are two be done in three directions: 1) DTS optimization, its components and price; 2) forming the best well run and stop conditions for measurements; 3) usage of advanced methods of interpretation and software.

Most urgent field task is DTS installation in horizontal well with ESP. Exact technology is not provided yet (ESP housing, Y-tool or composite fiber rod). Anyway for tie-in and reliable interpretation basic production logging studies will be conducted before DTS installation. In its turn obtained results of distributed acoustic sensing are still to be comprehended and may also find its place in production monitoring system.

References

1. Ipatov A.I., Kremenetskiy M.I., Kaeshkov I.S. et al., Undiscovered DTS potential

of horizontal well inflow profile monitoring (In Russ.), Neftyanoe khozyaystvo

= Oil Industry, 2014, no. 5, pp. 96-100.

2. Ipatov A.I., Kremenetskiy M.I., Gulyaev D.N. et al., Reservoir surveillance

when hard-to-recover reserves developing (In Russ.), Neftyanoe khozyaystvo

= Oil Industry, 2015, no. 9, pp. 68-72.

3. Patent no. 2541671 RF, Method for determination of flowing intervals in horizontal

wells, Inventors: Ipatov A.I., Kremenetskiy M.I ., Kaeshkov I.S.

A new catalytic technology - Soft Steam Reforming, intended for conversion of associated petroleum gas (APG) in the gas mixture consisting of about 75-90 % (by mole) of methane. The process is carried out in presence of a steam-to nickel-containing catalyst at temperatures of 250-350 °C and a molar ratio of H₂O/C₂₊ was 0.4-0.6. As a result, the process contained in Putney petroleum gas heavy homologues of methane (hydrocarbons C₂₊) with a conversion of above 90 % are converted into a gas mixture having a methane number close to 100, Bottom Shui calorific value of about 31.8 MJ/m³ and Wobbe index (lower) 41.0 MJ/m³. This gas can be effectively used as fuel for gas turbine and gas turbine power units.

References

1. Vernikovskaya M.V., Snytnikov P.V., Kirillov V.A., Sobyanin V.A., Technological

and economic advantages of processing following oil gases into the

methane-hydrogen gas mixture for the power units supply (In Russ.), Neftepererabotka

i neftekhimiya, 2012, no. 11, pp. 7–12.

2. Adzhiev A.Yu., Purtov P.A., Podgotovka i pererabotka poputnogo

neftyanogo gaza v Rossii (Treatment and processing of associated gas in Russia),

Krasnodar: Publ. EDVI, 2014, 349 p.

3. Rybakov B.A., Burov V.D., Rybakov D.B., Trushin K.S., Features flaring of associated

gas in gas turbine units (In Russ.), Turbiny i Dizeli, 2008, no. 3, pp. 2–8.

4. Kalla R., Jansson P., Converting low quality gas into a valuable power

source, Wartsila technical Journal, 2013, pp. 61–65.

5. Patent no. 2442819 RF, Method and device for processing associated oil

gases, Inventors: Snytnikov P.V., Kirillov V.A., Sobyanin V.A., Belyaev V.D., Kuzin

N.A., Kireenkov V.V., Amosov Yu.I., Polyanskaya T.V., Popova M.M.,

Potemkin D.I.

6. Patent no. 2443764 RF, Operating method of device for preparation of associated

petroleum gases to be used in power plants, Inventors: Snytnikov

P.V., Kirillov V.A., Sobyanin V.A., Belyaev V.D., Kuzin N.A., Kireenkov V.V., Amosov

Yu.I., Polyanskaya T.V., Popova M.M., Potemkin D.I.

7. Utility patent no. 160799 RF, Ustroystvo dlya polucheniya vodorodsoderzhashchey

gazovoy smesi (A device for producing hydrogen-containing

gas mixture), Inventors: Kuznetsov A.N., Dyagtyarev A.V., L.N. Kim, V.A. Kirillov,

V.N. Misnik, M.A. Misharin, A.V. Sazonov, Sulimskiy D.M., Frolov E.V.

According to conclusions of international consulting enterprise Bain & Company new analytical capabilities in big data will allow oil and gas industry to improve efficiency by 6-8%. Industry has already been dealing with huge amounts of information for decisions making for a long time. However, modern computational power and new algorithms for handling these data bring this process to a new level. When modern computers lack power to calculate through many iterations for solution of the petroleum engineering problems Big Data technologies come up to assist. Big Data applications already change the landmark of the industry.

In the age of information technology, followed by prompt growth of amount and diversity of processed data, a possibility arises for qualitative transition from quantity to quality of data. As the result vast amount of solutions and tools for structured and unstructured data were developed – Big Data technologies. The area has become one of key IT drivers and widespread in Western countries today. Progress in Big Data gave an impetus to introduction of modern gauge sensors collecting huge amount of production data.

Considerable attention is being paid to methods of processing and data mining in Gazprom Neft PJSC. The company has experience of small-scale solutions realization using Big Data technologies and initiated a set of projects aimed at overcoming petroleum engineering technological challenges by cognitive methods and tools.

References

1. Jacobs T., Automated drilling technologies showing promise, JPT, 2015,

V. 67, no. 6 (June), URL: http://www.spe.org/jpt/article/9010-automateddrilling-

technologies-showing-promise.

2. Rawi Z., Machinery predictive analytics, SPE 128559, 2010.

3. Stone P., Introducing predictive analytics: opportunities, SPE 106865, 2007.

4. How advanced analytics can drive productivity, URL: http://www.mckinsey.

com/business-functions/mckinsey-analytics/our-insights/how-advanced-

analytics-can-drive-productivity.

5. Big success with big data, URL: https://www.accenture.com/ieen/~/

media/Accenture/Conversion-Assets/DotCom/Documents/Global/

PDF/Digital_1/Accenture-Big-Data-POV.pdf.

Gazprom Neft PJSC is interested integrated approaches to conceptual engineering due to reduction of proven reserves and development of new areas with high levels of complexity and uncertainty; development of new areas with an underdeveloped infrastructure; large number of development targets and the need for quick engineering calculations.

To maintain production levels at brownfields we need to focus on improving operation efficiency, efficient development and rapid response to changes in the macro-environment. In such circumstances to make sound technological solutions is necessary at every stage of the design: when regard the interconnection of the reservoir, wells and ground infrastructure; when perform the multiple calculations in conditions of uncertainty; when assess the cost of drilling and infrastructure.

A uniform digital platform for the engineering models of different systems is considered in the framework of conceptual engineering enable to significantly improve the effectiveness of work.

Uniform design tool allows automation of calculations and implementation of the optimization algorithms; implementation the large number of calculation for the initial data, which are given by the uncertainty intervals; automation of data transmission between the individual functional units.

References

1. Khasanov M.M., Afanas'ev I.S., Latypov A.R. et al., Hierarchy of the integrated

models (In Russ.), SPE 117412-RU, 2008.

2. Ismagilov R.R., Maksimov Yu.V., Ushmaev O.S., Integrated model for complex

management of reservoir engineering and field construction (In Russ.),

Neftyanoe khozyaystvo = Oil Industry, 2014, no. 12, pp. 71-73.

3. Karsakov V.A., Tret'yakov S.V., Devyat'yarov S.S., Pasynkov A.G, Drilling cost

optimization during conceptual project phase of field development

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2013, no. 12, pp. 33-35.

4. Khasanov M.M., Sugaipov D.A., Zhagrin A.V. et al., Improvement of CAPEX

estimation accuracy during early project stages (In Russ.), Neftyanoe

khozyaystvo = Oil Industry, 2014, no. 12, pp. 22-27.

5. Khasanov M.M., Sugaipov D.A., Ushmaev O.S. et al., Development of cost

engineering in Gazprom Neft JSC (In Russ.), Neftyanoe khozyaystvo = Oil Industry,

2013, no. 12, pp. 14-16.

References

1. Rezapour A., Ortega A., Ershaghi I., Reservoir waterflooding system identification

and model validation with injection, SPE 174052-MS, 2015.

2. Doublet L.E., Pande P.K., McCollum T.J., Blasingame T.A., Decline curve

analysis using type curves – analysis of oil well production data using material

balance time: application to field cases, SPE 28688-MS, 1994.

3. Grinestaff G.H., Waterflood pattern allocations: Quantifying the injector to

producer relationship with streamline simulation, SPE 54616-MS, 1999.

4. Ojo K.P., Tiab D., Osisanya S.O., Dynamic material balance equation and

solution technique using production and PVT data, SPE Petroleum Society of

Canada, 2006, March 1, DOI:10.2118/06-03-03.

5. Nelder J.A., Mead R., Computer Journal, 1965, V. 7, pp. 308–313.

6. Dietz D.N., Determination of average reservoir pressures from build up surveys,

JPT, 1965, August, pp. 955–959.

7. Baykov V.A., Zhdanov R.M., Mullagalieva T.I., Usmanov T.S., Selecting the optimal

system design for the fields with low-permeability reservoirs (In Russ.),

Neftegazovoe delo = The electronic scientific journal Oil and Gas Business,

2011, no. 1, pp. 84–98.

Reserves of rims, when thickness does not exceed 10-15 m, are regarded as hard-to-recover. Development of oil reserves of oil-gas-condensate deposits is complicated because of multiphase flow in the formation, which leads to negative processes such as marginalization oil into the gas zone, gas breakthrough to the bottom of the production well (GOR increase of more than 1500 m³/t) and the disbanding of the oil rim. As a result, oil recovery does not exceed 10% of the initial endowments. To design oil preparation process in the case of joint production of gas and gas caps of the oil rims by the oil producing wells is necessary to correctly simulate the component-fractional composition of the produced fluid, taking into account the composition of the formation of oil and gas breakthrough in their number. The main difficulty of component-modeling of fractional composition of the produced fluid is the description of a hypothetical or pseudo-oil and hydrocarbon condensate produced from gas breakthrough. Calculated hypothetical components must describe the composition and properties of oil and condensate, both separately and mixtures thereof.

References

1. Brusilovskiy A.I., Fazovye prevrashcheniya pri razrabotke mestorozhdeniy

nefti i gaza (Phase transformations in the development of oil and gas fields),

Moscow: Graal' Publ., 2002, 575 p.

2. Sardanashvili A.G., L'vova A.I., Primery i zadachi po tekhnologii pererabotki

nefti i gaza (Examples and problems of oil and gas processing technology),

Moscow: Khimiya Publ., 1980, 272 p.

3. Ivanov S.S., Tarasov M.Yu., Zobnin A.A., Oil yield enhancement and reduction

of light liquid hydrocarbons content in petroleum gas at oil treatment unit

design (Part 1), Neftyanoe khozyaystvo = Oil Industry, 2011, no. 8, pp. 138–140.

References

1. Shakirov V.A., Deryushev D.E., Ivanov M.A., Sereda I.A., Current results of

overlooked targets identification in the fields of the Orenburg region (In Russ.),

SPE 176606-RU, 2015.

2. Dentskevich I.A., Oshchepkov V.A., Patterns of placement of deposits of oil

in the flank of Muhanovo-Erohovskiy deflection (In Russ.), Geologiya nefti i

gaza = The journal Oil and Gas Geology, 1989, no. 5, pp. 21–23.

3. Postoenko P.I., Cherepanov A.G., Prospects of oil bearing Frasnian - Lower

Famennian deposits in the south-east of the Volga-Kama anteclise (In Russ.)

Geologiya nefti i gaza, 1992, no. 2, pp. 28–32.

4. Gorbovskaya O.A., Demidova E.A., Geologicheskoe stroenie Bobrovskogo

mestorozhdeniya i usloviya zaleganiya nefti v plaste BII (bobrikovskiy gorizont)

(The geological structure of the Bobrovsky f ield and conditions of occurrence

of oil in the reservoir BII (Bobrikovian)), Proceedings of XVI Mezhdunarodnogo

simpoziuma imeni akademika M.A. Usova studentov i molodykh uchenykh,

posvyashchennogo 110-letiyu so dnya osnovaniya gorno-geologicheskogo

obrazovaniya v Sibiri (International Symposium named after Academician

M.A. Usov of students and young scientists, devoted to the 110th anniversary

of the founding of mining and geological education in Siberia), Tomsk, 2012,

pp. 252–254.

5. Prozorovich G.E., Pokryshki zalezhey nefti i gaza (Cap rocks of oil and gas

deposits), Moscow: Nedra Publ., 1972, 117 p.

6. Bondarenko P.M., Zubkov M.Yu., Forecast of secondary fracture zones on

the basis of seismic prospecting and tectonic-physical modeling (In Russ.),

Geologiya nefti i gaza = The journal Oil and Gas Geology, 1999, no. 11 – 12,

pp. 31–40.

One of the best practices for improving oil recovery in waterflood projects is horizontal drilling which involves construction of multifunctional horizontal wells as well as revitalization of marginal wells through sidetrack drilling, particularly horizontal sidetracking. The first attempts to implement horizontal drilling technology in Lower Carboniferous terrigenous and carbonate reservoirs, and in Domanic sediments of the Famennian stage and Upper Devonian Pashian reservoirs were made by geological surveys of Tatneft and Oil and Gas Production Department Bavlyneft. Oil fields operated by Bavlyneft comprise 29% of total count of horizontal wells drilled through the above mentioned reservoirs and 56% of horizontal wells drilled to produce from the Tournaisian production target.

Oil production rates obtained from horizontal wells in terrigenous reservoirs and low-permeability carbonates were estimated at 100 t/d and 10 t/d, respectively, at negligible water cut. In 2015, horizontal drilling was implemented in the Domanic sediments. These were brought into production using EOR methods and bottomhole assembly providing for division of a horizontal section into multiple isolated intervals with different reservoir properties.

Engineering design and well construction technology, as well as completion and operation of horizontal wells in Tatarstan have been brought to a relatively high level, which is confirmed by production and economic performance indicators that are comparable to those of the leading foreign and Russian energy companies.

At the present time in the process of drilling wells with complex profiles telemetry systems of well trajectory monitoring are extensively used. They improve drilling efficiency, provide operational accuracy of drilling and provide information about drilling dynamics in real-time to optimize drilling parameters and to improve the rate of penetration and well durability. Operational information about the state of reservoir, obtained by measuring gamma radiation, resistance and telemetric measurements allows to adjust the well trajectory by providing well drilling in the most productive part of the reservoir. To control the predetermined direction of the wellbore axis in space, allocating areas of its bending, which can cause problems during drilling and exploitation, and determining the true depth of productive layers, as well as spatial bottomhole position (zenith angle and azimuth) at individual points of the wellbore using inclinometer sensors. One type of such sensors are gyroscopic instruments, which allow to orient the wellbore in space during construction providing the origin from certain existing coordinate system in measuring angles and angular velocities. The most modern, promising and fastest growing among the gyroscopes are fiber optic devices.

The article describes the issue of increasing the efficiency of the small oil-producing assets through an integrated approach to geologic studies and reservoir engineering, on an example of a subsidiary of Zarubezhneft JSC - Orenburgnefteotdacha LLC. Orenburgnefteotdacha LLC owns exploration and development licenses for three small oil fields in the north of the Orenburg region: Pashkinskoye, Kirsanovskoye and Chernovskoye fields, which are producing oil from a small well stock since the beginning of the 2000s. In 2014 a comprehensive program of these fields’ development efficiency increase has been approved and it is being currently implemented. The first phase included re-interpretation of previous years’ 3D seismic survey and the increase of base oil production through an introduction of a reservoir pressure maintenance system, dual completion application and individually selected acid treatments with compositions based on the reservoir rocks and formation oil properties. In 2015, after successful results of the first stage, an exploration and development drilling program commenced at the fields. As a result of the first exploration well drilling, an additional small dome with commercial oil reserves was discovered at the Kirsanovskoye field. In course of development drilling program implementation the well completion method was selected on the basis of fields’ geologic peculiarities. So, on a multilayer Pashkinskoye field directional wells with dual completion were implemented and horizontal wells on a single reservoir Kirsanovskoye field. All of this allowed achieving economically efficient new wells’ drilling what had been previously considered lacking prospects. The basic well stock activities and new development wells’ drilling being performed have allowed increasing oil production of the enterprise in general by 50% by November 2016 with further plans to establish a full-scale development system and to further increase the oil production in 2017.

This paper presents an improved model of fluid inflow into hydraulic fractures. We also suggest here formulae for calculating flow rate in a horizontal well after multi-stage hydraulic fracturing job as dependent on the number of fractures, the angle of fracture deviation fr om the normal line to the horizontal section of the well and on the values of fractures’ dimensionless conductivity F_cd. In our previous papers we accounted for infinite conductivity, but only partially. In this paper we estimate the impact of fracture conductivity onto the total flow rate in a horizontal well after multi-stage hydraulic fracturing. The hydraulic fracture is viewed as a wedge-like channel with half-length of x_f, average width of w and constant height of h that is filled evenly with proppant and deviates at an angle ± from the normal line. Our assumption was that the pressure at fracture tip is higher than bottom-hole pressure p_тр> p_з, while the pressure at the beginning of the fracture (the point wh ere it enters the wellbore) is equal to bottom-hole pressure p_з. For F_cd>10 the previous and the current models render equal results. The new model is a powerful enabler for optimization of multi-stage fracturing it terms of identifying economically efficient number of ports as well as fracture half-length and the angle of fracture deviation from the normal line to the well.

References

1. Elkin S.V., Aleroev A.A., Veremko N.A., Chertenkov M.V., Flowrate calculation

model for fractured horizontal well depending on frac stages number

(In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 1, pp. 64–67.

2. Elkin S.V., Aleroev A.A., Veremko N.A., Chertenkov M.V., The model for rapid

calculation of horizontal well production rate depending on the number of

hydraulic fractures with anisotropic layer (In Russ.), Inzhenernaya praktika,

2016, no. 7, pp. 82–88.

3. Elkin S.V., Aleroev A.A., Veremko N.A., Chertenkov M.V., Consideration of

the impact of fracktures deviation from their perpendicular position to a horizontal

well on the liquid flow rate following a multi-stage hydraulic fracturing

(In Russ. ), Neftepromyslovoe delo, 2016, no. 10, pp. 37–42.

4. Cinco-L.H., Samaniego-V.F., Dominguex N., Transient pressure behavior for

a well with a finite-conductivity vertical fracture, SPE 6014-PA, 1978.

References

1. Agliullin M.M., Abdullin V.M., Abdullin M.M., Kurmaev S.A., Development

and implementation of thermobar-chemical method of increasing the productivity

of oil and gas wells (In Russ.), Neftegazovoe delo = The electronic scientific

journal Oil and Gas Business, 2004, no. 2. http://www.ogbus.ru

2. Belin V.A., Gribanov N.I., Shilov A.A., Pelykh N.M., Metody razrusheniya plasta-

kollektora energiey goreniya energeticheskikh kondensirovannykh sistem

(Methods of reservoir destruction by energy of combustion of energetic condensed

systems), Moscow: Publ. of MSMU, 2011.

3. Laspe C.G., Roberts L.N., A mathematical analysis of oil and gas well stimulation

by explosive fracturing, SPE 3355, 1971.

4. Young C., Barker D.B., Clark H.C., Field tests of the stem-induced explosive

fracturing technique, SPE 12840-PA, 1986.

5. Prikhod'ko N.K. et al., Primenenie khimicheskikh vzryvchatykh veshchestv

dlya intensifikatsii razrabotki neftyanykh i gazovykh mestorozhdeniy (The use

of chemical explosives for the intensification the development of oil and gas

fields), Moscow: Publ. of VNIIOENG, 1981, 131 p.

6. Patent no. 4330037 US. E 21 B 43/22, Well treating process for chemically

heating and modifying a subterranean reservoir, Inventors: Richardson E.A.,

Fair W.B.

7. Patent no. 2525386 s2 RF, Thermal gas chemical composition and its application

for well bottom and remote zones of productive stratum, Inventors: Zavolzhskiy

V.B., Burko V.A., Idiyatullin A.R. et al.

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induced impact of binary mixture reaction near wellbore (In Russ.), SPE-

182048-RU, 2016.

9. Aleksandrov E.N., Kuznetsov N.M., Large-scale heating of an oil-bearing formation

and liquid hydrocarbon production mode optimization (In Russ.),

Karotazhnik, 2007, no. 4, pp.113–127.

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compounds expert), Moscow: Khimiya Publ., 1987, 464 p.

Reservoir M of the Boko de Jaruco (the Republic of Cuba) field is a unique object that does not have a real equivalent anywhere in the world and has large potential reserves of hydrocarbons that are estimated to exceed hundreds of millions of tons. Reservoir M presents carbonate reservoir, high viscosity saturated oil, which should rather be viewed as bitumen. The development of this object can have a revolutionary impact on the Republic of Cuba, is comparable with the importance of development of deposits of bitumen in Canada. The development of reserves of the object will make a significant contribution to the achievement of energy security of the Republic of Cuba, and will ensure the development of the petrochemical industries. In this regard, Zarubezhneft JSC has initiated pilot projects to find effective technologies for the development of the reservoir M.

References

1. Afanasiev I.S., Yudin E.V., Azimov T.A. et al., Technology for the thermal treatment

of the productive formations of the Boca de Jaruco field: challenges,

opportunities, prospects (In Russ.), SPE 176699-MS, 2015.

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razrabotki karbonatnykh kollektorov (Expectation and reality of the carbonate

reservoirs development), Proceedings of V International scientific symposium

“Teoriya i praktika primeneniya metodov uvelicheniya nefteotdachi

plastov” (Theory and practice of EOR application), Moscow, 16–17 September

2015.

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1993, V. 32, no. 1, pp. 48–53.

The reduction of energy consumption for oil and gas production and processing is one of the important objectives of the fields development. More rational utilization of the compressed gas energy helps to solve this problem. Compressed gas energy might be converted to heat or electrical energy. Conversion process might be divided into several stages and one of these stages considers conversion of the kinetic energy of the gas stream to mechanical energy. Gas turbine which is connected to the pump or electrical generator via transmission is used at this stage of energy conversion, Transmission is used for mechanical energy transfer meeting the requirements aimed at preventing gas leakage to the atmosphere. Watertight system for mechanical energy transfer might be developed with usage of magnet coupling based on permanent magnets and equipped with watertight dividing screen.

Each half of the coupling is usually equipped with permanent magnets. Within the scope of this study new coupling design is considered where only one half of the coupling is equipped with permanent magnet. Second half of the coupling is equipped with steel rollers which are used as magnetic circuit. In the system where compressed gas energy is converted to heat energy, steel rollers work in conditions of high temperature while permanent magnets work in the zone with lower temperature. Technical objective is to provide more favorable conditions for permanent magnets work what will result in better reliability of the whole system.

References

1. US patent no. 4850818, Corrosion-resistant magnet pump, Inventor:

Masayuki Kotera, 1989, URL: http://www.freepatentsonline.com/

4850818.html

2. US patent no. 5066200, Double containment pumping system for pumping

hazardous materials, Inventor: Kazuo Ooka, 1991, URL: http://www.freepatentsonline.

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3. US patent no. 5201642, Magnetic drive pump, Inventor: Hinckley Ch.J.,

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4. US patent no. 7922464, Magnetic drive pump, Inventor: Kazunari Adachi,

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5. US patent no. 20040131485, Sealed magnetic drive sealless pump, Inventor:

Chi-wei Shi, 2004, URL: http://www.freepatentsonline.com/y2004/

0131485.html

6. US patent no. 4678409, Multiple magnetic pump system, Inventor: Toshio

Kurokawa, 1987, URL: http://www.freepatentsonline.com/4678409.html

7. US patent no. 4850821, Multiple magnet drive pump, Inventor: Sakai Naotake,

1989, URL: http://www.freepatentsonline.com/4850821.html

8. US patent no. 20050095149, Magnetic drive pump, Inventor: Seiya Tanaka,

2005, URL: http://www.freepatentsonline.com/y2005/0095149.html

9. Sazonov I.A., Mokhov M.A., Design of thermoelectric generators for oil and

gas production systems, Indian Journal of Science and Technology, 2015,

V.8(30), pp. 1–12, URL: http://www.indjst.org/index.php/indjst/article/view-

File/81878/63184

10. Sazonov Iu.A., Mokhov M.A., Frankov M.A., Biktimirova D.R., Studying issues

of compressed gas energy recovery, Indian Journal of Science and Technology,

2016, May, V.9 (19), pp. 1–7.

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for oil and gas production systems (In Russ.), Neftyanoe khozyaystvo = Oil Industry,

2015, no. 12, pp. 127–129.

12. Utility patent no. 160267, Magnitnaya mufta (Magnetic clutch), Inventors:

Sazonov Yu.A., Mokhov M.A., Gruzintsev D.A., Basharov S.F.

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References

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5. Conti P.F., Controlled horizontal drilling, SPE 18708-MS, 1989.

6. Temichev A.A., Kychkin A.V., The software simulator PLC VIDA350 of energy

management system My-JEVis (In Russ.), Vestnik Permskogo natsional'nogo

issledovatel'skogo politekhnicheskogo universiteta. Elektrotekhnika, informatsionnye

tekhnologii, sistemy upravleniya = PNRPU Bulletin. Electrotechnics, Informational

Technologies, Control Systems, 2011, no. 5, pp. 210–220.

7. Zaikin I.P., Pankov M.V., Ismailov N.A., Pushkarev S.V., Rotary controllable system

PowerDrive and well log survey system PeriScope operation in horizontal

well drilling (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2009, no. 11,

pp. 68–70.

8. Xue Q., Wang R., Huang L. et al., The strap-down automatic vertical drilling

system design and field applications, The Electronic Journal of Geotechnical

Engineering, 2012, no. 1, pp. 3009–3018.

9. Kychkin A.V., The long-term energy monitoring based on OpenJEVis Software

(In Russ.), Vestnik Permskogo natsional'nogo issledovatel'skogo politekhnicheskogo

universiteta. Elektrotekhnika, informatsionnye tekhnologii,

sistemy upravleniya = PNRPU Bulletin. Electrotechnics, Informational Technologies,

Control Systems, 2014, no. 1 (9), pp. 5–15.

10. Jian K., BoXiong W., Zhong Xiang H. et al., Study of drill measuring system

based on MEMS accelerative and magnetoresistive sensor, Electronic Measurement

& Instruments, ICEMI 09, Beijing, China. 2009.

11. Xue Q., Wang R., Sun F. et al., Continuous measurement-while-drilling utilizing

strap-down multi-model surveying system, IEEE Trans. Instrum. Meas.,

2014, V. 63, pp. 650–657.

12. Kostygov A.M., Kychkin A.V., Artemov S.A., An automated system for remote

energy monitoring of mobile objects with electric drives (In Russ.), Elektrotekhnika

= Russian Electrical Engineering, 2015, no. 11, pp. 48–50.

13. Lyakhomskiy A.V., Perfil'eva E.N., Kychkin A.V., Genrikh N., A software-hardware

system of remote monitoring and analysis of the energy data (In Russ.),

Elektrotekhnika = Russian Electrical Engineering, 2015, no. 6, pp. 13–19.

14. http://os.is/gogn/unu-gtp-report/UNU-GTP-2013-27.pdf

15. Kostygov A.M., Kychkin A.V., Structurization of remote monitoring of a

group of intelligent mobile platforms in real time (In Russ.), Datchiki i sistemy,References

1. Nikolaev N.I., Leusheva E.L., Theoretical and experimental investigation of

hard rock drilling efficiency (In Russ.), Vestnik Permskogo natsional'nogo issledovatel'skogo

politekhnicheskogo universiteta. Geologiya. Neftegazovoe i

gornoe delo = Bulletin of Perm National Research Polytechnic University. Geology.

Oil & Gas Engineering & Mining, 2015, no. 15, pp. 38–47, DOI:

10.15593/2224-9923/2015.15.5.

2. Kuz'mina T.A., Mironov A.D., Experience in the development of objects unproductive

using technology multihole drilling (In Russ.), Vestnik Permskogo

natsional'nogo issledovatel'skogo politekhnicheskogo universiteta. Geologiya.

Neftegazovoe i gornoe delo = Bulletin of Perm National Research

Polytechnic University. Geology. Oil & Gas Engineering & Mining, 2012, no. 3,

pp. 89–93.

3. Baldenko D.F., Vervekin A.V., Plotnikov V.M., Ways to further improvement of

well drilling by downhole drilling motors (In Russ.), Vestnik Permskogo natsional'nogo

issledovatel'skogo politekhnicheskogo universiteta. Geologiya.

Neftegazovoe i gornoe delo = Bulletin of Perm National Research Polytechnic

University. Geology. Oil & Gas Engineering & Mining, 2016, V. 15, no. 19, pp.

165–174, DOI: 10.15593/2224-9923/2016.19.7.

4. Ust'kachkintsev E.N., Increase productivity of construction in sidetrack of

Verkhnekamsk potassium-magnesium salts field (In Russ.), Vestnik Permskogo

natsional'nogo issledovatel'skogo politekhnicheskogo universiteta. Geologiya.

Neftegazovoe i gornoe delo = Bulletin of Perm National Research

Polytechnic University. Geology. Oil & Gas Engineering & Mining, 2012, no. 5,

pp. 39-46.

5. Conti P.F., Controlled horizontal drilling, SPE 18708-MS, 1989.

6. Temichev A.A., Kychkin A.V., The software simulator PLC VIDA350 of energy

management system My-JEVis (In Russ.), Vestnik Permskogo natsional'nogo

issledovatel'skogo politekhnicheskogo universiteta. Elektrotekhnika, informatsionnye

tekhnologii, sistemy upravleniya = PNRPU Bulletin. Electrotechnics, Informational

Technologies, Control Systems, 2011, no. 5, pp. 210–220.

7. Zaikin I.P., Pankov M.V., Ismailov N.A., Pushkarev S.V., Rotary controllable system

PowerDrive and well log survey system PeriScope operation in horizontal

well drilling (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2009, no. 11,

pp. 68–70.

8. Xue Q., Wang R., Huang L. et al., The strap-down automatic vertical drilling

system design and field applications, The Electronic Journal of Geotechnical

Engineering, 2012, no. 1, pp. 3009–3018.

9. Kychkin A.V., The long-term energy monitoring based on OpenJEVis Software

(In Russ.), Vestnik Permskogo natsional'nogo issledovatel'skogo politekhnicheskogo

universiteta. Elektrotekhnika, informatsionnye tekhnologii,

sistemy upravleniya = PNRPU Bulletin. Electrotechnics, Informational Technologies,

Control Systems, 2014, no. 1 (9), pp. 5–15.

10. Jian K., BoXiong W., Zhong Xiang H. et al., Study of drill measuring system

based on MEMS accelerative and magnetoresistive sensor, Electronic Measurement

& Instruments, ICEMI 09, Beijing, China. 2009.

11. Xue Q., Wang R., Sun F. et al., Continuous measurement-while-drilling utilizing

strap-down multi-model surveying system, IEEE Trans. Instrum. Meas.,

2014, V. 63, pp. 650–657.

12. Kostygov A.M., Kychkin A.V., Artemov S.A., An automated system for remote

energy monitoring of mobile objects with electric drives (In Russ.), Elektrotekhnika

= Russian Electrical Engineering, 2015, no. 11, pp. 48–50.

13. Lyakhomskiy A.V., Perfil'eva E.N., Kychkin A.V., Genrikh N., A software-hardware

system of remote monitoring and analysis of the energy data (In Russ.),

Elektrotekhnika = Russian Electrical Engineering, 2015, no. 6, pp. 13–19.

14. http://os.is/gogn/unu-gtp-report/UNU-GTP-2013-27.pdf

15. Kostygov A.M., Kychkin A.V., Structurization of remote monitoring of a

group of intelligent mobile platforms in real time (In Russ.), Datchiki i sistemy

2013, no. 9 (172), pp. 65–69.

One of the main factors of complicated oil extraction on the territory of the main business activity site of Surgutneftegas JSC - Middle Ob is high water-bearing nature of the region, about 40%. On the territory of Russinskoye oil field the amount of water is even greater – about 70%, 30% is accounted for woodlans including bottom lands. The hydrocarbons extraction influences on all the components of the nature within the territory of the oil field. This could be observed through the changes of the original landscapes geochemical status of the environment. Regular monitoring fixes these changes.

In this article the data of presence of different hydrocarbons, carbonic acids, biogenic substances, heavy metals exceeding the threshold available concentration in all streamflows of Rusinskoye oil field is presented. This is the feature not only of the Rusinskoye oil field, but of the whole Khanty-Mansiysk Autonomous District-Ugra. This is proved by the annual researches made on these territories.

The same situation is with the bed deposits and with the soils. The threshold available concentration of pollution is not exceeded in atmospheric air only.