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Zervando K.Y.,TNK BP | Safonov V.G.,TNNC
7th EAGE Saint Petersburg International Conference and Exhibition: Understanding the Harmony of the Earth's Resources Through Integration of Geosciences | Year: 2016

The report demonstrates the main results of exploration activities within the Uvat project in the last 10 years. The experience of application of the new techniques such as inversion and basin modeling is described. The evolution of ideas about geology and regional petroleum potential of Uvat area is also described.The profile of successful E&A drilling and growth of recoverable oil reserves in 12 years is given, which reflects the efficiency of the geological study strategy for the Uvat project generated by studying the results of exploration activities and scientific and analytical support. This approach can be used on other major projects of the company at an early stage of their development.

Kats R.M.,Russian Academy of Sciences | Volgin E.R.,TNK BP
Society of Petroleum Engineers - SPE Russian Oil and Gas Technical Conference and Exhibition 2010, RO and G 10 | Year: 2010

The localization of oil reserves in water-flooded areas is considered. Despite a high watercut of 90% or more well production, individual regions of the reservoir can retain recoverable oil. These reserves may have rather high (up to initial) oil saturations. Developing these reserves even partly will deliver a valuable incremental field production. Oil field development experience shows that recovery factor can be comparatively low, even at the late development stage. The issue of additional recovery is illustrated by the Bavly oil field experiment which ran for 30 years. This experiment included high watercut wells that were shut-in for a long time and subsequently brought back into production, and some of the wells yielded tens of thousands of tons of crude. Moreover it was established that remaining reserves can be located in certain areas. So, the problem of finding the location of such areas needs to be solved without resort to large-scale experiments like this. If we could do this, the scope of late stage infill drilling could be reduced thus preventing wells being drilled in swept zones. Currently the issue of finding high oil saturation zones is generally solved through reservoir modeling. The issue of the accuracy of modeling oil saturation distribution is of primary importance for a reservoir engineer. There are a variety of numerical methods for modeling oil and gas field development processes widely in use, but are not sufficiently reasonable for this goal. In the general case, heterogeneous media cannot be described by averaged equations with scientifically based pseudo-relative permeabilities. The inconsistency of using pseudo relative permeabilities for simulation of the heterogeneous reservoir development is illustrated by numerical experiment. The pseudo relative permeabilities technique enables forecasting the field production and injection rates and cumulatives only. The reliability of the prediction of the oil saturation distribution turned to be unsatisfactory. This means that currently used pseudo relative permeabilities techniques do not allow reliable detection of bypassed oil. At the moment, the only efficient method of locating unrecovered oil reserves is integration of advanced reservoir study methods combined with geological modeling and reservoir simulation. Copyright 2010, Society of Petroleum Engineers.

Akhkubekov A.E.,Rosneft | Vasilyev V.N.,TNK BP
Society of Petroleum Engineers - SPE Russian Oil and Gas Technical Conference and Exhibition 2010, RO and G 10 | Year: 2010

Petroleum industry needs low-cost and efficient hydrocarbon production enhancement techniques. Oil and gas reserves production need to be economic; therefore high-technology stimulation methods should be used. The considerable part of hydrocarbon world reserves is associated with carbonate reservoirs. To enhance production in carbonate reservoirs, the conventional and special techniques are applied. Sidetracking includes heavy expenses in both money and time, since it requires rig installation and drilling crew gathering. The carbonate natural property of dissolution with acid is used in acidizing and acid fracs. Acid treatment is inefficient in thick reservoirs, thus the treatment design becomes quite complex to achieve efficient acid placement. The acid frac efficiency in carbonate reservoirs is controlled by matrix to fracture porosity ratio, whereas acid fracs in fractured reservoir with zero matrix porosity will be unefficient. This paper describes the possibility to apply a relatively new enhancement technique - acid-tunneling - in Timan-Pechora oil province carbonate reservoirs in Russia. In this paper the evaluation methods of vertical and multilateral well potential are specified; the productivity ratios of various multilateral well designs in dual porosity reservoirs vs. permeability anisotropy are shown; the pseudoradial skin-factor calculation procedures of multilateral well are described. The well candidate technologic and economic selection criteria are also considered. As a result, the matrix of production enhancement technology application in Timan-Pechora oil and gas province has been developed. Copyright 2010, Society of Petroleum Engineers.

Alekseeva V.A.,TNK BP | Karfunkle J.,TNK BP
Society of Petroleum Engineers - SPE Russian Oil and Gas Exploration and Production Technical Conference and Exhibition 2012 | Year: 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. Copyright 2012, Society of Petroleum Engineers.

Cheremisin A.N.,TNK BP | Cheremisin N.A.,TNK BP
ECMOR 2012 - 13th European Conference on the Mathematics of Oil Recovery | Year: 2012

There exist a number of researches, which prove that the frequencies ranging from one to several thousands hertz as applied to oil reservoirs enhance the well stream and reduce watercut. Well-elaborated are the physical basis and various cases of basic technologies and solutions for commercial applications of vibroacoustic bottom hole treatment to restore the permeability and the increase the inflow in a well, but the question is still open regarding the mechanism to affect the remote flushed-out zone. This work addresses the wave EOR method. We have proven the relation of the natural frequency spectrum of the capillary trapped oil with the pore space in the reservoir, its current oil saturation and the external pressure gradient. The model was developed for the two-phase flow in the acoustic field based on the resonance effect on capillary trapped residual oil saturation. The model was backtested on site in Samotlor and other oil fields. Some model cases resulted in the methodic basis for efficient wave action application for various types of reservoirs and different development conditions. We provide evidence that oil recovery is enhanced locally if the oil reservoir is exposed to acoustic frequencies of 300 to 3000 Hz.

Yushkov A.Y.,TNK BP
ECMOR 2012 - 13th European Conference on the Mathematics of Oil Recovery | Year: 2012

The paper reviews the problem of very low or zero productivity of simulated horizontal wells, when "connections" are placed in cells with zero vertical permeability (PERMZ). Such cells may imply, for instance, thin interlayering of permeable and impermeable interbeds inside one cell. The formulas are considered to calculate parameters describing the fluid flow to the "connection": The equivalent radius (R0j), transmissibility (khj), and the connection factor (Tj or CCFj). The conditional calculated examples show shortcomings of formulas and the reasons that lead to zero productivity of simulated wells. The author proposes refined formula to calculate Tj , R0j khj, that account the well diameter going through the model cell. The formula imply that thinly-bedded vertically impermeable formation unit which has a plane-parallel filtration flow running across the area equal to well diameter multiplied by completion length. The applicability of the model for bigger cells is demonstrated by comparison of results obtained on the detailed grid. Bigger cells-based calculation results are close to those obtained on the detailed grid. The proposed formula can be used in dynamic simulators for more accurate simulation of fluid flowing to horizontal wells in case of bigger cells.

Malysheva E.,TNK BP
75th EAGE Conference and Exhibition Incorporating SPE EUROPEC 2013 | Year: 2013

The presentation will touch upon the comparison of well based and seismic interpretation models on the example of two hydrocarbon fields in Pechora oil and gas basin. It shows that the latter provides much more accurate lateral distribution of reservoirs in the inter well space. On the other hand in complicated polyfacial successions only apriori depositional models provide accurate and geologically reasonable interpretation of seismic data.

Kovalenko Igor V.,TNK BP
Society of Petroleum Engineers - SPE Heavy Oil Conference Canada 2012 | Year: 2012

Today considerable amount of hard-to-recover reserves from low reservoir properties formations or high-viscosity oil are involved into development. Hydraulic fracturing or horizontal wells drilling are applied to provide economic development. On the one side the low piezoconductivity value reduces the rate of pressure redistribution in the reservoir around the well. On the other side hydraulic fracture or horizontal well move away the radial flow in the reservoir for a considerable distance from the well. The joint presence of these two conditions leads to a failure to achieve radial flow at the appropriate times resulting in a high uncertainty during well testing interpretation. This article describes approaches of uncertainties reduction during the well testing interpretation in case of failure to achieve the late pseudoradial flow. The suggested method is based on the application of the special filtration equations in the early regimes to linear drain where as an example the horizontal well or hydraulic fracturing in the reservoir was provided. The presented solutions were successfully applied in both the heavy oil fields and in the other types of fields where the late filtration radial regime was not achieved during the well testing. Copyright 2012, Society of Petroleum Engineers.

Ivantsov N.,TNK BP | Stepanov S.,TNK BP
Society of Petroleum Engineers - SPE Heavy Oil Conference Canada 2012 | Year: 2012

This article describes the results of a theoretical and numerical study of the problem of a sharp drop in production rates of horizontal wells in one of Western Siberia fields represented by reservoirs consisting of poorly consolidated rock and saturated with heavy oil. The under gas cap oil rim is developed by depletion by horizontal wells. The reduction of the production rates is analyzed from different perspectives among which the most appropriate idea is elastoplastic deformation of the rock with its subsequent destruction in the bottomhole zone. Based on the analysis of the stress-strain state and theoretically justified rock ultimate strength, it is shown that actual bottomhole pressures lead to brittle fracture of the rock and, as a result of related processes, to particles movement and sharp increase in the skin factor. Copyright 2012, Society of Petroleum Engineers.

Stepanov S.,TNK BP | Vasilyev V.,TNK BP
ECMOR 2010 - 12th European Conference on the Mathematics of Oil Recovery | Year: 2010

At present, most of the companies that work in oil and gas industry are facing the situation which urges them to improve the efficiency of field development and, particularly, residual resources development. The solution of this problem requires comprehensive approach which should account for all significant factors attributable to field development including the consistency of hydrodynamic simulation modeling. This is especially concerned with the genuine understanding of correct modeling of processes occurring in bottomhole formation zone, both from the point of displacement processes physics, and from the point of mathematical algorithms applied to solving respective differential equations. From the above standpoints this paper furnishes the findings of bottomhole formation zone modeling problem study. Calculations were made for individual wells. It is shown that the complex nonmonotonic actual watercut history of the well can be represented by solving respective inverse problems with proper account taken for capillary and deformation processes. The relative phase permeabilities vs. pressure gradient relationship and capillary-gravity transition zone allow explaining of nonmonotonic watercut well history even at the constant well flow rate. The degree of inaccuracy in reservoir performance calculations made on numeric filtration models using coarser grids is supported by well-watercut analytical solution. In this context the concept of correction function that allows smoothening of coarse cells impact is introduced. It is also shown that use of stream line method in the well-vicinity area allows essential improvement of flow structure description and enhancement of reservoir performance calculation adequacy. Thus, when solving the problems of practical importance it appears that though the existing software simulators are capable of generating history-matched numerical filtration models, in most of the cases such models are not adequate to the reality, especially in terms of describing bottomhole formation zone processes.

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