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Samara Oblast
Improving the efficiency of forecasting and preventing zones of complete and catastrophic lost circulation in reef structures of the Kama-Kinel downfold system (Russian)
Shipovskiy, K. A. (SamaraNIPIneft LLC) | Tsirkova, V. S. (SamaraNIPIneft LLC) | Koval, M. E. (SamaraNIPIneft LLC) | Kozhin, V. N. (SamaraNIPIneft LLC) | Pilipets, E. Yu. (Rosneft Oil Company) | Krepostnov, D. D. (Rosneft Oil Company)
The article discusses the results of the study of the causes of complete and catastrophic lost circulation when drilling exploration and production wells in the reef structures of the Kama-Kinel downfold system. The features of the distribution of zones of mud losses of different intensities in the drowned the Upper Frasnian-Famennian-Tournaisian reef system are analyzed using the example of the Blagodarovsky uplift of the Kuleshovskoye field. It is shown that total and catastrophic lost circulation is mainly confined to the zone of the reef-front apron, which consists of psephitic and weak carbonate rocks. Drilling in a reef-front apron can be accompanied by drilling tool failures with loss of circulation and a significant decrease in the static level of the flush fluid. Partial losses occur, as a rule, in the zone of the carbonate core of the reef, its frontal and rear zones. The absence of losses or insignificant loss of circulation of the drilling fluid is characteristic of the depression (backreef) zone of the organogenic rocks. It was noted that it is important to determine the contours and amplitudes of the drowned reef, the boundaries of its facies zones. This enables to use standard S-shaped profiles when designing wells, bypassing possible intervals of complete and catastrophic lost circulation. At the same time, it allows to make the necessary technical and technological decisions for timely prevention and effective elimination of complications when drilling wells in organogenic massifs. It is shown that a detailed analysis of geological and geophysical information, taking into account the technical and technological data on previously drilled wells, makes it possible to predict zones of possible complications and develop effective measures to prevent complications at the design stage in order to increase the efficiency, reliability and safety of well construction and reduce the cost of drilling works at the fields of Rosneft Oil Company.
Foam Acid Treatment - The Key to Stimulation of Carbonate Reservoirs in Depleted Oil Fields of the Samara Region
Letichevskiy, Alexander (JSC Samaraneftegaz Rosneft) | Nikitin, Alexey (JSC Samaraneftegaz Rosneft) | Parfenov, Alexey (JSC Samaraneftegaz Rosneft) | Makarenko, Vitaliy (JSC Samaraneftegaz Rosneft) | Lavrov, Ilya (JSC Samaraneftegaz Rosneft) | Rukan, Gleb (Schlumberger) | Ovsyannikov, Dmitry (Schlumberger) | Nuriakhmetov, Ruslan (Schlumberger) | Gromovenko, Alexander (Schlumberger)
Abstract Oil fields of the Samara region are at a late stage of development, which is reflected in declining of their production level and rapid growth of watercut. About 30% of the region's industrial hydrocarbon reserves are concentrated in carbonate reservoirs, which require stimulation. Low reservoir pressure, heterogeneity of the formation and the proximity of water-saturated interlayers significantly complicate the task of efficient field development and exploitation. In such conditions, the use of traditional methods for treating the bottomhole zone of carbonate rocks does not bring the expected results, and the worsening stock of exploited objects makes it necessary to look for new promising methods for increasing oil recovery. Carbonate reservoirs stimulation in the Samara region is carried out using a spectrum of various technologies of hydrochloric acid treatments, both to extend the life of old wells and to efficiently start new wells after drilling. In order to increase the effect from the performed hydrochloric acid treatments in 2016, the foam diverting technology was applied in the framework of pilot projects. This technology uses a stable non-damaging agent to form a nitrogen foam of 65% quality at the bottom hole. After the treatment, the foam breaks down into liquid and nitrogen, which in turn improves well flow back and helps to restore the natural flow. Despite the high degree of field development, the use of foam made it possible to achieve a 69% greater initial well productivity index than other methods. At the same time, the starting production rate of wells increased almost 2 times. The technology also allowed to reduce the specific volume of injected acid per meter of oil saturation by 25% without compromising the efficiency of the treatment, what has key importance from the point of view of economic feasibility. Based on the results of the performed pilot operations, nitrogen-foam acid treatments were included in the regular program of wells stimulation.
- North America > United States (0.94)
- Asia (0.69)
- Europe > Russia > Volga Federal District > Orenburg Oblast (0.29)
- Europe > Russia > Volga Federal District > Samara Oblast (0.28)
- Europe > Russia > Volga Federal District > Samara Oblast > Volga Urals Basin > Kuleshovskoye Field (0.99)
- Europe > Russia > Volga Federal District > Orenburg Oblast > Precaspian Basin > Orenburg Field (0.99)
- Europe > Russia > Volga Federal District > Samara Oblast > Volga Urals Basin > Zhigulev-Orenburg Arch > Dmitriyevskoye Field (0.96)
New Opportunities for Brownfields: Channel Fracturing Offers a Significant Increase of Well Productivity in Complex Geological Conditions in the Samara Region
Letichevskiy, Alexander (JSC-Samaraneftegaz Rosneft) | Nikitin, Alexey (JSC-Samaraneftegaz Rosneft) | Parfenov, Alexey (JSC-Samaraneftegaz Rosneft) | Makarenko, Vitaliy (JSC-Samaraneftegaz Rosneft) | Lavrov, Ilya (JSC-Samaraneftegaz Rosneft) | Rukan, Gleb (Schlumberger) | Yudin, Alexey (Schlumberger) | Ovsyannikov, Dmitry (Schlumberger) | Nuriakhmetov, Ruslan (Schlumberger) | Gromovenko, Alexander (Schlumberger)
Abstract A characteristic feature of oil fields in the Samara region which main oil reserves are concentrated in terrigenous formations is considered to be a high level of exploration and depletion. One of the main challenges the solution of which will allow to maintain the current level of production is the systematic application of modern technologies for the oil inflow stimulation of small and hard-to-reach reservoirs with unfavorable geological and physical conditions. Under these circumstances the classical fracturing method with regular proppant injection has no the proper effect, what forces the oil producing companies to recourse to more efficient technologies. Gradually deteriorating geological conditions limit both the size of the proppant pumped and the tonnage of the whole hydraulic fracturing operation, not allowing to achieve the optimal "formation-well" connection. To optimize the fields development process in 2015-2016 four pilot operations were performed with a new technology for the region - the cluster fracturing. When it is performed, the proppant is being pumped with "pulses" alternating with self-dissolving fibers, thus achieving a highly conductive fracture structure that removes the restrictions for hydrocarbons inflow occurring during conventional fracturing. The development objects, treated with channel hydraulic fracturing, were sandstones of the Devonian system (D1, D3, Dk) of the Kuleshovskoye oil field, which was discovered as far back as 1959 and being the second largest in the Samara region. These formations are characterized by low reservoir properties and located at a much greater depth in comparison with the main oil reservoirs. The obtained results showed that the wells after the cluster fracturing demonstrated a productivity coefficient higher by 47%, the oil production rate increased by 1.56 times as compared to the wells with the conventional fracturing. Good production results were obtained due to the pad stage percent decreasing, a reduction of the fluid volume (when converted to the equivalent mass of standard fracturing), and the use of higher proppant concentrations.
- Europe > Russia > Volga Federal District > Samara Oblast > Volga Urals Basin > Kuleshovskoye Field (0.99)
- Europe > Russia > Volga Federal District > Orenburg Oblast > Volga Urals Basin > Tsarichanskoye Field (0.99)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Central Basin > Taylakovskoye Field (0.99)
- Europe > Russia > Volga Federal District > Samara Oblast > Volga Urals Basin > Zhigulev-Orenburg Arch > Dmitriyevskoye Field (0.97)
Abstract The problem of stability wellbore appears especially true when buroenii horizontal wells. This paper presents the results of stability analysis of rock Mukhanovskoye field. Also offers advice on selecting inhibited drilling fluid systems. The relevance in consideration and in the forecast of massif rock tension that contain oil and gas-saturated reservoirs is characteristic for the majority of the fields complicated by the abnormally high formation pressures (AHFP) [1]. Besides now they start the development of the fields with hard-to-recover reserves characterized by complex rock-and-geological conditions, low permeability and poor development of infrastructure. One of problems related to these fields consists in poor knowledge on regional stresses in the fields and sharp variability of magnitudes and orientation of horizontal stresses by depth. The stress condition of the rock produces significant impact upon the wall stability in the well especially in its horizontal sections. Need to consider the stress direction and its magnitude while selecting the well construction and completion procedure is related to their influence upon the direction of natural fracture system development and the dependence of fracture direction created by hydro-fracturing operations upon the natural stress status that subsequently has significant impact on the production volume [2]. For fields in development this need is connected with their impact upon the oil and gas production, as well as with the application of some production stimulation procedures and their effect upon the stress local fields. Change in formation pressure, arrangement of formation pressure maintenance system, extensive application of reservoir hydro-fracturing jobs conducts the redistribution of stresses and tensions in the rock near some wells, and sometimes for the whole field [3]. Indirectly this is confirmed by expansion of areas connected with the technogenic seismicity caused by field development process. Thus, it’s required to have continuous monitoring over the rock stresses in the area of hydrocarbon fields and the consideration of the information received by these measurements while constructing the wells and developing the fields using the oil production stimulation procedures [1]. The monitor of excessive or abnormally high formation pressure (AHFP) should be considered as the versatile aspect that combines the elements of geology, rock mechanics, chemistry and engineering. For this it's required to have the information on regional geological history as well as the results on detailed studies for the wells drilled closely or directly across the territory under study.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.57)
Abstract This paper considers the output mode wells equipped with electric centrifugal pump units (ECPU). The inference process is a complex task in unsteady hydrodynamic work, as most of the well and the reservoir. Process occurring in the reservoir in the derivation of ECPU mode, described by the differential diffusion equation. In this paper, to solve this equation for small times a mathematical model of hydrodynamic processes occurring in the well in the derivation mode. The resulting model accounts teamwork bottomhole formation zone, the well and pump. Theoretical dependence of the decline curve in the well was compared with practical ones obtained at the well number 16 of West-Shirochenskoe field of JSC "Samaraneftegaz." It has been found good agreement between the theoretical and practical curves. The resulting mathematical model was used to determine reservoir parameters (permeability, diffusivity coefficient, skin factor) for several wells of JSC "Samaraneftegaz." Next to this model is planned for full forecast output process well in the regime, i.e. determining the value of the maximum reduction value of dynamic level and time of its occurrence.
- Asia > Russia (0.47)
- North America > United States > Texas (0.29)
- Europe > Russia > Volga Federal District > Samara Oblast (0.15)