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Collaborating Authors
SPE Russian Oil and Gas Exploration & Production Technical Conference and Exhibition
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)
Development of Microbial Enhanced Oil Recovery Technology for Carbonate Formations: Stage 1
Khisametdinov, Marat (NTC Tatneft) | Sokolova, Diyana (NTC Tatneft) | Fedorov, Alexey (NTC Tatneft) | Khisamov, Rais S. (Tatneft) | Ibragimov, Nail G. (Tatneft) | Nazina, Tamara (Vinogradsky Institute of Microbiology) | Babich, Tamara (Vinogradsky Institute of Microbiology)
Abstract Initial stage of development of microbial enhanced oil recovery technology for carbonate petroleum reservoirs is presented. OAO TATNEFT has been successfully employing microbial technology in terrigenous formations for a long time. Results of carbonate reservoir characterization and microbial community analysis show prospectivity of microbial technology development for carbonate reservoirs as well. It has been found that microorganisms isolated from formation water can produce metabolites with high oil displacing potential when growing on carbohydrates. The main features of microbial method under development are formulated.
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.31)
Improvement of Drilling Technology for the Yarega Heavy Oil Field Development By SAGD Method with Counter Producing and Injecting Wells
Chertenkov, Mikhail V. (Lukoil) | Loparev, Denis S. (Lukoil-Engineering) | Buslaev, George V. (USTU Oil and Gas R&D Institute) | Yusifov, Asif A. (Scientific Drilling International) | Klyavlin, Aleksey V. (Scientific Drilling International)
Abstract Utilization of thermal production technologies in Yarega heavy oil field exemplifies a large-scale experiment of paramount importance for future development of oil industry, science, economics and technology. This paper presents a review of over than 75 year history of production technological development in Yarega heavy oil field. It shows that Russia pioneered and advanced in time in heavy oil and bitumen production, the world resources of which greatly exceed the light oil resources. The authors emphasize the LUKOIL-Komi experience, obtained during SAGD technology introduction in Yarega heavy oil field and drilling long horizontals (up to 1000 m) at shallow depths (200-210 m). SAGD technology was an alternative to oil mining, that had been used their since 1939. In 2006 three pairs of horizontals have been drilled in pilot testing area. Steam injectors were 5 m above producers, and average length of horizontal sections was about 300 m with total length of 610 m. In 2011-2012 another five pairs of producers and steam injectors have been drilled from two different clusters located 1400 m apart. Left and right pairs were azimuthally deviated. The problem in drilling of such wells was that the pay zone TVD was up to 220 m, and, therefore, the dog leg severity was 3.50° per 10 m. And the event of azimuth changes it increased up to 4° per 10 m and more. This resulted in problems with pushing BHA and casing, and also with placing fiber optic cable on the outer casing walls. In 2013 started the opposing wells drilling using the rack type rigs with 45-72° spudding angle, which decreased the dog leg severity and provided the longer horizontal sections. The paper provides a comparative analysis of advantages and disadvantages of vertical rigs and rack type rigs based on projected and actual field data.
- Europe > Russia > Central Federal District (0.31)
- Europe > Russia > Northwestern Federal District > Komi Republic (0.28)
- Europe > Russia > Northwestern Federal District > Timan-Pechora Basin > Chibyuskoye Field (0.99)
- Europe > Russia > Northwestern Federal District > Timan-Pechora Basin > Chibyu Field (0.99)
- Europe > Russia > Northwestern Federal District > Northwestern Federal District > Nenets Autonomous Okrug > Timan-Pechora Basin (0.99)
- (2 more...)
Abstract Growth in consumption of hydrocarbon resources in depletion requires effective methods for their extraction. One of these solutions is the construction of horizontal wells, the number of which in recent years have increased exponentially. Since the main task of drilling-horizontal well – is to increase drainage area of depleted reservoirs, the emphasis in this case is also given to the quality of primary formation exposing. Under the primary formation exposing of the producing formation pressure in the well is usually maintained above the reservoir pressure. As a result, washing liquid and the filtrate has penetrated under the influence of the repression on the producing formation. The dispersion medium of the washing liquid can penetrate into the layer even in the absence of repression by physico-chemical stimulation. Mud and liquid filtrate penetrating into the formation and contaminate collector, impair its reservoir properties in the area adjacent to the wellbore. The main reasons for the deterioration of reservoir properties of this zone – restriction of the pore channels, and even complete blockage of some of them due to mudding of dispersed phase drilling fluid; clay minerals formation swelling upon contact with an aqueous filtrate; upsetting of insoluble sludge in the interaction of the mud and reservoir fluids; reducing the mobility of the formation fluid into the contaminated area. The right choice of mud, subject to the characteristics of the reservoir enable to reduce the level and radius of pollution. For many decades, it is believed that optimal systems for primary formation exposing are oil-based system. The base of system is a hydrocarbon liquid on physico-chemical properties related hydrocarbon fluid saturating the producing formation. Composition comprises of hydrocarbon fluid, emulsifiers and aqueous phase. Under the influence of differential pressure they are filtered into permeable productive deposits. Growth in consumption of hydrocarbon resources in depletion requires effective methods for their extraction. One of these solutions is the construction of horizontal wells, the number of which in recent years have increased exponentially. Since the main task of drilling-horizontal well – is to increase drainage area of depleted reservoirs, the emphasis in this case is also given to the quality of primary formation exposing. Under the primary formation exposing of the producing formation pressure in the well is usually maintained above the reservoir pressure. As a result, washing liquid and the filtrate has penetrated under the influence of the repression on the producing formation. The dispersion medium of the washing liquid can penetrate into the layer even in the absence of repression by physico-chemical stimulation. Mud and liquid filtrate penetrating into the formation and contaminate collector, impair its reservoir properties in the area adjacent to the wellbore. The main reasons for the deterioration of reservoir properties of this zone – restriction of the pore channels, and even complete blockage of some of them due to mudding of dispersed phase drilling fluid; clay minerals formation swelling upon contact with an aqueous filtrate; upsetting of insoluble sludge in the interaction of the mud and reservoir fluids; reducing the mobility of the formation fluid into the contaminated area. The right choice of mud, subject to the characteristics of the reservoir enable to reduce the level and radius of pollution. For many decades, it is believed that optimal systems for primary formation exposing are oil-based system. The base of system is a hydrocarbon liquid on physico-chemical properties related hydrocarbon fluid saturating the producing formation. Composition comprises of hydrocarbon fluid, emulsifiers and aqueous phase. Under the influence of differential pressure they are filtered into permeable productive deposits. Components are interact and form a slow-moving mixture which block the pore space bottomhole formation zone.
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
Experimental Studies of Surfactant Adsoption Under Conditions of ASP Flooding at West Salym Field
Volokitin, Y. E. (Salym Petroleum Development N.V.) | Koltsov, I. N. (Salym Petroleum Development N.V.) | Evseeva, M. Ya. (Salym Petroleum Development N.V.) | Nurieva, O. A. (Gazpromenft NTC) | Akhatov, I. S. (Skolkovo Institute of Science and Technology) | Kovaleva, L. A. (Bashkortostan State University) | Zinnatullin, R. R. (Bashkortostan State University) | Mavletov, M. V. (Bashkortostan State University) | Kudasheva, F. H. (Bashkortostan State University)
Abstract To minimize risks related to ASP flooding at West Salym field, experiments have to be carried out to study surfactant adsorption in the formation. Initially one should develop a necessary and sufficient list of experiments, as well as their conditions and interpretation of results. Therefore, two objectives were set: 1) determine the adsorption of anionic surfactant blend in static conditions adding NaCl, Na2CO3, and polymer within the working range of concentrations; 2) determine the adsorption rate of an ASP formulation in coreflood experiments for water- and oil-saturated cores under formation temperatrue. The main reliability criterion for the results was the reproducibility of the surfactants adsorption experiments and achieving adsorption values within confidence interval. That is why, development of the methods that allow both to achive reproducibility of the results, and to identify sensitivity factors, is a critical aspect of the experiments. The work presents an interpretation of the experiments for subsequent modeling of processes using mathematic simulators with the view to evaluate surfactant losses in formation during ASP flooding. The achieved results allow further optimization of the ASP cocktail and return a realistic value for surfactant losses in the course of its filtration, as well as ascertain the economic risks inherent to the project.
- Research Report > New Finding (0.41)
- Research Report > Experimental Study (0.41)
Abstract Drilling of oil and gas wells is a basic process in production of hydrocarbons. Up to now drilling projects are often being designed on the base of segmental data and primary analysis of drilling experience, which is ineffective under modern drilling conditions. A possible solution of this problem consists in computer analysis of data on earlier drilled wells with the use of modern information technologies. Authors propose methods for prediction of probable troubles occurring while drilling new wells on the base of information on well stock of the oilfield using efficient data mining tools – artificial neural networks. Structural and parametric identification of a neural network solving the formalized problem of functions approximation has been conducted. Results of computational experiments on real data show effectiveness of software developed.
Use of Channel Fracturing Technology Increases Production and Reduces Risks in Horizontal Wellbore Completions - First Experience in Russia, South-Priobskoe Oil Field
Doctor, Sergey A. (Gazpromneft-Khantos) | Tolmachev, Alexey (Gazpromneft-Khantos) | Chebykin, Nikolay (Gazpromneft-Khantos) | Yudin, Alexey (Schlumberger) | Roukhlov, Valery (Schlumberger) | Gromovenko, Alexander (Schlumberger) | Mathur, Anil (Schlumberger)
Abstract South-Priobskoe field is in process of active development for over 10 years at the moment. Main producing horizons are low-permeable sandstone formations AS10-AS12 of Neocomian age. Hydraulic fracturing in the vertical wells proved to be effective way to increase oil production and provided profitable development of the oil field for several years period. Many wells had commingled production from 2 or 3 layers; each of the layers was stimulated separately. However, recent shift of drilling and development activity towards edge areas of the field led to reduction in formation quality and seldom well intersects more than one productive interval nowadays. Most effective way for such geological conditions is combination of horizontal well drilling development and multi-stage fracturing. This concept was successful applied worldwide for number of years and recently fulfill expectation at South Priobskoe field in Russia as well. Enhancement of oil production jointly with drainage scheme optimization allowed to decrease amount of wells and associated costs for infrastructure and well completion. Main weaknesses of this approach are increased screenout risks during fracturing operation and additional costs for horizontal wellbore cleanout in such a case. Implementation of channel fracturing technology became the next step of production optimization and well completion cost reduction. New method allows increasing reliability of proppant placement while improving fracture conductivity. These results are obtained by pulsing proppant on surface in conjunction with specialized equipment and fibers. New technology was implemented in 110 vertical wells over Russia including positive experience of channel fracturing campaign in 3 wells in South-Priobskoe field. This article describes Russia's first project of multistage stimulation (MSS) combined with channel fracturing technique applied in horizontal well. New approach allowed minimizing screenout risk, reducing completions costs and at the same time improving conductivity of hydraulic fractures. First production results showed increase in well productivity of over 15% compared to the neighboring horizontal wells stimulated by conventional MSS technique.
- Europe (1.00)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug (1.00)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Maverick Basin > Eagle Ford Shale Formation (0.99)
- (14 more...)
Copyright 2014, Society of Petroleum Engineers This paper was prepared for presentation at the Young Professionals session of the SPE Russian Oil and Gas Exploration and Production Technical Conference and Exhibition held in Moscow, Russia, 14-16 October 2014. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied.
- Europe > Russia > Central Federal District > Moscow Oblast > Moscow (0.25)
- Europe > Russia > Volga Federal District > Perm Krai (0.16)
Abstract Paper presents production logging (PL) problems in tight comingled reservoirs. Quantitative evaluation is possible when PL is done with JET pump or ESP & T-tool or naturally flowing wells. Authors have made series of numerical simulations to determine temperature distribution in producers and optimize production logging and interpretation procedure. Simulation illustrates traditional temperature interpretation technique with comparing well temperature logging curve with geothermal gradient is useless in case of tight reservoirs due to high influence of previous production and unstable flow. New way can handle that problem. New way of temperature interpretation to individual evaluation of tight comingled reservoirs can be used even in difficult for traditional temperature logging cases: horizontal wells, inflow control valves (ICV) presence in the wellbore, etc. Author’s method is based on mathematical simulation and on production logging case studies. In high rate producers temperature logging were compared with spinner and results were the same. Technology implementation on comingled wells of Western Siberia oil fields gives each formation rate and pressure. That results in production and injection optimization to increase sweep efficiency and recovery.