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Collaborating Authors
Romashkinskoye Field
Feasibility of Foam-Enhanced Water-Gas Flooding for a Low-Permeability High-Fractured Carbonate Reservoir. Screening of Foaming Agent and Flooding Simulation
Derevyanko, V. K. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Bolotov, A. V. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Minkhanov, I. F. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Varfolomeev, M. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Usmanov, S. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Saifullin, E. R. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Egorov, A. N. (CJSC, Aloil, Bavly, Russian Federation) | Sudakov, V. A. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Zhanbossynova, S (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation) | Sagirov, R. N. (Department of reservoir engineering, Kazan Federal University, Kazan, Russian Federation)
Abstract The carbonate reservoirs of the Alekseevskoye field (Russia, Republic of Tatarstan) are complicated by high heterogeneity and the presence of fractures, which make development difficult due to early water or gas breakthrough depending on the injected agent, as well as low of the productive horizon. To increase sweep efficiency and introduce fractured reservoirs into development, it is necessary to use gas enhanced oil recovery (EOR) technologies. To find the optimal technology in terms of technological complexity and efficiency, three technologies were compared: Water Injection (WI), Water-Alternating Gas (WAG), and Foam Assisted Water-Alternating Gas (FAWAG). Series of core-flooding tests were implemented under reservoir conditions on carbonate cores, and cores with artificial fractures, saturated with original reservoir fluids. For FAWAG method compatible with high-mineralization water surfactant was chosen. Total recovery factor for each test was calculated. It was equal to 33%, 76% and 53% respectively for WI, WAG and SWAG, on the original core models. Therefore, WAG and SWAG were chosen as most effective techniques to improve oil recovery for in comparison with CWI. In artificially fractured cores, the WAG method recovery rate was 40%; subsequent injection of a foaming active substance mixed with FAWAG formation water proved effective, increasing the oil recovery rate to 47% due to partial blockage of the fracture.
- Geology > Rock Type > Sedimentary Rock (0.46)
- Geology > Petroleum Play Type > Unconventional Play > Fractured Carbonate Reservoir Play (0.40)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.37)
- Europe > Russia > Volga Federal District > Bashkortostan > Alekseevskoye Field (0.99)
- Europe > Russia > Volga Federal District > Tatarstan > Volga Urals Basin > Romashkinskoye Field (0.94)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Fyodorovskoye Field (0.94)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug > West Siberian Basin > Central Basin > Samotlorskoye Field (0.94)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (4 more...)
Development of a smart tool for operational assessment of oil field development system effectiveness (Russian)
Kharlamova, D. I. (RN-BashNIPIneft LLC) | Kharlamov, K. A. (RN-BashNIPIneft LLC) | Ganiev, Sh. R. (RN-BashNIPIneft LLC) | Zhdanov, L. M. (RN-BashNIPIneft LLC) | Nikitenko, V. Yu. (RN-BashNIPIneft LLC) | Fatkhlislamov, M. A. (RN-BashNIPIneft LLC)
The article discusses approaches to creating a smart tool for operational evaluation of the efficiency of the development system by dividing the field sites (development blocks) into ranks according to the degree of confidence of reserves with further preparation of a research program, as well as the formation of geological and technical measures for the pre-development of clustered reserves. The standard practices used for the assessment and forecast of recovery factor (RF) do not allow to quickly identify problems, as well as timely and effectively plan corrective measures aimed at regulating the pace of stock selection. In this regard, an alternative tool for analyzing field development has been developed, the main idea of which is the clustering of recoverable oil reserves (according to the degree of their involvement in the development process) and verification of the parameters of the oil recovery coefficient. Effective involvement of reserves involves determining the boundaries of their localization. That is why the key stages of the proposed methodology are as follows: development of a tool for localization of remaining recoverable reserves (the method of clustering reserves and RF verification); determination of the reasons for not achieving the final RF; selection of additional research program; development of a tool for the selection of targeted geological and technical measures; assessment of the applicability of recommended geological and technical measures. The reserves were clustered, the RF was verified, and a smart card was built for one of the oil fields in Western Siberia, as well as the zones with the largest unprocessed reserves were identified and a program of additional studies and measures for the completion of reserves was formed. Depending on the category of the development site, as well as on the value of unprocessed reserves for each of the coefficients of the RF - an assessment of reserve losses due to the failure to achieve the design coefficient of displacement, flooding and coverage, respectively), recommendations are formed on the choice of geological and technical measures for involving non-drained zones in development. The developed methodology has been successfully applied at the fields of the Rosneft's subsidiaries, the effectiveness has been confirmed by the completed geological and engineering operations program.
- Europe > Russia > Volga Federal District > Tatarstan > Volga Urals Basin > Romashkinskoye Field (0.99)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Pโnyang Field (0.97)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Elk-Antelope Field (0.97)
- (10 more...)
The paper presents the results of studies of the effects of geomechanical factors on development of reservoirs confined to poorly cemented Tulskian sandstones. The study aims to assess the risks of irreversible reservoir changes in the interwell space due to deformations resulting from stresses beyond the elastic limit when reservoir pressure changes, provide recommendations on optimal bottomhole pressures for injection wells to ensure maximum injectivity, and determine critical drawdowns which result in carryover of solids into the wellbore for production wells. The results are based on 1D and 3D/4D geomechanical modeling. Input data used to build a geomechanical model included laboratory core study data and well logging data. Determination of elastic and strength properties, their dependence on other reservoir parameters and well logging data for each production target is a unique challenge. The paper presents the findings of geomechanical research efforts. The results of hydraulic fracturing processes analysis, downhole equipment maintenance data, reservoir pressure history, and well log interpretations were also used as input data. Laboratory core studies yielded the dependences on the parameters of radioactive logging methods (normalized gamma-ray logging, gamma-ray neutron logging) for estimation of geomechanical properties. Changes of the minimum horizontal stress with reservoir pressure variations were determined, recommended injection well overbalance ranges were obtained, analysis of solids carryover was conducted as well as calculations of critical drawdowns for production wells. Probability of irreversible reservoir changes in the interwell space for poorly cemented rocks was analyzed. Geomechanical modeling was conducted in GMS corporate software package of Tatneft PJSC.
Experimental and Numerical Analysis of Thermal EOR Recovery Schemes for Extra-Heavy Oil of the Oykino-Altuninsky Uplift of the Romashkinskoye Oilfield
Pituganova, Anastasia (Kazan Federal University) | Nassan, Taofik (Technical University Bergakademie Freiberg) | Amro, Mohd (Technical University Bergakademie Freiberg) | Minkhanov, Ilgiz (Kazan Federal University) | Varfolomeev, Mikhail (Kazan Federal University) | Bolotov, Alexander (Kazan Federal University)
Abstract Crude oil production from conventional oil reservoirs is declining owing to heavy exploitation to meet the global energy market demand which is growing on a yearly basis. Unconventional oil resources, e.g. extra-heavy oil and bitumen, can compensate for this decline if appropriate enhanced oil recovery (EOR) methods are developed to enable economic flow from these resources. The main objective of this study is to set the best practice for the extra-heavy oil production of the Oykino-Altuninsky uplift of the Romashkinskoye oilfield (Tatarstan Republic, Russia). A series of experimental tests are applied on a real unextracted unconsolidated core sample from Romashkinskoye oilfield where the viscosity of the crude oil is above 600,000 cP at reservoir conditions. Different recovery schemes are tested experimentally and sequentially, namely: water flooding, hot water flooding, steam flooding, and finally in-situ combustion (ISC). Furthermore, the complete experimental run is simulated by a standard nonisothermal simulator and the results are compared to the experiments. On contrary to what was expected hot water at 100ยฐC didnโt achieve any recovery from the sample and steam injection recovered only 11,5% of OOIP. ISC-is also known as fire flooding-attained the best recovery which reached 45% after steam flooding. Complete SARA analysis of the original oil and produced oil by steam and ISC is implemented to understand the mechanisms of each process. Numerical modeling is applied to the corresponding laboratory experiments and the results for water, hot water, and steam flooding were in good agreement with the experimental results while the in-situ combustion simulation showed a better recovery factor than experiments. The laboratory and numerical experiments will improve our understanding of the recovery options of Oykino-Altuninsky uplift of the Romashkinskoye oilfield and help the developers to choose the best production sequence for this oilfield particularly. Moreover, the experiments will provide inputs for the field-size numerical model after running more experiments on unconsolidated and consolidated cores.
- North America > United States (1.00)
- Europe > Russia > Volga Federal District > Tatarstan (1.00)
The Geochemical Survey Methods for Optimization of Oil Field Development
Sergeevna Shipaeva, Maria (Kazan Federal University) | Karlovich Nurgaliev, Danis (Kazan Federal University) | Anatolevich Sudakov, Vladislav (Kazan Federal University) | Albertovich Shakirov, Artur (Kazan Federal University) | Abuzarovich Lutfullin, Azat (PJSC Tatneft) | Galievich Ganiev, Bulat (PJSC Tatneft) | Ilfatovich Minikhairov, Lenar (PJSC Tatneft)
Abstract The paper considers issues of determining the direction of filtration for oil deposits by means of complex study of the geochemical composition of formation fluids and the dynamics of bottomhole pressure and flow rates, and further use of this information in geological and reservoir simulation models. This integrated technology is not expensive and makes it possible to identify geological uncertainties in the reservoir for intelligent management of development processes, such as waterflooding optimization, reservoir simulation models improvement, water cut source definition, etc. Improving the reliability of information about the reservoir and the presented fluids is undoubtedly relevant and significant task. To solve this problem, fluid samples were taken and complex studies of the composition of the produced water was carried out, including the determination of hydrogen and oxygen isotopes and element composition. The authors note that the isotopic composition of formation waters for a number of wells differs from the analogical parameters for injected water, which is probably associated with the area of โโuneven reservoir distribution and the existence of a stagnant undrained zone. The result of the calculations is an estimate of the impact coefficient of the injected water on the water composition in the surrounding producer wells. In addition to this, the work included the analysis of the dynamics of fluid flow rate, oil flow rate, bottomhole and reservoir pressures, the influence of injection on the pressure in the drainage area of โโproducer wells. Basing on the results obtained the recommendations were given for changing the injection patterns as it is noted that a number of wells are not affected by injection. Recommendations have been developed for carrying out workovers in order to prevent a decrease in pressure and an increase in oil production.
- Asia (0.47)
- Europe > Russia > Volga Federal District (0.28)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
The Choice of the Optimal Strategy for the Use of Solvents of High-Molecular Organic Deposits, Considering their Complex Composition and the Effect on the Oil Dispersion System
Guskova, Irina Alekseevna (Almetyevsk State Oil Institutes) | Khayarova, Dinara Rafaelevna (Almetyevsk State Oil Institutes) | Abzyapparova, Elvira Rafaelevna (Almetyevsk State Oil Institutes)
Abstract The long-term practice of operating wells producing oil rich in paraffins and asphaltenes has shown that the optimization of technologies for the removal of solid high-molecular organic deposits (asphaltene-resin-paraffin deposits) in oilfield equipment, lifting pipes and flow lines makes it possible to effectively solve the issues of improving the environmental friendliness and energy efficiency of oil production. The use of composite hydrocarbon solvents is one of the most well-known methods used to remove asphaltene-resin-paraffin deposits. Thus, to date, there is no systemic solution to this issue. This paper is aimed at discussing the provisions that determine the possible prospects for the development of an optimal strategy for the use of solvents for the removal of asphaltene-resin-paraffin deposits.
- Europe > Russia (0.46)
- North America > United States > Texas (0.28)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Inhibition and remediation of hydrates, scale, paraffin / wax and asphaltene (1.00)
- Facilities Design, Construction and Operation > Flow Assurance > Precipitates (paraffin, asphaltenes, etc.) (1.00)
Delineating the Multi-Stacked Domanik Play in the Volga-Urals Basin, Russia
Shaw, Kevin (APEX Petroleum Engineering) | Randolph, Theodore (APEX Petroleum Engineering) | Anthony, William (APEX Petroleum Engineering) | Harkrider, John D. (APEX Petroleum Engineering) | Gendelman, Igor (Wavetech Energy)
Abstract This paper shows the importance of an integrated, multidisciplinary approach to exploiting the unconventional Domanik Play in the Volga-Urals Basin in Russia. A combination of understanding the reservoir and applying different completion techniques is necessary to verify the best way to drill, complete, and produce the basin. In 2012, DirectNeft drilled the first well specifically targeting the Domanik interval in the Volga Ural Basin. This discovery well tested oil from multiple horizons within the 350+ m (1150โ) thick "Domanikoid" section. In the broad Upper Frasnian interval, Well A was the first successful hydraulic fracture treatment in the Domanik. The subsequent Well B, seven miles to the northwest, penetrated a largely identical Domanik section and was also fractured and tested in multiple horizons, including the Upper Frasnian. Well tests, logs and core analysis have identified two primary and two secondary productive intervals within the Domanik. These two wells provided the first sets of modern logs in the area, which are critical to better understand the reservoirs. In addition, the coring of key intervals and extensive analysis of those cores have proven invaluable in understanding the nature of the reservoirs. Existing well control and seismic data clearly indicate the thick section of Domanik rocks extends throughout the area. The presence and viability of oil saturated Domanik low permeability reservoirs has been confirmed by the two wells. Oil flows have been recovered from perforated intervals of the Tournaisian, Zavolzhian, Famennian and Upper Frasnian. Based on these exploration findings, subsequent operations expanded the project by drilling four horizontal wells in 2017-2018, three of which have been completed. Objectives are multi-fold and included further delineation of the four productive intervals by refining the understanding of geologic, petrophysical and geomechanical models that influence the completion and stimulation operations, ultimately impacting production. Early results from the completed wells have shown a rapid improvement in production results, showing that the multidisciplinary workflow is successful. Future tests incorporate significant increase of entry points to further prove the success of the play. This paper describes the methodology and modifications implemented based on improved understanding of the reservoir, including the use of multi-stage completion techniques. Also discussed are operational issues related to implementing state-of-the-art completion techniques including sliding sleeves, coil-tubing operations, jet cutting operations and plug and perf operations.
- Europe > Russia > Volga Federal District (0.90)
- Europe > Russia > Northwestern Federal District (0.81)
- Geophysics > Borehole Geophysics (0.93)
- Geophysics > Seismic Surveying (0.86)
- Europe > Russia > Volga Federal District > Volga Urals Basin (0.99)
- Europe > Russia > Northwestern Federal District > Volga Urals Basin (0.99)
- Europe > Russia > Volga Federal District > Tatarstan > Volga Urals Basin > Romashkinskoye Field (0.94)
- Europe > Russia > Volga Federal District > Bashkortostan > Volga Urals Basin > Arlanskoye Field (0.94)
Geochemical Monitoring of Formation Fluids for Reservoir Management Considering Complicating Factors in Mature Oilfields
Shipaeva, Mariya Sergeevna (Kazan Federal University) | Nurgaliev, Danis Karlovich (Kazan Federal University) | Zaikin, Artem Aleksandrivich (Kazan Federal University) | Sudakov, Vladislav Anatolevich (Kazan Federal University) | Shakirov, Artur Albertovich (Kazan Federal University) | Abuzarovich, Lutfullin Azat (PJSC ยซTatneftยป) | Ganiev, Bulat Galievich (PJSC ยซTatneftยป)
Abstract At the present stage of the hydrocarbon production process, most of the unique and largest fields in the world are at a late stage of development. Despite the active development and policy of a decarbonised economy, the demand for liquid and gaseous hydrocarbons remains high, while of inevitably growing the number of mature fields. The Volga-Ural oil and gas province today is an old oil and gas producing region, most of the fields have already entered the final stage of development. However, through the introduction and development of new technologies for oil extraction, monitoring of production and localization of reserves, the life of the fields can be extended. One of these technologies is geochemical monitoring of well production. Its goal is to optimize the development of mature fields on the basis of promptly obtained information about the state of the wells using geochemical studies of the formation fluid, allowing timely implementation of the necessary measures. Geochemical studies allow identifying the source of fluid entering the well, determining a violation in the wellbore structure, checking the tightness of downhole equipment for separate operation, and performing an area analysis of the area development efficiency. This type of research is relevant both in giant fields with a large stock of production wells, often characterized from a geological point of view by multilayer structure, with technological complexity, packing, wear of equipment and strings, in some cases the impossibility of running gauge for research, and in fields with low depletion. The possibilities of geochemistry for solving local operational problems in wells are shown. Several hydrogeological complexes have been studied, the change in the properties of the produced water during the development process is described. The concepts of the geochemical conditions in the hydrocarbon deposits that existed earlier are changing due to the development of these objects as a dynamic system, continuous injection of different types of water into the reservoir, the use of enhanced oil recovery methods and other technogenic impact associated with the development of reserves. The digital revolution and the modern development of the industry marked the beginning of the creation of the Digital Atlas of Groundwater, the development of specialized algorithms that allow processing large amounts of data.
- Phanerozoic > Paleozoic > Carboniferous (0.67)
- Phanerozoic > Paleozoic > Devonian (0.46)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Environmental Geology > Hydrogeology (0.34)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Geochemical characterization (0.88)
- Health, Safety, Environment & Sustainability > Environment > Water use, produced water discharge and disposal (0.67)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (0.66)
Application of machine learning method for planning of well drilling in producing oil formations (Russian)
Ganiev, B. G. (Tatneft PJSC) | Nasybullin, A. V. (TatNIPIneft) | Sattarov, Ram. Z. (TatNIPIneft) | Timofeev, V. S. (Novosibirsk State Technical University) | Faddeenkov, A. V. (Novosibirsk State Technical University) | Timofeeva, A. Yu. (Novosibirsk State Technical University)
The paper describes algorithms for predicting oil production rates based on Arps model whose parameters are estimated in terms of well production performance and the algorithm based on panel data models with a trend component described by Arps model. An algorithm for selection of input factors based on Bayesian neural networks has been proposed and implemented. An algorithm for construction of piecewise multiple regression models to estimate the Arps constant and to predict oil production rates based on application of Kohonen networks and structural change analysis approaches has been proposed and implemented. This method for prediction of oil production rate and production decline considers numerous factors that influence production performance. A module for prediction of oil production performance of project wells has been developed. The host application is written in Python 3.6 programming language. Computational algorithms of model building are implemented in R programming language. The authors describe the principle of operation of software module for forecasting oil production performance of project wells. The described method has been field tested at production sites of Tatneft Company. Machine learning has been done using selected geological and production data from producing wells in Kynovian and Pashian reservoirs for a group of production areas of Romashkinskoye field. Machine learning enabled selection of project wells and estimation of production and economic performance. A comparative analysis of existing methods for prediction of input oil production rates and annual production decline rates of project wells for the selected group of areas has been performed. Resultant data suggest applicability of machine learning method for prediction of production performance of project wells in oil fields. This is particularly important for mature fields, which provide sufficient accumulated statistical data required to apply machine learning methods.
The interest in hard-to-recover hydrocarbon reserves has recently increased significantly, which is primarily due to the need to maintain the level of oil production in the late stage of development. Since all relatively large oil fields in Republic of Tatarstan have been identified and developed, in the last decade, the process of exploration extra-heavy oil deposits, whose reserves are enormous, has been rapidly developing. The object of the study is extra-heavy oil reservoir of the Kamyshla Beds of the Kazanian Stage, confined to the Gorskoye field, located in the marginal part of the Eastern side of the Melekess depression, near its junction with the western slope of the South Tatar arch. At the same time, the location of the field within the outer side zone of the Ust-Cheremshan trough of the Kama-Kinel trough system predetermined the significant influence of sedimentation processes on its formation. In order to establish the genesis, time of formation of the trap and Gorskoye extra-heavy oil deposit, the authors constructed a series of structural maps, carried out studies by methods of isopachic triangle and graph of structure growth. Paleotectonic reconstructions of the studied territory at various stages of ontogenesis allowed us to establish that the core of the Gorsky structure is an organogenic structure of Late Frasnian age, the growth of which was resumed repeatedly until the Early Kazanian age. The formation of the Gorskoye extra-heavy deposit occurred in the Late Permian age, and as a result of tectonic movements of the Alpine stage of tectogenesis, the deposit finally formed and began to collapse.
- Phanerozoic > Paleozoic > Permian (1.00)
- Phanerozoic > Paleozoic > Devonian > Upper Devonian > Frasnian (0.54)
- Europe > Russia > Volga Federal District > Tatarstan > Volga Urals Basin > Romashkinskoye Field (0.99)
- Europe > Russia > Northwestern Federal District > Kaliningrad Oblast > Baltic Sea > Baltic Basin > Kravtsovskoye Field (0.99)
- Europe > Russia > North Caucasian Federal District > North Caucasian Federal District > Republic of Ingushetia > North Kavkaz Basin > Malgobek Voznesenskoye Field (0.99)
- (25 more...)