Russian Oil Fields Research Articles

Прогнозы развития крупнейших сегментов рынка нефтесервисных услуг России

Прогнозы развития крупнейших сегментов рынка нефтесервисных услуг России

О формировании российской нефтесервисной отрасли

О формировании российской нефтесервисной отрасли

MAIN PRINCIPLES OF WELLS SELECTION PLANNING FOR INTERVENTION AT OIL FIELDS WITH HARD-TO-RECOVER RESERVES

Background Most of the oil fields in Russia are at a late stage of development, characterized by a decrease in flow rates, selection rates of recoverable reserves, an uncontrolled increase in watering, and a low efficiency of waterflooding systems used. The prospects for engaging in the active development of the remaining hard-to-recover oil reserves of such fields, confined to areas (zones) and seams that are not covered by the impact of waterflooding, are closely connected with the improvement of the selection method and geological field substantiation of targeted technologies affecting the formation. Aims and Objectives Improving the methodology for the substantiation of the impact of the formation on the basis of the study of the geological structure of the layers, paleofacial analysis, geological and hydrodynamic modeling and analysis of the development of reserves. Results Conducted studies using the methods of mathematical statistics allowed to estimate the degree of influence of various geological and field factors on the effectiveness of geological and technical measures.

THE OIL DEMULSIFICATION MODE IN OIL FIELD TREATING OPTIMIZATION

Background In the late stages of the development of oil fields, the oil production process is accompanied by high water cut, which leads to such complications as the inorganic salt deposits on the internal walls of the pipelines, high corrosion damage to pipelines and equipment, and intensive formation of emulsions. These complications lead to an increased risk of accidents, environmental and commercial damage. Obtaining commercial dehydrated oil from emulsions is usually achieved by a thermochemical method, i.e. heating the emulsion to 40-60 °C and introducing special reagents - demulsifiers. Aims and Objectives More than 100 varieties of demulsifiers are presented on the Russian oil field market, each of which shows high efficiency under certain conditions. Optimal selection of the type of demulsifier and the mode of its application guarantees high quality of oil field treating. The aim of the article is to determine the optimal technological regime parameters - temperature, flow rate - when the fluid is dehydrated by chemical reagents. Methods The task was solved on the basis of the results of an experimental study of a 20 % oil emulsion. As a method of instrumental fluid study, a bottle test was used. The initial base of chemical reagents were 20 demulsifiers of Russian and foreign production. A method for choosing the optimal regime of dehydration of the extracted liquid on the basis of information on the preferences of the decision maker is proposed. Multiple pair comparison of criteria statistically approximates the resulting solution near the optimal one. Results The implementation of the decision-making optimization method based on the properties of demulsifiers is recommended to optimize the choice of the usage of the oil treatment reagent mode. It is shown that for oils of the West Siberian region of Russia, the usage of the demulsifier Intex 1018A at the temperature of 60 °C, dosing of 15 g / t, settling time of 30 min is optimal. At the same time, the relative allocation of water will amount to 94.1 %.

Laboratory investigation of asphaltene-induced formation damage

The purpose of this study is to evaluate the degree of formation damage caused by asphaltene deposition in the pore throats in case of oilfield operation. Many wells in the Samara region oilfields are operated under high reservoir drawdown, with downhole pressure lower than the bubble point. Such wells’ operating conditions lead to a change in oil composition (light components are extracted from oil while asphaltenes are precipitated and deposited) in the near wellbore, and the productivity of the wells declines due to asphaltene deposition. The study procedure presented in the paper included the following methods: high-pressure microscopy with grain size analysis (the visual method), the near infrared light scattering method and the gravimetric method to measure asphaltenes onset pressure in oil. Formation damage was measured by the filtration method. Asphaltene concentration in oil after filtration was measured by the photocolorimetric analysis. Microcomputed tomography of the core sample was provided to visualize formation damage. In addition, fluid flow in the pore space was simulated before and after asphaltene deposition using a dynamic simulator. In the paper, reservoir oil of one of the Russian oilfields was investigated. The main results of this paper are the following: asphaltene onset pressure in oil at the reservoir temperature (48 °C) was measured as equal to 6.8 MPa which is slightly higher than the bubble-point (6.5 MPa). Oil was flowed through the core sample of the field at three different specific backpressures (at constant flow rate) and formation damage was estimated. The studies have shown that decrease in permeability of the core is caused by asphaltene deposition in the pore space. In this case, a decrease in the amount of asphaltenes in oil emerging from the core sample is observed which was proved by the spectrophotometric analysis. Via microcomputed tomography, a 3D model of the rock matrix and the pore space of the initial and damaged core sample was constructed and a decrease in porosity after formation damage was estimated. Based on the obtained 3D model of the core, computer simulation of fluid flow (in a dynamic simulator) in the initial and damaged core was performed, and the flow parameters (velocity and streamlines) were calculated. The proposed methodology including a set of physical methods to study a core before and after formation damage combined with fluid flow simulation enables predicting potential complications under the field operation.

Potential of Russian Regions to Implement CO2-Enhanced Oil Recovery

The paper assesses the techno-economic potential of Russia to implement carbon capture and storage technologies that imply the capture of anthropogenic CO2 and its injection into geologic reservoirs for long-term storage. The focus is on CO2 enhanced oil recovery projects that seem to be the most economically promising option of carbon capture and storage. The novelty of the work lies in the formulation of a potential assessment method of CO2 enhanced oil recovery, which allows for establishing a connection between energy production and oil extraction from the viewpoint of CO2 supply and demand. Using linear optimization, the most promising combinations of CO2 sources and sinks are identified and an economic evaluation of these projects is carried out. Based on this information, regions of Russia are ranked according to their prospects in regards to CO2 capture and enhanced oil recovery storage. The results indicate that Russia has a significant potential to utilize its power plants as CO2 sources for enhanced oil recovery projects. It has been estimated that 71 coal-fired power plants, and 185 of the gas-fired power plants of Russia annually produce 297.1 and 309.6 Mt of CO2 that can cover 553.4 Mt of the demand of 322 Russian oil fields. At the same time, the total CO2 storage capacity of the Russian fields is estimated at 7382.6 Mt, however, due to geological and technical factors, only 22.6% can be used for CO2-EOR projects. Of the 183 potential projects identified in the regional analysis phase, 99 were found to be cost-effective, with an average unit cost of € 19.07 per ton of CO2 and a payback period of 8.71 years. The most promising of the estimated regions is characterized by a well-developed energy industry, relatively low transportation costs, numerous large and medium-sized oil fields at the final stages of development, and favorable geological conditions that minimize the cost of injection. Geographically, they are located in the North-Western, Volga, and Ural Federal districts.

The challenges of waxy oil production in a Russian oil field and laboratory investigations

The objective of this paper is selection the appropriate well operation conditions and effective wax inhibitor to reduce impact of wax in oil on production. The field operation is complicated with formation of wax deposits in flowlines and tubings due to high wax concentration in oil and improper wells operation. Expensive selection of effective wax inhibitor is regularly carried out in the field.The methodology of research used in this paper basically includes theoretical and experimental approaches. Theoretical approach is devoted to studying the thermodynamic functions of state of the system during wax crystallization in oil. This approach allows to explain behavior of wax in oil during crystallization. The authors of this paper calculated thermodynamic state functions of the system during wax precipitation in hydrocarbon solution and in reservoir oil to describe the process of wax crystallization and to explain change of apparent WAT with change of the well operation conditions and dosing of wax inhibitor. Calculations of thermodynamic state functions for model hydrocarbon solutions were carried out for pressure, ranging from 0.1 to 40 MPa, and for wax concentration in solution, ranging from 10 to 60%. Experimental approach was based on studying wax precipitation in reservoir oil by visual method using microscope under high pressure. The study was performed in the pressure range from 5.6 to 18.4 MPa, and wax concentration of 24%. Experimental data of wax precipitation in kerosene and in oil was processed using Vant Hoff's diagrams, Gibbs free energy equation during chemical reaction, and first and second laws of thermodynamic equations.The main result of this paper is examination of impact external factors on wax crystallization in oil, which will assist to select the well operation conditions in the presence of parafinization. Particularly, it was determined that with increase in pressure, apparent wax appearance temperature (WAT) is increasing, however, wax crystallization rate is declining. Additional research showed that apparent WAT is decreasing when oil cooling rate and depressurization rate are rising. Authors explain this phenomenon in reliance on thermodynamic parameters of wax crystallization in oil. Also wax inhibitor is developed for oil field conditions. Experiments demonstrated, that addition of inhibitor to oil leads to decrease in apparent WAT and does not accelerate wax crystallization, which will promote reduction of wax formation in oil wells.The proposed methodology has allowed to evaluate the most dangerous range of flowrates in terms of well parafinization and to propose measures for prevention of well parafinization in the field.

Направления развития рынка сопровождения бурения наклонно направленных скважин для российских нефтесервисных компаний

Направления развития рынка сопровождения бурения наклонно направленных скважин для российских нефтесервисных компаний

Effect of the Asphaltene, Resin, and Wax Contents on the Physicochemical Properties and Quality Parameters of Crude Oils

On the basis of published reference data on crude oils recovered from more than 300 Russian oilfields, the effect of the concentrations of paraffin waxes, resins, and asphaltenes on oil properties has been analyzed. There are correlations between the oil density, viscosity and the resin content, whereas the amount of asphaltenes (along with resins) has a greater effect on the oil quality characteristics, such as sulfur content, coke and petroleum diesel yields. Crystallizable paraffins do not have a significant effect on the properties of the oils, the pour point of which does not depend explicitly on the composition.

EOR Technologies: Physico-Chemical Aspects

<p>The application of self-regulating oil-displacing systems is considered to be a promising trend in the development of physico-chemical EOR methods. Technologies intended to increase conformance predominate. EOR technologies, where heat energy of the formation is used to generate alkaline buffer systems, CO<sub>2</sub> and gels increasing oil displacement and conformance, have wide potentialities. Such methods have been realized in the technologies developed at the Institute of Petroleum Chemistry SB RAS (IPC). Hydrolysis, hydrolytic polycondensation and coagulation in the system carbamide – aluminum salt – surfactant – water is the physico-chemical base for the technologies involving alkaline buffer systems, CO<sub>2</sub> and inorganic gels. To prepare thermoreversible polymer gels one uses change of phase from solution to gel in the system: cellulose ether with a lower critical dissolution point – water. Presented are the results obtained on the application of physico-chemical EOR methods and technologies developed at IPC in oil fields of Russia. The technologies proved to be economically effective and environmentally safe. The period of payback is 5-12 months.</p>

Permafrost thawing from different technical systems in Arctic regions

A new three-dimensional model of thermal interaction in a “heat source-and-soil” system is proposed to study the process of permafrost degradation from various engineering facilities operating in the Arctic regions, taking into account a number of physical and climatic factors that affect the heat distribution. On the base of the proposed model, a software complex was developed to predict long-term dynamics of permafrost thawing in the upper layer of soil, and this approach was used in the design of 11 northern Russian oil and gas fields and is in a good agreement with numerical rezults and experimental data. Numerical calculations are presented for illustration the possibility of carrying out long-term forecasts for the determination of permafrost zone defrosting during operation of production wells in northern oil and gas field.

Laboratory Investigation of Organic-Scale Prevention in a Russian Oil Field

Summary The objective of this research is a definition of wax-precipitation conditions in waxy oil (a kind of oil that intends to produce high-molecular-weight paraffins during production) at various thermobaric conditions taking place in oil wells, and also proposing a method for the determination of the potential wax-formation depth in a well. In most cases in Russia, many reservoirs are producing oil with high asphaltenes, resins, and wax content that causes the formation of organic deposits in downhole equipment. It reduces the workover period of wells and decreases their productivity. The oil-production system represents the sensitive hydrodynamic system, so any changes in well operational parameters, thermobaric conditions, and oil composition lead to wax and asphaltenes precipitation in oil. Natural surfactants (asphaltenes) stabilize water-in-oil emulsions and change rheological properties of the borehole flow. It demands additional energy consumption for raising reservoir fluid to the surface and for transporting it to gathering and oil-treatment systems. All laboratory experiments are conducted by use of conventional (standard) techniques. The grain-size-analysis microscopy was performed under high-pressure conditions. Also, a light-scattering method and viscometric analysis were performed, and functional wax-appearance temperature (WAT) vs. the pressure of live and degassed oil are carried out during experimental studies. The results of our experiments showed that, when the pressure drops below the bubblepoint pressure and the gas starts coming out from the oil, the WAT increases. A significant increase in the viscosity of a live-oil sample with a decrease in temperature and pressure in the range of downhole conditions that can become the reason of decline in the performance of an electrical submersible pump (ESP) is noted. The most technological methods directed on drop in the presented risks—among which are offered (1) the change of well-operation conditions allowing the regulation of the waxing of tubings and (2) the application of inhibitors that demonstrated high efficiency during the laboratory investigations—are mentioned. Mathematical analysis showed that the increase in well flow rate promotes a considerable decrease in potential wax-formation depth in an oil well. The proposed assessment technique of wax-precipitation depth that has been performed in this work can be useful for selecting the well-operation system. Among the studied inhibitors, the experiments showed that Inhibitor A has the highest efficiency in the slowing of the wax-formation process in the borehole conditions.

The Outsourcing-Based Model of Organizing the Russian Oil and Gas Industry

The article analyzes the risks and benefits of international outsourcing for the Russian oil and gas industry. It is shown that the dependence on non-Russia oil field servicers may lead to the technological obsolescence of the Russian oil and oil service industries and enable foreign operators to implicitly influence the efficiency of the Russian economy. It is shown that the dependence of Russian oil companies on foreign oil field service providers in 2014 affected not only individual companies, but the entire oil and gas industry. Given the importance of the oil and gas industry for Russia’s economy, this poses a high risk to Russia’s economy as a whole. Finally, the article offers several prescriptions concerning Russian oil field servicing as it operates under sectoral sanctions.

Sectoral entry-barriers for entrepreneurial activities – a Russian start-up between challenging global markets and local conservative path dependencies

Purpose Sectoral foresight activities often identify technological opportunities but leave the question open who will pursue them. Entrepreneurial activities have become increasingly important for the introduction and commercialization of new technological solutions. The same is true for Russia’s oil and gas industry, which requires a major technological upscaling to stay competitive. Promising start-ups, however, often face high barriers and fail to commercialize superior technological solutions. The purpose of this study is to show how industry-specific entry barriers can hamper start-up activities. Design/methodology/approach This paper discusses the experiences of a Russian oilfield service start-up in commercializing a self-developed technology for increasing the productivity of oil wells. Findings The start-up faced conservatism from corporate decision-makers, declining oil prices and suboptimal protection of intellectual property rights. The company overcame most barriers through moving into other markets outside of Russia, as closing a deal with customers in the USA and Canada went much faster than the extended business cycles of national oil companies. Originality/value This paper connects sectoral foresight activities to the real-life experience of a start-up. The findings suggest that entry barriers need to be addressed by the planning process to really pave the way for a greater impact of entrepreneurial activity.

THE FIRST OIL PRODUCTION OF RUSSIA (TO THE 270 ANNIVERSARY OF THE BASIS)

Although beginning of oil production our country is considered 1866 year, facts talk about other: the first oil fields of Russia appeared almost on 100 before. Foremost, the analysis of terms of beginning of regular booty of oil on territory of districts of Russia within bounds of middle of the XIX century shows that she began not earlier 1813 year, when to her were added Baku and Derbent khanates. However reports about sources, acted from the different corners of the state as early as XVI – XVIII centures. So, 1597 year from the district of the river Ukhta to Moscow first delivered combustible thick water that small amounts was collected from the surface of water. In 1721 year native Mezen town Grigory Cherepanov found on to Ukhta petroleum key, what by the decree of Peter 1 was recipient of an award by six roubles. However interest this opening did not cause. In 1738 year the Main artillery office the statement Shahanin about opening to them source of oil on Volga, below than Simbirsk. However decision about development of source of oil accepted it was not. In 1754 year attempt of creation of plant oil-spill the tatar petty officers of Urazmetovs under took from the surface of the river Juice. However the amount of the obtained oil appeared small. Finally illness of undermined an enterprise. In 1760 year request on a source being the Orenburg province, did the Ufa merchat Seneev and petty officer Yakshimbetov. They found out him near the river Inzer. Yetin 6 collection of oil being the Russian lakes in the Orenburg province near the White river Morgunov began. But most successes with the booty of oil man obtained on of that time territory of Russia, merchant F.S. Priadunov. In 1741 year on the instructions of Archangelic Province Office he visited Pustoozersky district for collecting tax. Here F.S. Priadunov knew that a local population from time immemorial had ladled her from pits and used domestic aims. After it he 1744 year about submitted the Archangelic Berg- college an application about permission to create a plant him the booty of oil on the Ukhta river. On 18 November, 1745 year by a Berg- college such permission it was given out him. Booty of oil of F. S. Priadunov began 1746 year.

Detailed Modelling of Hydrocarbonaceous Media Separation Process

This paper presents the results of a detailed study of the separation process in the range of characteristic values temperature (Т ≅ 0 ÷ 70 °C) and pressure (P ≅ 50 ÷ 700 kPa). The critical analysis of hydrocarbonaceous media separation process problem is made within functioning processing equipment on objects of the “Vyngapurovskoe” oil field in Russia. Modelling of first stage separation process is illustrated from data of reservoir fluid with detailed characteristic of evolution some components concentration into off-gas in dependence of temperature and pressure. Recommendations to the calculation of the component composition of hydrocarbonaceous fluids under the provisions of equilibrium thermodynamics using the model of Peng-Robinson are extradited. It has been established that the heavy hydrocarbons (С4+higher) concentration decreasing into off-gas theoretically could be achieved up to 48.41%.

Satellite observation of pollutant emissions from gas flaring activities near the Arctic

Gas flaring is a common practice in the oil industry that can have significant environmental impacts, but has until recently been largely overlooked in terms of relevance to climate change. We utilize data from various satellite sensors to examine pollutant emissions from oil exploitation activities in four areas near the Arctic. Despite the remoteness of these sparsely populated areas, tropospheric NO2 retrieved from the Ozone Monitoring Instrument (OMI) is substantial at ∼1 × 1015 molecules cm−2, suggesting sizeable emissions from these industrial activities. Statistically significant (at the 95% confidence level, corresponding uncertainties in parentheses) increasing trends of 0.017 (±0.01) × 1015 and 0.015 (±0.006) × 1015 molecules cm−2 year−1 over 2004–2015 were found for Bakken (USA) and Athabasca (Canada), two areas having recently experienced fast expansion in the oil industry. This rapid change has implications for emission inventories, which are updated less frequently. No significant trend was found for the North Sea (Europe), where oil production has been declining since the 1990s. For northern Russia, the trend was just under the 95% significance threshold at 0.0057 (±0.006) × 1015 molecules cm−2 year−1. This raises an interesting inconsistency as prior studies have suggested that, in contrast to the continued, albeit slow, expansion of Russian oil/gas production, gas flaring in Russia has decreased in recent years. However, only a fraction of oil fields in Russia were covered in our analysis. Satellite aerosol optical depth (AOD) data revealed similar tendencies, albeit at a weaker level of statistical significance, due to the longer lifetime of aerosols and contributions from other sources. This study demonstrates that synergetic use of data from multiple satellite sensors can provide valuable information on pollutant emission sources that is otherwise difficult to acquire.

PROSPECTS OF CCS PROJECTS IMPLEMENTATION IN RUSSIA: ENVIRONMENTAL PROTECTION AND ECONOMIC OPPORTUNITIES

The urgency of environmental protection is determined by its intensive change because of human impact, which, among other things, accompanied by an increasing of carbon dioxide (CO2) emissions. One of the ways to reduce the emission is Carbon Capture and Storage (CCS) technologies. To date, developed countries have successfully implemented a number of CCS demonstration projects. Their main purpose is to study the effectiveness of CO2 storage. Russia is one of the world’s largest producers of CO2 emissions. However, CO2 capture and storage issues are not studied by Russian enterprises due to the absence of environmental taxes. The experience of developed countries shows that CO2 storage projects, in addition to the reduction of anthropogenic impact, can be commercially effective not only by reducing the tax burden. This review presents the analysis of international experience in the field of CO2 capture and storage. Given the immaturity of technology and lack of the necessary volume of statistical data, it was an attempt to determine the minimum conditions, which permit the implementation of CCS projects in Russian oil fields. On the basis of the Russian development forecast and the fuel balance structure the volumes of CO2 emissions in the 2016–2030 years were calculated. According to significant difference in opinions about the feasibility of CCS implementation in Russia, this review presents the main arguments for and against such projects. Evaluation of the potential effectiveness of CCS projects to enhance oil recovery factor showed that in spite of the absence of CO2 emissions taxes, such projects could be commercially effective in Russia due to the increase in oil recovery.

STATE, CHALLENGES AND PROSPECTS OF DEVELOPMENT OF THE METHOD FOR SIMULTANEOUS-SEPARATE OPERATION OF WELLS USING ECP UNITS IN THE MULTIHORIZON FIELDS OF WEST SIBERIA

To create the operable equipment for simultaneous-separate operation of wells by electrical centrifugal pumping units (“SSO-ECP”) the experience gained by domestic and foreign specialists in this equipment designing, manufacturing and introduction was studied. It is offered to experimentally apply the assembly of SSO-ECP -A unit in wells being in operation for development of multihorizon fields with the purpose to increase these horizons oil recovery factor and current flow rates of wells. It is shown that for perspective development of SSO-ECP it is necessary to speed up the designing process and to arrange the commercial production of automated well systems of flow rate control and water encroachment of layers separated in the borehole, well chokes, and to prepare the industry «Methodical recommendations for designing the SSO technologies in multihorizon oil fields of Russia».

Development of ultrasonic equipment and technology for well stimulation and enhanced oil recovery

An ultrasonic well module and an ultrasonic technology for oil well stimulation and enhanced oil recovery are developed. The parameters of the ultrasonic radiating systems of downhole tools are calculated, and their optimization is performed. The conducted field tests of the ultrasonic well module as a part of an ultrasonic well complex in oil fields in Russia (Western Siberia and Samara Region) and the United States indicate a high efficiency of the developed equipment and technology. The developed ultrasonic equipment and technology can be offered to oil-producing companies as one of the promising methods for well stimulation and enhanced oil recovery. • Equipment and technology for ultrasonic well stimulation are developed. • Average increase in the production rate is 7.3 t/d in Russia and 4.45 t/d in the USA. • The percentage of successful treatments is up to 90%. • The duration of the effect after treatment is 4–24 months. • The advantages are simplicity, selective treatment, and low energy consumption.