Oilfield Practice Research Articles

A Novel Method to Calculate Water Influx Parameters and Geologic Reserves for Fractured-Vuggy Reservoirs with Bottom/Edge Water

In practical oilfield production, the phenomenon of water influx typically shortens the water-free recovery period of wells, leading to water flooding and causing a sharp decline in the production well yields, bringing great harm to production. Water invasion usually occurs as a result of the elastic expansion of the water as well as the compaction of the aquifer pore space. However, it can be due to the special characteristics of fractured-vuggy reservoirs such as non-homogeneity and the discrete distribution of the pore spaces. It is challenging to use traditional seepage flow theories to analyze the characteristics of water influx. Also, reservoir numerical simulation methods require numerous parameters which are difficult to obtain, which significantly reduces the accuracy of the results. In this study, considering the driving energy for water influx, a water influx characteristic model was obtained by fitting a graph plate. Subsequently, an iterative calculation method was used to simultaneously obtain water influx volume and OOIP. The aquifer to hydrocarbon ratio was determined by fitting the water influx curve with the graphic plate. Results show that the calculation method is sensitive to the values of reservoir pressure and the crude oil formation volume factor. After applying the method to one field case, it was discovered that water influx performance can be characterized into two types, i.e., linear water influx and logarithmic water influx. In the early stages, the water influx rate of logarithmic water influx is greater compared to linear water influx. However, the volume and energy of waterbody are limited, and the water invasion phenomenon occurs almost exclusively within a short period after the invasion. On the other hand, the volume of waterbody invaded by linear water influx is larger, and it can maintain a stable rate of water influx. The results of the study can provide theoretical support for the waterbody energy evaluation and dynamic analysis of water influx, as well as the control and management of water in these types of reservoirs.

APPLICATION OF HYDROGELS FOR WATER SHUTOFF TREATMENTS. Message No. 2

The article analyzes the use of hydrogels with nanoparticle additives for well water shutoff, as well as the development of a mathematical apparatus for hydrodynamic modeling of water shutoff operations. One of the most significant trends in the development of gel forming compounds for well water shutoff in the last 10 years has been the use of nanocomposites. The base polymers for nanocomposites used for water shutoff operations are either synthetic or biopolymer origin. The article highlights the novelty and prospects of using nanoparticles in sealing compositions. Various nanocomponent additives are used to increase the success of the use of hydrogel polymer systems in order to limit water inflow and expand the scope of their application in complicated reservoir conditions. These include carbon and mineral nanoparticles, which increase the stability and strength of crosslinked gels in formation conditions.In this paper, we consider the optimization of the repair and insulation operations design using gels for well water shutoff using mathematical modeling, which helps to justify the volume of hydrogel injection and calculate the necessary pressure gradients at which the sealing screen remains stable. The paramount importance of determining the source of well flooding is emphasized, depending on which the processing design is already being built, and appropriate materials are selected; trends in the development of repair and insulation operations at the present stage are traced. Based on the results of the implementation of the proposed model by numerical methods, the authors constructed diagrams of the stability of the waterproofing screen depending on the fracture width, screen size, gel injection rate and reservoir permeability. The technique proposed in the work allows to correctly select and optimize the technological parameters of the operation to maintain the stability of the screen in specific geological conditions.Mathematical modeling allows us to strictly justify the volume of injection of the gel screen, increase the technological and economic efficiency of the process, and in large fields — to rank wells according to the priority of processing. Oilfield practice in various regions of the country fully confirms the main conclusions made in this review article. Preliminary mathematical modeling and the introduction of microdispersions into gel formulations can significantly increase the efficiency of water shutoff operations. The next step in the development of water insulation technologies is the use of nanodispersions, which look very promising in laboratory modeling and are no longer exotic materials with unrealistic cost.

Three-Water Differential Parallel Conductivity Saturation Model of Low-Permeability Tight Oil and Gas Reservoirs

Addressing the poor performance of existing logging saturation models in low-permeability tight sandstone reservoirs and the challenges in determining model parameters, this study investigates the pore structure and fluid occurrence state of such reservoirs through petrophysical experiments and digital rock visualization simulations. The aim is to uncover new insights into fluid occurrence state and electrical conduction properties and subsequently develop a low-permeability tight sandstone reservoir saturation model with easily determinable parameters. This model is suitable for practical oilfield exploration and development applications with high evaluation accuracy. The research findings reveal that such reservoirs comprise three types of formation water: strongly bound water, weakly bound water, and free water. These types are found in non-connected micropores, poorly connected mesopores where fluid flow occurs when the pressure differential exceeds the critical value, and well-connected macropores. Furthermore, the three types of formation water demonstrate variations in their electrical conduction contributions. By inversely solving rock electrical experiment data, it was determined that for a single sample, the overall cementation index is the highest, followed by the cementation index of pore throats containing strongly bound water, and the lowest for the pore throats with free water. Building on the aforementioned insights, this study develops a parallel electrical pore cementation index term, ϕm′, to account for the differences among the three types of water and introduces a parallel electrical saturation model suitable for logging evaluation of low-permeability tight oil and gas reservoirs. This model demonstrated positive application effects in the logging evaluation of low-permeability tight gas reservoirs in a specific basin in the Chinese offshore area, thereby confirming the advantages of its application.

APPLICATION OF HYDROGELS FOR WATER SHUTOFF TREATMENTS. Message 1

Application of gels for well water shutoff has become a part of oilfield practice, and this direction is constantly evolving due to several objective reasons. The main reason is the growing water cut of well production, and repair and isolation operations using hydrogels occupy a worthy place in this segment of technological processes for limiting water inflow. The second reason for oilfield workers’ interest in hydrogels for water shutoff is related to the possibility of smooth regulation of their properties: they are injected with low viscosity, then mature in the required isolation interval, and their viscosity and structural-mechanical properties increase multiple times. The penetration ability of gelants (immature gels) into porous media far exceeds traditional cement slurries and synthetic curing resins. An important reason for the interest of scientists and engineers in the oil industry in hydrogels is the possibility of complexing technology: after injection they are reinforced by cement slurry or curing resins, which synergistically increases the effect of water isolation. Also, gel-forming compositions can be easily transformed into foam-gel compositions by simple manipulations, which increases their isolation efficiency. In terms of rheological characteristics, hydrogels, depending on whether they are based on organic or inorganic materials, have viscoelastic or viscoplastic properties. Organic-inorganic hybrid plugging materials combine both of these important properties, allowing hydrogels of different natures and structures to be used for targeted blocking of the source of water inflow.This article emphasizes the primary importance of determining the source of well watering, depending on which the treatment design is already built, and the appropriate materials are selected.

Polyacrylamide degradation in oil field wastewater by UV/H2O2 and UV/PDS: Rapid experimental measurement and model simulation

Ultraviolet-based advanced oxidation processes (UV-AOPs) are effective for degrading refractory pollutants in wastewaters. However, performing rapid efficiency evaluations represents a significant challenge for process selection and optimization in practical application. This study investigated polyacrylamide (PAM) degradation by UV/hydrogen peroxide (H2O2) and UV/potassium peroxydisulfate (PDS) in pure water and practical oil field wastewater. Based on a previously developed mini-fluidic photoreaction system that is easy to operate and requires low sample volumes, an experimental setup for rapid evaluation of UV-AOP efficiency was constructed that enabled on-line analyses of viscosity, UV absorbance, and pH via specially fabricated flow cell devices together with off-line analyses of PAM, chemical oxygen demand (COD), and acrylamide (AM). The PAM degradation rate constants (k′PAM) in practical oil field wastewater by UV/H2O2 and UV/PDS were 2.4 and 2.1 m2 einstein−1, respectively, which were much higher than those by sole UV process (0.8 m2 einstein−1). Combing with the analyses of viscosity, UV absorbance (220 nm), pH, COD, and AM concentration, the UV/H2O2 and UV/PDS demonstrated the effectiveness in PAM degradation in oil field wastewater. Additionally, the scavenging capacities of HO• and SO4•− of practical oil field wastewater were determined, and the k′PAM values were predicted by model simulation and verified experimentally. This study provides rapid evaluation methods for UV-AOP efficiencies, which is helpful for selecting and optimizing UV-AOPs for industrial wastewater treatments.

МҰНАЙ КӘСІПШІЛІК ЖАБДЫҚТАРЫНЫҢ СЕНІМДІЛІК СИПАТТАМАЛАРЫН БАҒАЛАУ ЖӘНЕ БЕЛГІСІЗДІК ЖАҒДАЙЫНДА ШЕШІМ ҚАБЫЛДАУ

Abstract. The article is devoted to the results of information analysis and the establishment of the relationship between factors affecting the reliability of oilfield equipment using a fuzzy clustering algorithm. One of the main tasks of oilfield practice is to assess the influence of various factors on the efficiency of field operation and make the right technological decisions. The reliability of estimates and decisions is determined by how reliably the input and output variables and their values are selected. Situations often arise when, given the same data, fundamentally different results are obtained. To find specific expressions of these dependencies and the parameters characterizing them, in particular, methods of statistical data processing are used. As a result of the analysis of the causes of failures of deep-well pumps, factors influencing the efficiency of the pump in the fields under consideration were identified and subjected to fuzzy cluster analysis, which allows us to gain an understanding of the influence of selected factors on efficiency indicators under conditions of uncertainty. A relationship was obtained between the input and output variables, which can be expressed by a fuzzy expression of the IF-THEN rule. Keywords: reliability, liquid flow rate, turnaround time, fuzzy set theory, fuzzy cluster analysis.

Factors of influence on the development of self-induced hydraulic fracturing cracks

The article is devoted to the regularities of the propagation of self-induced hydraulic fracturing cracks in the process of injection of the displacement agent into the formation in order to maintain reservoir pressure. Technogenic and petrological factors have a significant impact on the processes of initiation, propagation and degradation of self-induced hydraulic fracturing cracks. In modern oil and gas field practice, we are just beginning to use geomechanical simulators for private calculations and have not yet used them in integrated calculations of field development options, nevertheless, the influence of geomechanical processes of the spread of man-made cracks makes a significant contribution to the field development indicators. The aim of the study is a complex of factors that prevent and contribute to the development of self-induced hydraulic fracturing cracks. The study uses the author's methodology for estimating the crack length of a selfinduced hydraulic fracturing depending on the downhole pressure in the injection well. The results of the work have developed a classification of factors influencing the development of self-induced hydraulic fracturing cracks, a quantitative analysis of the differences in the characteristics of the spread of man-made cracks for two deposits with different geomechanical and hydrodynamic properties. The work makes a significant contribution to the understanding of the laws of the development of man-made cracks and has broad prospects for development, allowing us to significantly improve the current 3D digital models and analytical filtration models, which will improve the production of field reserves and increase the value of the oil recovery factor.

The role of the Absheron facies in the formation of the productive strata in the South Caspian Basin

In oilfield practice, the lithofacies criterion is very often decisive for the formation of deposits of liquid and gaseous hydrocarbons. The Absheron lithofacies type of sediments (Absheron facies), enriched in quartz material, composes the reservoirs of the horizons of all large oil and gas fields in the South Caspian Basin. The genesis of the Absheron facies is closely related to the genesis of the productive stratum, there is no consensus on both issues to date. It is indisputable that the productive stratum and the Absheron facies were formed in the conditions of a closed continental basin, which arose as a result of the orogenic restructuring of the areas surrounding the Caspian Sea, the bowing of its bottom and the subsequent Pontian regression of the sea. As a result of the restructuring of the hydrographic system in the south of the Russian Platform, many paleorivers, flowing along the newly formed land, began to flow and carry a huge amount of water and precipitation into the South Caspian Basin. Deposition of the productive stratum and Absheron facies began. The greatest role in the supply of quartz-enriched sandy material belonged to the Paleovolga, which, together with other paleorivers in the north of the South Caspian Basin, formed an extensive marginal delta, from which sediments were transported far to the south, west, and east.

Designing of a washing composition model to conduct the hot flushing wells producing paraffin crude oil

The article discusses the problems of asphaltene, resin and paraffin deposition and paraffin control methods in an oil production well. This is a critical issue in the oil and gas industry, especially in the oilfields of the Ural-Volga region (Russia). This work aimed at the development of a basic model of a detergent for hot flushing in oil wells. Traditionally in oilfield practice, well cleanouts are followed by discharge of used flush fluid into production fluid gathering and transportation system. This is a counterproductive and unsustainable practice involving costly chemical agents that retain all their useful properties after use. The authors have developed a water-based detergent model for hot flushing at a target facility. Its process efficiency was evaluated against the use of hydrocarbon solvents. Proposed is the developed solvent technology that will allow to increase its effective use and to reduce costs due to its re-use. The technology's novelty consists in the waste reduction during well cleanout and the increase of process efficiency of measures based on several flushing operations. The theoretical studies have highlighted the possibility of repeated use of the developed detergent, which will considerably reduce the subsoil users' costs.

Polystyrene nanofluids for enhanced oil recovery

We report the synthesis of nanosized polystyrene (PSt) microspheres with good uniformity, strong absorptivity, good shear resistance and controllable size. The PSt nanofluid, entitled with a high surface adsorption of nanoparticles, can effectively reduce interfacial tension without using surfactants and alter the wettability towards a more water-wet condition. Subsequently, their fluidic properties for chemical enhanced oil recovery of PSt nanofluidic microspheres were also investigated based upon core flooding experiments, sand-pack and NMR tests. It is found that remaining oil displacement can be realized by regulating the nanofluid behavior, including wettability and interfacial tension. Moreover, deep fluid diversion could be achieved through profile control by plugging pores. All these advantages made the PSt nanofluid to be favorable for oilfield practice.

Concurrent 18. Presentation for: Wireline packer remediation using novel bismuth technology

Presented on Wednesday 18 May: Session 18 Prior to the execution of this project, there were limited options for repairing a failed production packer. Conventional oilfield practice would default to a well workover to replace the failed component. In an offshore environment, this approach not only carries significant capital cost, but also material risk and health, safety and environment exposure associated with the large operational footprint and time requirement of the operation. An innovative solution was developed to remediate the failed packer without a workover while simultaneously significantly reducing cost and risk. A new packer was formed by melting a bismuth alloy plug into the annulus using wireline equipment, eliminating the requirement for a workover rig. Bismuth alloy pellets were deposited onto the packer via precisely drilled holes in the tubing before being melted into an annular plug, forming a gas-tight metal-to-metal seal. As this was an industry first, prototype testing of the annular bismuth plug was undertaken to demonstrate concept feasibility. After a series of iterative testing a viable concept was achieved, and the prototype was taken forward to qualification. The annular plug was qualified to industry standard ISO 14310 V0 for the well’s operating conditions which included both pressure differential and axial loads. After the bismuth annular plug was qualified, the deployment method for the bismuth pellets was optimised to ensure they reached targeted location without compromising well integrity. After 2 years of design, the industry-first wireline intervention was successfully executed in 2021 and the well was returned to production. To access the presentation click the link on the right. To read the full paper click here

Wireline packer remediation using novel bismuth technology

Prior to the execution of this project, there were limited options for repairing a failed production packer. Conventional oilfield practice would default to a well workover to replace the failed component. In an offshore environment, this approach not only carries significant capital cost, but also material risk and health, safety and environment exposure associated with the large operational footprint and time requirement of the operation. An innovative solution was developed to remediate the failed packer without a workover while simultaneously significantly reducing cost and risk. A new packer was formed by melting a bismuth alloy plug into the annulus using wireline equipment, eliminating the requirement for a workover rig. Bismuth alloy pellets were deposited onto the packer via precisely drilled holes in the tubing before being melted into an annular plug, forming a gas-tight metal-to-metal seal. As this was an industry first, prototype testing of the annular bismuth plug was undertaken to demonstrate concept feasibility. After a series of iterative testing a viable concept was achieved, and the prototype was taken forward to qualification. The annular plug was qualified to industry standard ISO 14310 V0 for the well’s operating conditions which included both pressure differential and axial loads. After the bismuth annular plug was qualified, the deployment method for the bismuth pellets was optimised to ensure they reached targeted location without compromising well integrity. After 2 years of design, the industry-first wireline intervention was successfully executed in 2021 and the well was returned to production.

Production calculation of the second and tertiary recovery combination reservoirs under chemical flooding

Based on the analysis of the production composition of reservoirs developed by the second & tertiary recovery combination (STRC), the relationship between the overall output of the STRC project and the production level during the blank water flooding stage is proposed. According to the basic principle of reservoir engineering that the “recovery factor is equal to sweeping coefficient multiplied by oil displacement efficiency”, the formula for calculating the ultimate oil recovery factor of chemical combination flooding reservoir was established. By dividing the reservoir into a series of grids according to differential calculus thinking, the relationship between the ultimate recovery factor of a certain number of grids and the recovery degree of the reservoir was established, and then the variation law of oil production rate of the STRC reservoir was obtained. The concept of “oil rate enlargement factor of chemical combination flooding” was defined, and a production calculation method of reservoir developed by STRC was put forward based on practical oilfield development experience. The study shows that the oil production enhancing effect of STRC increases evenly with the increase of the ratio of STRC displacement efficiency to water displacement efficiency, and increases rapidly with the increase of the ratio of recovery degree at flooding mode conversion to the water displacement efficiency. STRC is more effective in increasing oil production of reservoir with high recovery degree. Through practical tests of the alkali free binary flooding (polymer/surfactant) projects, the relative error of the oil production calculation method of STRC reservoir is about ±10%, which meets the requirements of reservoir engineering.

RESULTS OF THE APPLICATION OF NEW TECHNOLOGIES IN INCREASING RESOURCES IN HIGH PRESSURE DRILLS

In oilfield practice, as well as in the transportation of oil and gas, great importance is attached to the use of high-pressure valves. Since the demand for this fleet of equipment is growing, it is especially important to increase their resources and reduce their cost on this basis. Along with the constructive and technical measures taken in this direction, serious attention should be paid to improving the choice of materials for the manufacture of parts and their production technology.. The article is devoted to the discussion of the results obtained when using the coquille technology for the manufacture of parts made of low-alloy chromium-molybdenum steel Keywords: high-pressure gate valve, body, gate, seat, hardness, wear.

SUBSTANCE CONCENTRATION IS AN INFORMATION INDICATOR OF TECHNOLOGICAL PROCESSES IN OIL PRODUCTION

Background The parameter «substance concentration» is used in all areas of science, technology and life, characterizes, to one degree or another, practically all processes known to us. In the article, this parameter is considered from several angles. Based on the definition of the term, examples of technological processes are considered in which the concentration of either a single-component substance or a single-phase one (the concentration of the first type) changes. The processes occurring in reservoir conditions, during movement and separation in wells, pipelines and storage equipment, are usually described using the concentration of a substance of the second type, when the quantitative presence of one component is estimated relative to all constituents of the substance. An objective relationship between the concentration of substances of both types and such characteristics of fluids as pressure, temperature, speed of movement is shown using well-known examples of the theory and practice of oil production. Aims and Objectives: o to conduct a typology of the term «substance concentration» based on a comparative analysis of methods and technologies used to assess the characteristics of oil production processes; o to prove the change in the substance concentration in reference technologies by assessing the internal state of lift pipes of wells and production pipelines, which is recorded by known measuring instruments. Methods The concentration of a substance is estimated by the density, pressure, temperature and speed of movement of fluids in the studied area of the oil production object. The volume of deposits in oilfield equipment is determined by the volumetric method after fixing the amount of reference fluid in the studied cavity. Results It is proposed in oilfield practice to conditionally distinguish two types of substance concentration, which differ in the method of determination in field conditions. Examples of reference technologies based on changes in the concentration of a substance of the first type are given.

Fault Recognition of Indicator Diagrams Based on the Dynamic Time Warping Distance of Differential Curves

Oil recovery with pumping units is widely used in oilfield development at present. The management level of pumping units is related to the overall economic benefit of oilfield. In order to effectively control the production management of pumping wells, it is necessary to take all the production data to formulate a reasonable working system and make continuous analyses about the daily management level of pumping wells. The analysis and interpretation of the indicator diagram is a direct understanding way about the situation of deep well pumps in petroleum engineering. However, the complicated practical oilfield conditions often lead to the distortion of regular indicator diagrams, resulting in the low efficiency of fault-type diagnosis and wrong recognition. A new method of identifying the fault type of indicator diagrams is proposed by using the dynamic time warping (DTW) distance, through which a two-dimensional indicator diagram is transformed into a one-dimensional differential curve. The experimental results of real indicator diagrams show that the method is effective for the type diagnosis of indicator diagrams with high accuracy and fast speed.

Гидрогеохимические критерии поиска и разработки углеводородных месторождений: обзор, анализ и перспективы использования на острове Сахалин

The paper discusses the directions of hydrogeochemical researches used to solve actual problems of the oil and gas industry: assessment of the oil and gas potential of territories, localization of oil and gas trap, prediction of the phase composition of hydrocarbon fields, control the development process of hydrocarbon fields, etc. Based on the literature data, the analysis and systematization of the main hydrogeochemical indicators of groundwater with oil and gas prospecting significance, as well as used already at the stage of development of oil and gas fields, have been carried out. The most efficiency of the application of hydrogeochemical researches in oilfield practice is achieved with the integrated use of various indicators. On the example of researches of the oil and gas potential of Sakhalin Island, it is shown that the hydrogeochemical data of the middle of the 20th century, obtained by outdated chemical analytical methods, cannot always be considered reliable. In this regard, additional researches are required to update the relevant hydrogeochemical data in this region.

Synergistic inhibitory effects of free nitrous acid and imidazoline derivative on metal corrosion in a simulated water injection system

To maintain the integrity of the internal surfaces of the pipelines in oil and gas industry, chemicals, including corrosion inhibitors and biocides, are commonly dosed to prevent corrosion. Imidazoline and its derivatives are widely used corrosion inhibitors for the protection of oil pipelines, which have been shown effective in reducing general corrosion. As an effective biocide, free nitrous acid (FNA) is suitable to inhibit microbially influenced corrosion, induced by for example sulfate-reducing bacteria. In this paper, we hypothesize that the continuous addition of imidazoline and intermittent dosing of FNA, when used in combination, would yield effective control of both general and pitting corrosions. As a typical imidazoline derivative, N-b-hydroxyethyl oleyl imidazoline (HEI-17) was applied in conjunction with intermittent dosing of FNA in the experimental system, with the results compared with two control systems, one receiving HEI-17 only, and one receiving no chemical dosing. The corrosion properties were monitored with open circuit potential, electrochemical impedance spectroscopy, linear polarization resistance, 3D optical profiling, and weight-loss measurement. Following a single dose of FNA, the general corrosion rates in the experimental reactor dropped up to 50% of that in the reactor receiving continuous HEI-17 dosing (0.27 ± 0.04 vs. 0.54 ± 0.08 mm/y), but gradually recovered to 93.4% of that in 2.5 months. After the FNA treatment, the pitting corrosion was decreased by 64.6% compared with continuous HEI-17 dosing reactor for a month from measuring the cumulative distribution of the pitting depth. HEI-17 treatment alone showed moderate pitting corrosion inhibition effect (approx. 27%), and the FNA treatment inhibited the formation of deep pits effectively. The combined application of HEI-17 and FNA has shown synergistic effects and high efficiency in mitigating MIC in the simulated water injection system. This treatment strategy has strong potential to be applied in the practical oilfield operations.

Ethanol enhanced anionic surfactant solubility in CO2 and CO2 foam stability: MD simulation and experimental investigations

CO2 foam has been widely scrutinized as a potential candidate in enhanced oil recovery while reducing CO2 emissions through geo-sequestration due to the high-efficiency CO2 mobility control ability. However, its application has been retarded partially because of the limited solubility of commercial and environmentally friendly surfactants in supercritical CO2. In this work, the challenge of limited solubility of surfactant sodium bis(2-ethylhexyl) sulfosuccinate (AOT) in CO2 is overcome by using ethanol as a co-solvent. The presented MD simulation reveals the underlying mechanism of the ethanol increased solubility of AOT in CO2 and the subsequently water-CO2 interfacial properties favorable for a stable CO2 foam. Experimental observation is in good accordance with the MD simulation that foamability and foam stability both significantly increase with ethanol as co-solvent, and their dependence on ethanol content. With ethanol as co-solvent to assist the dissolution of AOT in CO2, the CO2 foam has a high stiffness and the foam film has a high dilational modulus under high pressure of 15 MPa, which explain the stable CO2 foam. Experiments also show that ethanol helps the foam regeneration, making the practical oil field application of the presented system even more promising.

Electrophysical Apparatus for Intensifying the Production of High-Viscosity Oils

The production of heavy high-viscosity oils is associated with the formation of asphalt-resin-paraffin deposits in the pipelines of the wells, which leads to a rapid decrease in their flow rate. Currently, a variety of mechanical, chemical, thermal and combined sediment removal tools are used in oilfield practice. Nevertheless, there remains a request for the search for new technological solutions that would allow environmentally sound removal of deposits without interruptions in the process of oil production with minimal energy and labor. This article reports on the first results of developing a new technology for removing deposits from well pipes, which is based on their non-contact local induction heating. At the contact point of the deposits with the heated section of the pipe, their partial melting occurs, as a result of which the bulk of the deposits in the form of large fragments is removed together with the oil flow. The inductor moves slowly along the axis of the well, receiving a high-frequency current from a nearby immersed energy converter.