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During waterflooding of a multilayer oil field there is a constant deterioration of the structure and composition of residual reserves due to geological and technological reasons. The largest share of residual reserves is localized in pillars, which arise from uneven development of the production facility and are undrained or poorly drained zones. The results of a quantitative assessment of the distribution of residual oil reserves in the Middle and Upper Devonian deposits of the Romashkinskoe oil field of the Republic of Tatarstan are presented. A retrospective method is proposed to identify reserves by analyzing and summarizing historical exploration data and the long history of reservoir development, and a calculation algorithm is proposed to quantify them. It has been established that residual oil reserves are localized in rows of dividing and injection wells, as well as in the central rows of producing wells in a three-line drive, in abandoned and piezometric wells, in the areas adjacent to the zones of reservoir confluence, pinch-out, oil-bearing contours, distribution of reservoirs with deteriorated porosity and permeability properties. Depending on geological conditions, algorithms for selecting geological and technical measures to include localized reserves in development and forecasting production profiles were proposed. According to the proposed method, residual recoverable reserves were identified and a number of wells were recommended for experimental works on their additional recovery: in well 16 (hereinafter in the text, conventional well numbers are used) after isolation of overlying high-water-cut formations, the additional perforation was carried out and oil flow was obtained. Additional perforation in well 6 resulted in oil recovery during development as well. Thus, the developed approaches to identifying residual recoverable reserves and patterns of their spatial distribution can be recommended in other multilayer oil fields with a long history of development.

Petrographic and petrophysical characterizations of the pre-salt Chela formation of the Nsiamfumu and Liawenda fields in the onshore Coastal Basin of the D.R. Congo it was performed. These characterizations, as part of the static modelling of the reservoirs, involved reading log measurements, thin-slice observations of rock samples taken from this formation, calculations and interpretation of logs, CPI (Computer Processed Interpretation) and DST (Drill Stem Testing) from well tests. The following observations were obtained: • Wells Lw-1: the formation is characterized by dolomitic limestone and micaceous black shale with a thickness of 34 m having heavy oil indices and an average porosity of 17% and a salinity greater than 300 gr/L; • Well Lw-2: the formation is characterized by islands of sand, coarse sandstone and a few quartz pebbles with a thickness of 10m showing evidence of light oil, gas and an average porosity of 24%; • Shaft Lw-3: the formation is dominated by micaceous shale and dolomite interbeds with a thickness of 14m showing little evidence of hydrocarbons, only salt water and residual oils; • Puits Ns-1: the formation is characterized by beige to grey dolomite, grey shale and white sand with a thickness of 6m showing evidence of light oil and an average porosity of 20%. [ABSTRACT FROM AUTHOR]

Copyright of Journal of Petroleum Research & Studies is the property of Republic of Iraq Ministry of Higher Education & Scientific Research (MOHESR) and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

The article describes a numerical-analytical model for gas breakthrough to a well during the development of oil fields with a gas cap using horizontal wells. The employed semi-analytical model allows describing the process of gas cone development and reproducing oil and gas production parameters from the well by matching to the actual production history using several coefficients. The numerical scheme of the model was implemented as a computational library in the Python 3.6 programming language.The algorithm was tested on oil deposits with a gas cap in the South Yamal oil and gas region and showed good results in history matching and forecasting calculations. The average calculation time of one iteration being less than 10 seconds allows for multiple model run scenarios using optimization algorithms for automatic calibration to actual production data. The results of the testing show the possibility of achieving satisfactory convergence using automated calibration to the production history. The developed algorithm reduces the workload of specialists in forecasting production, thereby enhancing the effectiveness of decisions made for development optimization.

At the late stage of field development, residual oil reserves undergo a significant change from mobile to sedentary and stationary. These reserves are mainly located in technogenically and production altered, watered layers and areas of deposits.Localization and development of such sources of hydrocarbons is an effective method of increasing the final oil recovery factor in mature fields, due to the presence of a readymade developed infrastructure for production, transportation and refining, as well as the availability of highly qualified personnel.This article considers an approach that allows, based on neural network algorithms, the estimation the volumes and localization of residual oil reserves in multi-layer deposits in combination with the analysis of geochemical studies of reservoir fluids. The use of machine learning algorithms allows a targeted approach to the development of residual reserves by automated selection of wellwork. This approach significantly reduces the manual labor of specialists for data processing and decision-making time.

Arranged the hydrocarbons in an oil reservoir require several techniques for their exploitation. The Liawenda field, discovered in December 1971 following the drilling of the Liawenda-01 exploration well, has a total of 186 wells with an annual production of 3,009,553 barrels. Having started production several years ago, the field has used the water injection technique following a drop in pressure. Despite this recourse to water injection methods, production from the Liawenda field is not always satisfactory. Knowledge of fluid flow inside an oil reservoir is important because it enables us to estimate certain useful parameters that can determine fluid movements in order to identify the causes of excessive water production. Thus, the present paper deals with water injection data in order to understand fluid movements in the Turonian reservoir of the Liawenda Field: - What is the fluid movement like in the Turonian reservoir of the Liawenda Field? - How does water move in relation to oil? - What are the efficiencies of fluid movement within the Liawenda Field? - What is the speed and travel time of the fluids in this reservoir? - How mobile are fluids?

This study aims to investigate the occurrence of surface displacements in the Canto do Amaro (CAM) onshore oil field, situated in Rio Grande do Norte, Brazil, using Sentinel-1 data. The persistent scatterer interferometry (PSI) technique was used to perform the analysis based on 42 Sentinel-1 images, acquired from 23 July 2020 to 21 December 2021. Moreover, information regarding the structural geology of the study area was collected by referencing existing literature datasets. Additionally, a study of the water, gas, and oil production dynamics in the research site was conducted, employing statistical analysis of publicly available well production data. The PSI points results were geospatially correlated with the closest oil well production data and the structural geology information. The PSI results indicate displacement rates from −20.93 mm/year up to 14.63 mm/year in the CAM region. However, approximately 90% of the deformation remained in the range of −5.50 mm/year to 4.95 mm/year, indicating low levels of ground displacement in the designated research area. No geospatial correlation was found between the oil production data and the zones of maximum deformation. In turn, ground displacement demonstrates geospatial correlation with geological structures such as strike-slip and rift faults, suggesting a tectonic movement processes. The PSI results provided a comprehensive overview of ground displacement in the Canto do Amaro field, with millimeter-level accuracy and highlighting its potential as a complementary tool to field investigations. [ABSTRACT FROM AUTHOR]

Foam has been widely used in drilling, well washing, and oil driving during the development of oil and gas fields. Although air foams have been successfully employed as an enhanced oil medium, the oxygen they contain can seriously corrode piping systems, which can have a negative influence on output. This work used a combination of sodium dodecyl sulfate (SDS), dodecyl aminopropyl betaine (LAB), sodium dodecylbenzene sulfonate (SDBS), and cosurfactants to solve the problem above. The corrosion inhibitor hydrazine hydrate (N₂H₄·H₂O) was added as corrosion inhibitor. The foaming (air)-corrosion inhibitor all-in-one (SLN) was obtained with the formulation of SDS: LAB: N₂H₄·H₂O = 8:2:4. The foam volume of 0.7 % SLN was measured to be 515 mL at room temperature with a half-life of 4.1 min using the stirring method. The initial foam height of this all-in-one agent was measured to be 15.6 cm at 30 °C using the Roche foaming method. The foam height was still maintained at 15.5 cm after 20 min with a foam height retention of 99.2 %. The foam height retention rate was 50.0 % at 70 °C. Moreover, the formulation had good salt resistance to common inorganic salts in oilfield water. It should be emphasized that the SLN all-in-one agent has strong corrosion inhibition performance, and the corrosion inhibition rate can reach up to 96.9 %. The surface tension of this SLN all-in-one agent was reduced to 27.8 mN m−1 at a concentration of 0.1 %. It indicated that the all-in-one agent might increase the stability of the foam by decreasing the surface tension, thus improving the persistence of the foam and the effect of the repelling oil. [ABSTRACT FROM AUTHOR]

It is necessary to improve oil production from reservoirs. Various methods have been proposed to increase oil extraction from reservoir. Each method has specific challenges. In this research, the effect of water and gas injection in to Azadegan reservoir has been analyzed. Azadegan oil field is located south of Iran. In this study, water, immiscible gas and water alternating gas injected to reservoir and its effect on enhanced oil recovery have been investigated. Finally, a comparison between results of methods is provided. Results show that effective method for enhanced oil recovery is immiscible gas injection with 46% oil production efficiency and water alternating gas injection with 36% oil production efficiency. This study shows that oil production efficiency can be increased if duration of gas injection is increased. This study shows, increasing viscosity of water in water alternating gas scenario did not improve the production of Azadegan reservoir. [ABSTRACT FROM AUTHOR]

Copyright of Mesopotamian Journal of Marine Science is the property of Republic of Iraq Ministry of Higher Education & Scientific Research (MOHESR) and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Journal of Chongqing University of Technology (Natural Science) is the property of Chongqing University of Technology and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

The level of snow cover pollution by potentially toxic metals and metalloids is estimated for the area of the Vatinskoe oil field (Khanty-Mansiysk Autonomous Okrug–Yugra). Studies of the filtrate of melted snow and solid-phase precipitation (particles larger than 0.45 µm) showed an increase in Ni and Cr concentrations, suspended fraction, as well as Zn due to the traffic load. The level of pollution increases in areas with a higher concentration of industrial objects. [ABSTRACT FROM AUTHOR]

Copyright of Journal of Petroleum Research & Studies is the property of Republic of Iraq Ministry of Higher Education & Scientific Research (MOHESR) and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

The evaluation of the corrosion wear rate was carried out using the Norsok Standart M-506 method for oilfield production tubing in Belarus. The method is based on a model that takes into account the speed of the gas-liquid flow, its pH, the volumetric flow rate of water, oil, gas, pressure, temperature, immersion depth, pH, density and viscosity of these media, and diameter and wall thickness of tubing. A feature of the model is the consideration of the friction of the gas-liquid flow on the walls of the tubing and the resulting shear stresses near them, which allows taking into account the corrosion-mechanical component of the metal degradation process of the tubing. The characteristics of well media and operating conditions of equipment in fields are given. Empirical coefficients of the considered model for typical conditions of Belarusian oil fields have been determined and a predictive calculation of the corrosion rate of 32Mn1A tube steel strength group N80 (Q) of the API Specification 5CT has been carried out. Data on actual values of corrosion wear of tubing from more than 100 production wells have been collected. The results indicate a high convergence of calculated and actual data. The adapted Norsok Standart M-506 method of predicting corrosion wear is recommended for use at oil fields in Belarus. It is shown how the proposed approach can be extended to other oil-bearing regions. [ABSTRACT FROM AUTHOR]

Carbon capture utilization and storage for enhanced oil recovery (CCUS-EOR) is considered a promising solution to meet future global energy needs while significantly reducing carbon dioxide emissions. However, the future growth of CCUS-EOR is uncertain due to the global economic recession and low oil prices. This research analyzes the impact of uncertain oil and carbon market prices on the economic value of a CCUS-EOR project which contributes to appropriate investment and future policy decisions. To explore the potential trade-offs between available carbon dioxide (CO2) quantities for trading or injection for enhanced oil recovery, the market's trading mechanism is analyzed by predicting future oil and carbon prices. The forecasted market prices are then used in an optimization model to estimate the optimal cumulative cash flow from implementing a proposed CCUS-EOR project to capture CO2 from the Hartha power plant located in the southern Basra Province of Iraq, considering three different oil fields of Rumaila, Nassriya, and Noor. The results revealed that the profitability of the proposed CCUS-EOR project is affected by both oil and carbon market prices, and a higher carbon price is needed to compensate for the financial setbacks, resulting from reduced oil prices. The research also features the strategic decision-making of oil fields across different sizes in response to various price scenarios. The medium-sized fields consistently prioritize carbon injection for enhanced oil recovery (EOR) over market trading. In contrast, small and giant fields adapt their approach based on the prevailing market price dynamics.

Nowadays, due to the limitation of fossil fuels, the topic of their optimal use has been given more attention than before. In the upstream literature of oil and gas economy, the word synonymous with this topic is reservoir management. In this study, selected one of the oil fields of Iranian Offshore Oil Company (IOOC). In the first step, by using field data, the cost function of the field is estimated by considering the environmental costs and secondary recycling costs, and in the next Nowadays, due to the limitation of fossil fuels, the topic of their optimal use has been given more attention than before. In the upstream literature of the oil and gas economy, the word synonymous with this topic is reservoir management. This study selected one of the oil fields of the Iranian Offshore Oil Company (IOOC). In the first step, by using field data, the cost function of the field is estimated by considering the environmental costs and secondary recycling costs, and in the next step, the discounted profit of the field during its life under three discount rate scenarios, and it is maximized by dynamic programming method. The results of the bell curve study confirmed the production during the life of the field. Also, in the scenario of the discount rate of 5%, the harvest results from the field have been more balanced, and with the increase of the discount rate to 10 and then 20%, more harvest has been achieved in the first years of production and less harvest in the final years of productionstep, the discounted profit of the field during its life under three discount rate scenarios. and it is maximized by dynamic programming method. The results of the bell curve study confirmed the production during the life of the field. Also, in the scenario of discount rate of 5%, the harvest results from the field have been more balanced, and with the increase of the discount rate to 10 and then 20%, more harvest has been achieved in the first years of production and less harvest in the final years of production.

Abstract Heavy metal pollution caused by oil well drilling operations is one of the environmental problems that the oil industry imposes on the environment. The source of such pollution should first be determined precisely to manage and control it. Studies show that the main source of environmental pollution in well drilling operations is the drilling fluid additives or the elements in the well column formations. In this research, in addition to measuring the concentration of heavy metals and comparing it with the existing standards, an attempt is made to determine the exact origin of these metals. To study the source of such pollution in the area of the Abteymour oil field in the southwest of Iran, 19 cuttings (from 8 formations), 10 waste samples (drilling mud and cutting), and 7 drilling muds and their additive samples from one of the wells were assessed to determine the concentration of heavy metals. In this study, a total of 56 elements were measured using the ICP-MS analysis method; however, 16 elements that had a higher concentration than the average of the upper crust (as a reference concentration) with Ni, Cr, and V elements were studied. These 16 elements included Fe, Ag, As, Ba, Bi, Cd, Cu, Mg, Mn, Mo, Pb, Sb, Sr, and W heavy metals, and Ca and S elements. The analysis of the examined elements' concentrations in muds and their additives revealed that samples of heavy water-based muds and barite contained the highest concentrations of the elements. The cuttings samples primarily had a higher concentration than the waste samples, which was due to the mixing of the cuttings of different depths in the waste and the dilution of the element concentration in the waste samples, according to an analysis of the variation of 19 elements compared to the depth. Among the studied formations, the Gachsaran Evaporite Formation has high concentrations of studied elements. This problem is due to the complexity of the lithology of Gachsaran Formation, which consists of all kinds of rocks such as anhydrite, gypsum, salt and marl. This result shows the importance of managing drilling operations in this formation to prevent the release of heavy metals in the environment. Based on the Igeo, Ca, Ag, As, Ba, Bi, Cd, Cu, S, Sb, and Sr elements had high levels of pollution in all samples of waste and drilling cuttings. Based on the EF, only Cr, Mn, and V elements had no enrichment, and other elements had different enrichment levels in waste and drilling cuttings samples. The main result of this study shows that the main source of heavy metal pollution in the first stage is the type of elements in the lithology of the well column formations and in the next stage is the type and additives of the drilling fluid used in the well. Specifically, in the Abteymour oil field, the main reason for the contamination of the Gachsaran formation is due to the complexity of the lithology and the use of heavy water base drilling mud. The results of this research show that before choosing the type of drilling fluid, it is necessary to do a detailed environmental study and identify heavy elements in subsurface formations and the designed drilling fluid.

Abstract It is necessary to improve oil production from reservoirs. Various methods have been proposed to increase oil extraction from reservoir. Each method has specific challenges. In this research, the effect of water and gas injection in to Azadegan reservoir has been analyzed. Azadegan oil field is located south of Iran. In this study, water, immiscible gas and water alternating gas injected to reservoir and its effect on enhanced oil recovery have been investigated. Finally, a comparison between results of methods is provided. Results show that effective method for enhanced oil recovery is immiscible gas injection with 46% oil production efficiency and water alternating gas injection with 36% oil production efficiency. This study shows that oil production efficiency can be increased if duration of gas injection is increased. This study shows, increasing viscosity of water in water alternating gas scenario did not improve the production of Azadegan reservoir.

The territory of the Republic of Kalmykia includes three soil zones, completely different in their physicochemical, chemical and biological properties. In the present work, an attempt was made to carry out a comparative analysis of the chemical and biological properties of soils in Kalmykia. Zonal soils of the Republic of Kalmykia were chosen as objects of study. Laboratory and analytical studies, as well as sampling, were carried out using methods generally accepted in biology and soil science. During the laboratory experiment, it was found that the most favorable conditions for the growth and development of radishes were found on the southern chernozem, followed by light chestnut and brown semi-desert soil. On the soils of the oil field, the growth of radish is significantly inhibited, on the contrary, on the soils of the reserve it is stimulated. As a result of the research, it was found that the soils of Kalmykia, according to the activity of soil enzymes, form the following series of southern chernozem > light chestnut > brown semi-desert. According to the availability of macroelements, the soils of Kalmykia form a similar series. The biological properties of southern chernozem, light chestnut and brown semidesert soils differ significantly, which is probably due to the availability of biophilic elements available to plants and their granulometric composition, and anthropogenic or recreational impacts also affect biological properties.

Copyright of Journal of The Planner & Development is the property of Republic of Iraq Ministry of Higher Education & Scientific Research (MOHESR) and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

This study aims to investigate the occurrence of surface displacements in the Canto do Amaro (CAM) onshore oil field, situated in Rio Grande do Norte, Brazil, using Sentinel-1 data. The persistent scatterer interferometry (PSI) technique was used to perform the analysis based on 42 Sentinel-1 images, acquired from 23 July 2020 to 21 December 2021. Moreover, information regarding the structural geology of the study area was collected by referencing existing literature datasets. Additionally, a study of the water, gas, and oil production dynamics in the research site was conducted, employing statistical analysis of publicly available well production data. The PSI points results were geospatially correlated with the closest oil well production data and the structural geology information. The PSI results indicate displacement rates from −20.93 mm/year up to 14.63 mm/year in the CAM region. However, approximately 90% of the deformation remained in the range of −5.50 mm/year to 4.95 mm/year, indicating low levels of ground displacement in the designated research area. No geospatial correlation was found between the oil production data and the zones of maximum deformation. In turn, ground displacement demonstrates geospatial correlation with geological structures such as strike-slip and rift faults, suggesting a tectonic movement processes. The PSI results provided a comprehensive overview of ground displacement in the Canto do Amaro field, with millimeter-level accuracy and highlighting its potential as a complementary tool to field investigations.

Oilfield chemicals prepared with natural products is an effective way of green oilfield chemistry development. The konjac gum is used as the flocculant for waste drilling fluid, and it is used as a multifunctional oil field additive. By the single factor experiments, the optimal flocculation conditions were screened out. The conditions are as follows: the adding amount is 0.10%, flocculation temperature is at 40°C, pH 7, stirring rate is 200 rpm and stirring is for 5 min. the flocculation efficiency can be significantly improved using composite flocculant with konjac gel and orange peel, and get puff and large flocs. The flocculation efficiency is the best under the mass ratio of 1:5 between konjac gum and orange peel. The flocculation efficiency of the compound flocculant is between polyacrylamide and polyaluminum chloride, but it has obvious an advantage in filtration loss. Experimental results show that the "adsorption bridging" and "charge neutralization" mechanisms in the composite flocculant may coexist and reinforce each other. This research will be beneficial for improving the environmental performance of flocculants in waste drilling fluid treatment. [ABSTRACT FROM AUTHOR]

Sediments are the main absorbers of metal pollutants. Therefore, it is essential to study them. In this paper, 72 samples of surface sediments from six stations were selected using Grap sampler in the summer of 2015 to determine the concentration of heavy elements such as cadmium, nickel, lead, and vanadium in the surface sediments of the North Yaran oilfield in Hur Al-Azim wetland. An atomic absorption device was used to determine the concentration of heavy elements, and SPSS and EXCEL software were used for statistical data processing. According to the results, the average concentration of cadmium, lead, vanadium, and nickel was 1.4, 48.87, 32.65, and 87.33 mg/L, respectively. Sediment quality standards in the United States (NOAA) and in Canada (ISQGs) were used to compare these values with the allowable contamination levels of elements in sediment. According to the results, the average concentration of cadmium and lead in the present study was higher than the standard indicators of ERL and TEL and lower than the standard indicators of ERM and PEL. Average concentration of nickel was higher than these standard indicators. The results showed that nickel has more pollution than other metals, consistent with other research conducted in the region. Based on results, the amount of pollution of heavy metals studied in this research was not dangerous and critical. Still, it is necessary to prevent the increase in metallic toxicity in the region's environment by adopting preventive approaches.

The article is devoted to the life and the fate of the unfairly forgotten mining engineer Nikolay Stepanovitch Obukhovsky who has been victim of political repression in 1930-ies and to the disclosure of the activity of the Volga oil prospecting, Obukhovsky was the head of this authority in 19191924. The loss of the main oil-producing regions in Russia during the Civil War, the combusted fuel crisis had moved to the agenda the search for oil in the other regions, including the Volga region, this area has been oil tested even before the revolution (exploration drilling). As a result, the authority of the Volga oil prospecting was established and the oil prospecting works were started. The goals of the study are to recall the life course of the mining engineer N.S. Obukhovsky, to discover the main directions of his management of the Volga region oil prospecting and publishing with the main accent onto the Volga region oil. The authors clear and analyze the originality and the main aspects of functioning of oil fields under extreme conditions of the famine, the chronic shortage of finances, material and technical and human resources as well. The article shows the whole number of disadvantages leading to the disruption of geological oil prospecting work in the Volga region, firstly the extremely poor financing of the performed works, abnormal food shortage, under-staffing and the competition of the old oil-producing southern regions outperformed the Volga territory at that time. The conclusion that the Volga oil prospecting authority managed by N.S. Obukhovsky in the period 19191924 became the first attempt to decide a question about the availability of the Volga oil nationally and the name of the authority director must be entered into the constellation of the Soviet oil-well experts who have taken the first steps on the way to the big oil of the Second Baku is drawn

This article presents results of investigation of dust load and content of metals and metalloids (MMs) in the snow samples taken at the Vatinskoye oil field (Khanty-Mansi Autonomous District - Yugra). Concentrations of dissolved and suspended forms of MMs in 20 samples collected in March 2021 were determined by the ICP-MS and ICP-AES methods. Eighteen elements (Ag, Ba, Bi, Cd, Cr, Cu, Fe, Hg, Li, Mn, Ni, Pb, Sb, Sn, Sr, Ti, W, and Zn) indicating various sources of emissions were selected for further analysis. Filters with a pore diameter of 0.45 μm were used to separate dissolved and suspended forms. Enrichment of the suspension with chalcophile elements (Ag, Cu, Zn, Sn, Sb, Pb) was noted in the background areas. Calculations of enrichment coefficients (CO) using Li as a reference element demonstrated that Cu, Mn and Ni come from natural sources (rocks and soils), while the others have a mixed natural-anthropogenic origin. It was noted also that the mass fraction of a number of metals (Cr, Cu, Ni, Zn) increases in solid-phase deposits. The metals Zn, Cu and Cr are mainly contained in snow in suspended form, and Ni - both in dissolved and suspended forms. As a result of calculations of the total Cr pollution index, most of the deposit is classified as "low, non-hazardous" pollution areas. The highest concentrations of MMs in the snow were found in the southern part of the deposit, where the main infrastructure facilities and the communications lines are concentrated, including roads, railways and pipelines. They were specified as "average, moderately dangerous" level of pollution. To determine sources of pollution, the factor analysis was applied, and as a result of which two main factors were identified: 1) the background pollution, which is indicative of deposition of Cu, Sn, Sb, Ag; 2) the anthropogenic one, corresponding to high levels of Cr, Ni, Zn. Spatial analysis of the MMs distribution showed that the deposition of Ni, Cr is associated with drilling operations, while Zn - with the presence of transport. The data obtained can be used to understand the processes of atmospheric deposition of potentially toxic metals and metalloids, as well as to assess the quality of the environment at oil and gas fields.

The paper represents the results of field measurements in the off-grid power system of oil field including diesel power plant, which supplies drilling rig system BU-4500/270 EK-BM. The data has been processed using the instantaneous power theory by Hirofumi Akagi. The active power load diagram of diesel power plant and power system frequency schedule have been obtained for hole drilling technological process of drilling rig. Abrupt load changes during drilling lead to large frequency deviations, which do not allow using gas piston generators in power system of oil field without revision of number and rated power of generators or using electrical energy storage system.

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ASP flooding oil technology, as a highly concerned method for improving oil recovery in recent years, has the advantages of high oil displacement efficiency and good environmental protection. Horizontal-vertical joint development technology is a method of achieving efficient oil-field development by optimizing well network layout, adjusting injection production parameters, and other means. It improves the pressure field and flow field distribution inside the reservoir, enhances sweep efficiency and oil recovery efficiency, thereby achieving the goal of increasing crude oil recovery rate. This article aims to explore the combined application effect and mechanism of ASP flooding oil technology and horizontal-vertical joint development technology through experimental research, providing new ideas and methods for efficient development of oil fields. The joint application of ASP flooding oil technology and horizontal-vertical joint development technology provides a new approach for efficient oil-field development. This joint application can not only improve the recovery rate of crude oil, reduce development costs, but also help reduce environmental pollution and achieve the sustainability of oil-field development.

Perforation repair technology plays an important role in prolonging the life cycle of oil fields. However, the traditional perforation repair method can no longer meet the needs of modern oilfield development. With the continuous growth of artificial intelligence technology, the optimization algorithm based on data analysis and model has achieved remarkable success in many fields. In this paper, an optimization algorithm based on artificial neural network (ANN) is proposed to improve the performance of perforation repair and oil recovery. The algorithm can predict the oil field output under different perforation repair schemes according to the information of geological data, production data and historical data of the oil field, and get the optimal perforation repair scheme through optimization. The results show that this algorithm has obvious advantages compared with the traditional support vector machine (SVM) algorithm, and the error is reduced by 24.58%. By comparing the reservoir state prediction results of SVM algorithm, it is found that the prediction results of ANN are closer to the actual value and can better reflect the actual situation. This method provides new ideas and methods for the optimization and improvement of oil field perforation repair technology, and shows broad prospects for the application of machine learning technology in petroleum engineering.

Copyright of Corrosion & Protection in Petrochemical Industry is the property of Corrosion & Protection in Petrochemical Industry Editorial Office and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Alkyl nitrates (RONO2) are important reservoirs of nitrogen oxides and play key roles in the tropospheric chemistry. Two phases of intensive campaigns were conducted during February-April and June-July of 2017 at a rural coastal site and in open oil fields of the Yellow River Delta region, northern China. C1-C5 alkyl nitrates showed higher concentration levels in summer than in winter-spring (p 4 carbon atoms were also important precursors of alkyl nitrates in the oil fields. This study demonstrates the significant effects of oil field emissions and biomass burning on the volatile organic compounds and alkyl nitrate formation, and provides scientific support for the formulation of control strategies against photochemical air pollution in the Yellow River Delta region.

The working condition of medium in the Tahe Oilfield sewage treatment system is complicated and harsh, and the forced current cathodic protection technology can effectively control the station corrosion, prolong the service life and improve the oil removal efficiency. Based on the research method of combining theory with practice and taking into account the relevant domestic and foreign standards and codes, the calculation method of the forced current parameters, the selection of the auxiliary anode block and the selection of the potentiostat were put forward from the aspects of design, construction and evaluation. The installation position and form of the auxiliary anode block were introduced, the key points and requirements of the construction quality control were summarized, and the field application of the forced current cathodic protection technology was analyzed and discussed. Besides, its applicability in Tahe Oilfield was analyzed from three levels: pre - application necessity analysis, field parameter determination and effect evaluation. It was proved that after applying the above - mentioned technology, the corrosion problem of sewage treatment system was effectively controlled, the safe and stable operation of the oil and gas processing system was ensured.

The article describes an approach to expanding the methodology for applying hydraulic fracturing in oil fields by adding the possibilities of 3D modeling with color imaging of the pore structure of the productive intervals of wells. As an applied example, the geological and geophysical section of the productive level of one of the wells of the Moscudinskoye oil field, with known data on the integrated interpretation of the results of well-logging and microcomputer tomography, was chosen. According to well-logging data, the productive reservoir in the analyzed section of the section is characterized by a high degree of heterogeneity. Tomographic studies of a full-size core made it possible to identify four lithotypes here with different pore structure features. Accounting for the identified reservoir heterogeneity, as well as data on the thickness and other characteristics of reservoir properties of individual lithotypes that make up the section, made it possible to significantly increase the detail of the final geological model of the wellbore section. A distinctive feature of this final geological model is the use of the method of enlargement of the initial data array by adding intermediate values that were calculated theoretically. The visibility of the final geological model of the borehole walls is provided by color 3D imaging of the calculated data of the enlarged massif and makes it possible to judge the presence of areas with good and weak fluid conductivity on the lateral surface of the borehole walls. According to this model, intrastratal transverse and longitudinal fluid-conducting "corridors" are observed in the circumwell zone that determine the hydro-dynamic movements of natural and artificial fluids in the space of productive reservoirs. [ABSTRACT FROM AUTHOR]

Using digital technologies in its activities, an oil producing enterprise is able to gain a success only when a strategic approach is applied and, establishing a balance between actual and actual capability is equal to capability to beneficial transformations. The oil-extracting businesses digitalization of oil producing enterprises fundamentally alters key technologies throughout the entire life cycle from geological modelling, drilling and field development to commercial oil production. Peculiar to each stage of the life cycle, tools appear to evolve and transform themselves in accordance with the development of the enterprise. At the moment, advanced production technologies that are most in demand at oil producing enterprises are digital engineering, simulation modelling, smart manufacturing technologies, industrial Internet of things and artificial intelligence, virtual and augmented reality. Digital technologies enable production losses, mean time between failures, recovery time or downtime to be better foreseen and improve decision-making, early failure detection, calculate capital costs, operating costs and net present value for each particular well or for the deposit or oil field as a whole. The entire implementation of the project with digital technologies occurs according to the order: data collection, data research, modelling, analysis of results, testing the model's performance on other wells, and replication. [ABSTRACT FROM AUTHOR]

This study was conducted within the Al-Gharraf oil field area to evaluate the pollution status of some heavy metals (Pb, Co and Cu), which are the source of gases and vapors emitted from the Al-Gharraf oil field due to oil extractive operations in region. This study was conducted within the Al-Gharraf oil field area, which included cultivated and uncultivated lands at dimensions of (600, 1200 and 2400) m from the source of pollution and at two depths of (0-15) cm and (15-30) cm. Soil samples were collected from the study locations and the required analyzes were conducted on them. The results of the study showed an increase in the total concentration of heavy metals (Pb, Co, Cu) in the locations near the source of pollution (the first location) for cultivated and uncultivated lands compared to the far locations (the third location), the average concentration of these elements in the uncultivated lands increased in comparison with the cultivated lands, as their concentration in the uncultivated lands reached (233.31, 36.28 and 246.89) mg kg-1 soil sequentially, while the cultivated lands recorded a lower value of (187.68, 27.48, and 191.24) mg kg-1 soil, respectively. The results of the study showed an increase in the values of pollution standards (CF and PLI) for cultivated and uncultivated lands, which were caused by human activity in the region represented by oil extraction operations and the Contaminate factor value (CF) for the studied heavy elements was between medium to considerable pollution the pollution load index value 1 < PLI for cultivated and uncultivated lands and this means indicates deterioration of location quality. [ABSTRACT FROM AUTHOR]

Determining formation pressure in the well extraction zones is a key task in monitoring the development of hydrocarbon fields. Direct measurements of formation pressure require prolonged well shutdowns, resulting in underproduction and the possibility of technical problems with the subsequent start-up of wells. The impossibility of simultaneous shutdown of all wells of the pool makes it difficult to assess the real energy state of the deposit. This article presents research aimed at developing an indirect method for determining the formation pressure without shutting down the wells for investigation, which enables to determine its value at any time. As a mathematical basis, two artificial intelligence methods are used – multidimensional regression analysis and a neural network. The technique based on the construction of multiple regression equations shows sufficient performance, but high sensitivity to the input data. This technique enables to study the process of formation pressure establishment during different periods of deposit development. Its application is expedient in case of regular actual determinations of indicators used as input data. The technique based on the artificial neural network enables to reliably determine formation pressure even with a minimal set of input data and is implemented as a specially designed software product. The relevant task of continuing the research is to evaluate promising prognostic features of artificial intelligence methods for assessing the energy state of deposits in hydrocarbon extraction zones.

Relevance of the research is, on the one hand, conditioned by the reduction in effectiveness of oil field development using conventional methods, on the other hand, by climate change agenda, which is aimed at reduction in carbon footprint in production. The global experience has shown the growing demand for gas method of enhanced oil recovery that optimally meets the requirements for balance between oil recovery and carbon footprint. The aim of the research is to justify the probability of gas method of enhanced oil recovery at basic developed oil fields of the formations K1jk - III-VII, K1nch -I, K1nch - III-IV. Research area is Vankor oil-gas condensate field located in Krasnoyarsk Territory and included in Vankor Cluster. Method: calculation of minimum miscibility pressure using techniques from Russian and international practice. Results. Taking into account oil displacement with gas and key factors influencing the process and choice of gas (pressure and temperature condition, geologic and physical reservoir characteristics, physical and chemical composition of formation fluids), the calculation of minimum miscibility pressure was performed at which gas can be completely dissolved in formation oil as a result of multiple contact miscible process at formation temperature. The types of gas miscibility with formation fluid were justified for the chosen pay zone in Vankor oil-gas condensate field, as well as the maximum efficiency of carbon dioxide gas as a gas driver was substantiated to enhance oil recovery as compared to nitrogen and carbon dioxide gas at final stage of separation. However, due to contemporary infrastructure, production, macroeconomic conditions of producing company operation the project is not profitable.

Flare volume measurement has been the sole yardstick for tracking flare gas reduction progress and provides a single view of monitoring in the context of its use. In this study, an alternative method was introduced to broaden the perspective of flare gas monitoring. Flaring intensity is a simple and effective measure for tracking flare gas reduction. Flaring Intensity index was applied in different levels of flare volume estimation, namely Oilfield, Oil Company, Petroleum Upstream Contract and Country. Nigerian Petroleum Production data were sourced from regulatory reports and satellite data from 2012 to 2015 and 2018 annual reports. The results revealed that Nigeria’s flaring intensity is on the decline due to exogenous factors and it illustrates flaring intensity as a comparative and benchmarking tool for gas flare performance at various hydrocarbon production levels. The study also inferred that improved flare gas measurement, transparency in reporting, robust regulation and increased gas handling infrastructure were necessary in order to mitigate flaring in Nigeria to achieve the 2030 Zero Routine Flaring target.

Many waterflooding oil fields, injecting water into an oil-bearing reservoir for pressure maintenance, are in their middle to late stages of development. To explore the geological conditions and improve oilfield recovery of the most important well group of the Hu 136 block, located on the border areas of three provinces (Henan, Shandong, and Hebei), Zhongyuan Oilfield, Sinopec, central China, a 14C cross-well tracer monitoring technology was developed and applied in monitoring the development status and recognize the heterogeneity of oil reservoirs. The tracer response in the production well was tracked, and the water drive speed, swept volume of the injection fluid were obtained. Finally, the reservoir heterogeneity characteristics, such as the dilution coefficient, porosity, permeability, and average pore-throat radius, were fitted according to the mathematical model of the heterogeneous multi-layer inter-well theory. The 14C-AMS technique developed in this work is expected to be a potential analytical method for evaluating underground reservoir characteristics and providing crucial scientific guidance for the mid to late oil field recovery process. [ABSTRACT FROM AUTHOR]

Toward the goal of achieving carbon neutrality by 2050, carbon capture and storage (CCS) is becoming more important as a measure to reduce CO2 emission associated with oil and natural gas development. INPEX corporation jointly with JOGMEC set out plans to drill two new wells in Minami-aga oil field with the following objectives: • to evaluate foam enhanced oil recovery (EOR) technology using foaming agent currently under development; • to investigate potential opportunity of further commercial development of Minami-aga field using CO2-EOR; and • to acquire lessons learnt of field experiences for carbon capture, utilization and storage (CCUS). This presentation describes the conceptual well design of the two wells to be used for huff and puff operation. Fiber cables are designed to be installed behind production casing to acquire data by distributed acoustic sensing (DAS) and distributed temperature sensing (DTS). To avoid damage to the fiber cables, an oriented perforation is planned. Hence, the inclination across the perforation is designed at 30 degrees to assure high and low sides. In completion, a formation isolation valve (FIV) is designed to be incorporated, to eliminate effect of wellbore storage during pressure'build up / fall off recorded by downhole gauge. Unlike surface-controlled subsurface safety valve (SCSSSV), FIVs adopt a fail-as-is feature which cannot close the valve in case of control line failure. Since wells are unable to naturally flow over the period of well life, a SCSSSV is not adopted. The perforation gun with dynamic underbalance is planned to be deployed through the completion. Prior to perforation, wellbore is displaced to underbalance fluid to reduce skin damage. During wellbore clean-up flow and production, gas lift using a coiled tubing or macaroni pipe installed inside the tubing is planned since the wells are unable to naturally flow due to the reservoir pressure depletion. [ABSTRACT FROM AUTHOR]

The development of Arctic hydrocarbon resources is in the sphere of interests of many large companies. At the same time, the vast northern territories and polar seas do not have a developed infrastructure that would allow implementing various transport and technological solutions for the development of oil fields. The opportunities for attracting the resources of the Russian Arctic into economic circulation are currently being used to a small extent, which is caused by various factors, both objective and subjective, that were formed at the previous stages of the country's development. This work is devoted to the problem of choosing an HR strategy when placing objects of the transport and technological system of oil fields in the Russian Arctic, taking into account the ecological, economic and socio-economic features of this macroregion. Using the example of oil and gas fields in the coastal-shelf zone of the south-eastern part of the Barents and Kara Seas, the authors consider multivariate forecasts for the formation of a rational scheme for the transportation of hydrocarbons as an integral part of the regional oil and gas complex. The authors assign a special role to the important economic and socio-psychological components associated with the processes of organizing the work of oil workers. At the same time, they come to the conclusion that the shift method of labor organization, adopted by many large mining companies, should not displace, but only complement the traditional methods of attracting personnel to the Arctic oil infrastructure facilities. The use of the combined method of labor organization in the Arctic is the most optimal, allowing to integrate the advantages and localize the disadvantages of other methods of labor organization.

Concentrations and sources of Polycyclic aromatic hydrocarbons were determined seasonally in some terrestrial plant species (Conocarpus lancifolius, Eucalyptus camaldulensis and Suaeda vermiculata) at three stations in west Qurna-1 oil field, southern Iraq during the period from January 2018 to December 2018. The results showed that the highest mean concentration of PAHs in plant species at DS6 was (2.813 ng/g dry weight) in E. camaldulensis and the lowest was in C. lancifolius (2.106 ng/g dry weight). Seasonal variation of PAHs concentration showed that the highest mean concentration was recorded in spring (2.634 ng/g dry weight) in E. camaldulensis while the lowest mean concentration was recorded in winter (1.975 ng/g dry weight) in Suaeda vermiculata. According to the PAHs indices [(The Fluoranthene/Pyrene ratio, Phenanthrene/Anthracene ratio, LMW/HMW ratio, Ant/(Ant+Phen) ratio, BaA/(BaA+Chry) ratio and InP/(InP+BghiP) ratio)], the main sources of PAHs in these plants species were pyrogenic and petrogenic. [ABSTRACT FROM AUTHOR]