Stages Of Field Development Research Articles

Применение скважинных установок предварительного сброса воды с мобильными установками подготовки нефти на поздних стадиях разработки месторождений

Применение скважинных установок предварительного сброса воды с мобильными установками подготовки нефти на поздних стадиях разработки месторождений

Определение температуры гидратообразования в скважинах как метод предупреждения выпадения газовых гидратов

Deposits of solid gas hydrates in gas and gas-oil wells at the late stages of field development is one of the most common types of well complications. The formation of hydrate deposits in the well leads to clogging of the flow area of the lifting pipes, a decrease in well productivity, abrasive wear of the working bodies of the pumps and product emulsification. Methods for removing hydrate plugs are very expensive, and their effectiveness is low due to their recurrence. One of the most promising methods of dealing with hydrate deposits is a preventive method, which consists in maintaining thermobaric conditions in the well, under which hydrates will not form. This technique is proposed to be implemented using the Katz technique for determining the sum of molar components in the gas phase.

Effectiveness of gas inflow stimulation works at the final stage of field development

The focus of the study is the investigation of terminological foundations and the development of practical recommendations for assessing the effectiveness of hydrocarbon inflow stimulation at the final stage of field development. The authors refer to scientific works on the issues of company performance. The paper provides substantiation and improvement of methodological grounds with respect to assessing the effectiveness of gas inflow stimulation works. A classification and analysis of prominent Russian and foreign methods are provided and their issues are identified. As a result, the work refines the methodology for assessing the effectiveness of work at the drilling enterprise. The authors' comprehensive approach to assessing the effectiveness of inflow stimulation works, which allows for obtaining interrelated performance assessments, is proposed.

Assessment of reasonability of production wells transfer to well workover stage

The article discusses predicting the critical parameters of production wells to assess the need to transfer them to well workover stage and put on the program of geological and technical measures (GTM). A methodology for substantiating and assessing the influence of critical values of reservoir parameters on the operation of production wells is presented. Three stages of transferring wells to workover are considered: geological, technological and analytical, and the procedure for assessing their effectiveness. The procedure for calculating the shut-in time of wells and gas losses during the transition of production wells to workover, determining the parameters of the technological regime after geological and technical measures are considered. A method has been developed for predicting the time of well shut-in due to flooding (self-killing) and assessing the timing of its operation with production flow rates at the final stage of field development. The results of the study of dependence of the critical height of the liquid column on the bottomhole pressure and the average daily flow rate of the Cenomanian well, the scheme for revealing the dependence of gas water contact level on the reservoir pressure and the volume of the sampled gas are presented. The procedure for calculating the technical and geological-production state of wells is considered according to the diagnostic rating assessment. Keywords: field; gas well; prediction; critical parameter; cenomanian; flooding; flow rate; pressure.

Investigation methods of protection from the complications during the production in the final stage of field development

In the article, based on the data of the fields in the final stage of exploitation, the most important complications that occurred during the production period and the methods of preventing these complications in the modern period were investigated. In particular, the methods of preventing of the sand plug and flooding, which are the main problems in this type of fields, were investigated and the significance of these methods of selective control against flooding was investigated, the most successful ones among these methods were shown, the hardening of the bottom hole against sand plug and the use of sand control screen in modern times were considered, in the hardening of the bottom hole the use of resin-containing components is mentioned. Keywords: Complications; Sand plug; Flooding; Chemical hardening; Waterproofing.

Localization and development of residual oil reserves using geochemical studies based on neural network algorithms

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 ready-made 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.

Improving the efficiency of processing the results of reservoir filtration studies and parameters when modeling complex oil reserves

The issues of improving the efficiency of processing the results of studies of the filtration properties of reservoirs within the oil and gas producing areas of the central part of the West Siberian oil and gas province are considered. The high degree of development of the hydrocarbon resources of the studied territory is characterized by the presence of long-term developed deposits, which determines the solution of tasks aimed at increasing the success of the search for complex deep-lying reservoirs, the efficiency of their exploration and additional exploration, since the overlying productive horizons are practically developed. This task is one of the most important at the current stage of field development in this region, in the context of falling oil production at the main large fields, and has no unambiguous solution.This article covers the issues of reservoir modeling using new scientific and methodological approaches to the processing of geophysical data and the possibility of using modern software products when grouping development objects according to criteria corresponding to a reservoir of a certain lithotype. This approach allowed us to build high-quality geological models and justify the use of the most effective complex of geophysical studies for modeling low-amplitude (no more than 15 m) and small-sized (less than 20 km2) oil deposits. In the course of research: The results of the reservoir filtration properties were processed; low-amplitude and small-size sediments of channel sediments (river valleys) were established; the industrial oil and gas content of complex sediments characterized by low-amplitude and small-size sediments (Tyumen formation, object Ю2) was proved; The interpretation of geophysical studies of wells was carried out, the results were compared with the energy characteristics of the reflected waves (seismic studies), zones saturated with water-oil-gas fluid were established (3D models were built), and the possibility of using this technique for identifying and mapping complex deep oil deposits was shown.

Factors affecting the effectiveness of the application gel-forming dispersed compositions in chemical methods of oil recovery improvement

The use of enhanced oil recovery (EOR) methods has a significant impact on the current level of hydrocarbon production. Therefore, the issue of maintaining the high efficiency of their application remains relevant at all stages of field development. Currently, in the field of flow diverting technologies (FDT) and technologies for leveling the injectivity profile many different reagents and compositions of EOR have been developed, as well as approaches and methods of their application. The choice of using certain methods of influencing a productive formation depends on its geological and physical conditions (HFC), therefore, the correctness of this choice has a direct impact on the effectiveness of the use of EOR technologies. This article is devoted to an analysis of the effect of certain HFCs on the efficiency of FDT use with the use of GFS gel-forming systems, heat-resistant GFS (T) gel-forming systems and GFS-1AS gel-forming systems with fillers. As a result of the analytical work carried out, the main trends in the efficiency of the application of the above technologies were predetermined from different indicators, such as the effective thickness of the formation, its reservoir properties, the volume of injected reagents, the compartmentalization of the formation, the injectivity of wells before treatment and the change in their mode of operation after treatment. The main conclusion, which is obtained based on the results of the work carried out, is that at the moment there is a need to search for or develop new approaches to the implementation of physical and chemical enhanced oil recovery methods, which will allow solving two main problems: improving the rheological characteristics of cross-linked polymer systems and reducing the cost of the work performed.

Управление добычей нефти на основе нейросетевой оптимизации режимов работы скважин на участке опытно-промышленных работ пласта ЮВ1 Ватьеганского месторождения ТПП «Повхнефтегаз»

Optimization of the “mature” fields development in machine learning algorithms is one of the urgent problems nowadays. The task is set to extend the effective operation of wells, optimize production management at the late stage of field development. Based on the task set, the article provides an overview of possible solutions in waterflooding management problems. Production management technology is considered as an alternative to intensification of operation, which is associated with an increase in the produciton rate and involves finding solutions aimed at reducing the water cut of well production. The practical implementation of the “Neural technologies for production improvement” includes the following steps: evaluation, selection, predictive analytics. The result is a digital technological regime of wells that corresponds to the set goal and the solution of the optimization problem in artificial intelligence algorithms using the software and hardware complex “Atlas – Waterflood Management”. “Neural technologies for production improvement” have been successfully tested at the pilot project site of the productive formation of the Vatyeganskoe field. The article provides a thorough and detailed analysis of the work performed, describes the algorithms and calculation results of the proxy model using the example of the pilot area, as well as the integration of the “Atlas – Waterflood Management” and the organization of the workflow with the field professionals of the Territorial Production Enterprise Povkhneftegaz.

ON THE ANALYSİS OF OPERATİNG PRACTİCES OF LİQUEFİED GAS PİPELİNES

ON THE ANALYSİS OF OPERATİNG PRACTİCES OF LİQUEFİED GAS PİPELİNES

INVESTIGATION OF WELLS IN THE WORKING FUND OF “AZNEFT” PU AND PROPOSAL OF ANTI-SAND MEASURES

INVESTIGATION OF WELLS IN THE WORKING FUND OF “AZNEFT” PU AND PROPOSAL OF ANTI-SAND MEASURES

Optimization and Evaluation of Stabilizers for Tight Water-Sensitive Conglomerate Reservoirs.

The upper Wuerhe formation in the Mahu-1 play is a tight conglomerate reservoir that has characteristics of low porosity and low permeability. During the early stage of field development, it has been noticed that horizontal wells typically have a high flowback ratio and an extremely low oil production rate during the early production, and this is likely attributed to the water–rock interaction that causes the closure of generated hydraulic fractures. In this study, a stabilizer and its dosage in a fracturing fluid are optimized, and its effect on clay antiswelling and rock stabilization is evaluated. Experimental results indicate that a mixture of a salt and an inorganic cationic polymer can effectively inhibit the water–rock reaction by minimizing the clay swelling and compressing the electric double layer on the rock surface. The antiswelling rate of montmorillonite can reach 93.56%, and that of the reservoir rock powder can reach 75.32%. Meanwhile, Brazilian splitting tests are conducted to evaluate the mechanical property change of reservoir rocks before and after being submerged in fracturing fluids with different stabilizers. Compared to 4% KCl, which is currently used in the field, the new formula can enhance the breakdown pressure by more than 10% without increasing the cost. The findings of this work provide a solution for fracturing water-sensitive reservoirs and also establish a set of laboratory methods for optimizing stabilizers as fracturing fluid additives.

Modification of Permeability Cube of Geologic and Hydrodynamic Model Under Various Volumes of Input Data

At any stage of field development, the process of developing and history-matching geologic and hydrodynamic models has many uncertainties. To improve reliability of geologic and hydrodynamic models all the available information shall be used. For undeveloped fields, these are the results of hydrodynamic well tests at the stage of early production, and for fields with a high degree of exploration all the available information shall be objectively integrated. This paper considers various approaches to improvement of geological and hydrodynamic models’ reliability. The authors propose a method of hydrodynamic model history-matching to indicator diagrams results. To refine permeability cube at underexplored fields, it is proposed to history-match the geologic and hydrodynamic model to the results of hydrodynamic tests carried out at exploration stage. For fields with a high degree of exploration, it is proposed to integrate different studies. Linear discriminant analysis was used for this purpose. As a result, this allowed to significantly reduce the model adaptation time and increase its predictive reliability.

DEFORMATİON DURABİLİTY - ADJUSTABLE BUFFERİNG BARRİER OF THE BOTTOM HOLE AREA

DEFORMATİON DURABİLİTY - ADJUSTABLE BUFFERİNG BARRİER OF THE BOTTOM HOLE AREA

Choosing a methodological base for forming and accounting for the construction costs of a gas well at the final stage of field development

The article introduces the problems of choosing a methodological base for forming and accounting costs during well construction, taking into account the intensification of gas inflow at the final stage of field development. The main methods that allow taking into account the costs of drilling operations are outlined. The main costs that need to be taken into account when designing fields with hard-to-recover gas reserves are identified and characterized. The main stages of cost formation by construction phases of a gas-producing well are shown, as well as the factors influencing the level and structure of the cost price during the construction of a well are highlighted. The authors consider the classification of cost accounting methods in the context of the comparison criterion and present the possible results of the correct choice of the cost formation method during the construction of a gas well at the final stage of its development.

Estimation of existing production capacity during operation in conditions of high watercut

The paper studies the estimation of existing production capacity of the wells operated via oil well pumps in conditions of high watercut. Production parameters are of great importance during the increase of production and efficiency of using well stock, particularly, in the last stages of field development. In this view, based on the actual field data, the values of oil and water rates of the wells operated from one object have been analyzed, as well as the distribution of rates by actual watercut diapason developed. The change rate of oil and water output depending on the watercut have been calculated based on mathematical models. The research results allow specifying the limit values of watercut, as well as contribute to trustworthy prediction of oil flow rate of the wells and development by the groups and whole well stock of producing wells.

Main directions of searching for hydrocarbons in Nadym-Pursk oil and gas region

Nadym-Pursk oil and gas region has been one of the main areas for the production of hydrocarbon raw materials since the sixties of the last century. A significant part of hydrocarbon deposits is at the final stage of field development. An increase in gas and oil production is possible subject to the discovery of new fields. The search for new hydrocarbon deposits must be carried out taking into account an integrated research approach, primarily the interpretation of seismic exploration, the creation of geological models of sedimentary basins, the study of geodynamic processes and thermobaric parameters. Statistical analysis of geological parameters of oil and gas bearing complexes revealed that the most promising direction of search are active zones — blocks with the maximum sedimentary section and accumulation rate. In these zones abnormal reservoir pressures and high reservoir temperatures are recorded. The Cretaceous oil and gas megacomplex is one of the main prospecting targets. New discovery of hydrocarbon deposits are associated with both additional exploration of old fields and the search for new prospects on the shelf of the north. An important area of geological exploration is the productive layer of the Lower-Berezovskaya subformation, in which gas deposits were discovered in unconventional reservoirs.

Differential evolution for early-phase offshore oilfield design considering uncertainties in initial oil-in-place and well productivity

• Differential evolution optimization of number of wells, plateau rate and NPV. • Multi-objective optimization considering ultimate recovery factor and NPV. • The NPV distribution average can be estimated with the average of the variables. • Method provides decision support to field planners in early field development. During the early phases of offshore oil field development, field planners must decide upon general design features such as the required number of wells and maximum oil processing capacity (field plateau rate), usually by performing sensitivity studies. These design choices are then locked in subsequent development stages and often prevent from achieving optimal field designs in later planning stages when more information is available and uncertainties are reduced. In the present study, we propose using numerical optimization of net present value (NPV) to advice field planners when deciding on the appropriate number of wells, maximum oil processing capacity (plateau rate) in a Brazilian offshore oil field. Differential Evolution (DE) is employed for solving the optimization models. The uncertainties considered are well productivity and initial oil-in-place, handled by (1) using the mean of the distributions and (2) Monte Carlo simulation. A multi-objective optimization was also formulated and solved including ultimate recovery factor in addition to net present value. The proposed method successfully computes probability distributions of optimal number of wells, plateau rate and NPV. If one wishes to compute the mean of such distributions only, for most cases it is adequate to run an optimization using the mean of the input values instead of performing Monte Carlo sampling. The multi-objective optimization allows to find field designs with high ultimate recovery factor and high NPV. In this case, the value of NPV is similar to the optimum NPV value when optimizing NPV only. The methods described could provide decision support to field planners in early stages of field development.

Ntegration of Petrophysical Analysis and Elastic Log Properties as an Input to Optimize the Development Wells Target in Unique Globigerina Limestone Gas Reservoir in Madura Strait

The Madura Strait PSC is located in the southern part of North East Java Basin with biogenic gas from Globigerina limestone Pliocene Mundu and Selorejo sequence as main target. At early stage of field development,understanding and knowledge about petrophysical and elastic properties of reservoir rock quality is required and very important. The petrophysical analysis provide properties such as clay volume, porosity, permeability, water saturation and mineral volume to separate reservoir and non-reservoir zone. The elastic rock properties such as acoustic impedance (AI), shear impedance (SI), velocity ratio (Vp/Vs), and Poisson’s ratio (σ) were generated to identify clay zone, gas and non-gas also focused to distinguish reservoir rock quality inside gas zone as an effective reservoir characterization. This research is done by utilize core data, quad combo logs from eleven wells and shear velocity from eight wells. The purpose of this research is to optimize development well target in Globigerina limestone gas reservoir, which have good to best reservoir rock quality shown with high porosity and permeability,low clay volume and water saturation. Results from this research indicate that lime mud matrix have significant impact in the reservoir rock quality. Meanwhile, gas saturation can affect the elastic properties due to this high gas saturation can decrease compressional velocity (Vp) value. Finally, the integration of petrophysical result and combination of elastic properties implementation can help in distinguishing the best reservoir rock quality, which contains gas that should be penetrated by the development wells

CONTROL OF THE HEATING CABLE OPERATION BASED ON A MATHEMATICAL MODEL OF HEAT AND MASS TRANSFER PROCESSES IN AN OIL WELL

The paper considers the problem of controlling the process of thermal dewaxing of oil and gas wells using a heating cable. An axisymmetric mathematical model of heat and mass transfer processes in an oil well is proposed, the implementation of which makes it possible to estimate the temperature distribution on the wall of a pumping compressor pipe, to determine the area of ​​possible deposition of asphalt-resin-paraffin substances and the necessary conditions to prevent their formation. The mathematical model is a system of differential equations based on the laws of conservation of energy, mass and momentum. Considers the basic principles of heating cable control used in modern thermoelectric installations. The inefficiency of these methods is shown, which leads to increased energy consumption and accelerated aging of the heating cable. A fundamentally new algorithm for controlling the operation of a heating cable is proposed, based on modeling the processes of heat and mass transfer in an oil well. The use of this algorithm makes it possible to obtain with a sufficiently high accuracy the temperature distribution inside the well and determine the required heating time and power to prevent the deposition of asphalt-resin-paraffinic substances on the walls of the tubing. The control algorithm is implemented taking into account the technological parameters of production, which have a significant impact on the temperature distribution in the well, and adapts to their possible change caused by the heterogeneity of the oil and gas reservoir. The proposed heating cable control algorithm makes it possible to reduce energy consumption, which is the main disadvantage of thermal dewaxing of oil wells using resistive heating, and to prevent premature equipment failure caused by possible overheating of the heating cable line. The results presented in the work can be useful in the development and operation of oil and gas wells complicated by asphalt-resin-paraffin deposits. Application of the proposed mathematical model makes it possible to evaluate the efficiency of thermal dewaxing of wells with a heating cable at the stage of field development and draw conclusions about the effectiveness of this method of combating paraffin deposits. The control algorithm based on the proposed mathematical model makes it possible to effectively use the equipment and reduce capital costs for electricity and well turnaround.