Czarnota, Robert
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inżynieria środowiska, górnictwo i energetyka
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Item type:Article, Access status: Open Access , Hydraulic fracturing optimization framework based on PKN and Cinco–Ley methods(2017) Budzowski, Radosław; Janiga, Damian; Czarnota, Robert; Wojnarowski, PawełIn an era of decreasing number of discoveries of conventional hydrocarbon reservoirs, in the global oil and gas industry we can observe growing interest in unconventional resources. Conducting effective production from this type of reservoirs is associated with carrying out the intensification processes of production, among which hydraulic fracturing is the most popular. Fracturing project design consist of several technological parameters, i.e. the type of fracturing fluid and quantity of proppant, which have a direct impact on the process effectiveness. The actual shape of the fracture is difficult to predict due to the local heterogeneity of the reservoir and the superposition of the phenomena occurring during stimulation treatment. In this paper optimization model was proposed, which allows for selection appropriate parameters of fracturing technology. Developed optimization algorithm is based on two-dimensional PKN fracture model and Cinco–Ley analytical method. Optimization method used in this paper based on nature – inspired algorithms which were compared with gradient method.Item type:Article, Access status: Open Access , Optimization of well placement and control to maximize CO₂ trapping during geologic sequestration(2016) Stopa, Jerzy; Janiga, Damian; Wojnarowski, Paweł; Czarnota, RobertThe $CO_{2}$ injection into geological formations such as saline aquifers can be effective method of sequestration enabling efficient immobilization of gas by surface and capillary forces. The main objective of presented method of optimization was to determine optimal well position and injection rates that maximize residual trapping. This would mitigate the risk of the $CO_{2}$ leakage outside of storage zone. A genetic algorithm and particle swarm optimization have been developed and coupled with reservoir simulator to optimally examine various placement and injection control strategies for vertical as well as horizontal well. Optimization was carried out in 3D heterogeneous real field model with water-$CO_{2}$ -formation rock relationship. Numerical examples confirm that developed algorithm can find a promising optimal solution effectively within a partial number of simulation runs.Item type:Article, Access status: Open Access , Microscale modeling of CO₂-EOR process in coupling with laboratory measurements(2017) Janiga, Damian; Czarnota, Robert; Stopa, Jerzy; Wojnarowski, PawełApplication of enhance oil recovery methods (EOR) as carbon dioxide injection ($CO_2$-EOR) can increase technological or economical production indicators. For the evaluation of process effectiveness, full scale simulation model is used. Numerical models require large number of high quality geological and production data. However, the necessary data may be uncertain therefore microscale laboratory experiment and modeling can provide a knowledge to understand the fluid flow phenomena. In this paper the authors propose an integrated decision model coupling laboratory measurements of displacement with the numerical simulation of flow. First step consists of routine rock properties determination, after that core sample geometry, porosity and permeability were reconstructed in numerical reservoir simulator. Simple core model was combined with relative permeability measurements for oil - water and oil - carbon dioxide as well as fluid properties. Calibrated to laboratory measurements simulation model was used to analyze the process of $CO_2$-EOR and evaluation of its effectiveness depending on technological parameters.Item type:Article, Access status: Open Access , Laboratory measurement of wettability for Ciężkowice sandstone(2016) Czarnota, Robert; Janiga, Damian; Stopa, Jerzy; Wojnarowski, PawełThe type of reservoir rock wettability is one of the most important factors affecting flow of formation fluids in rock pores. It impacts on the characteristics of capillary pressure curves and residual oil saturation, what result in final recovery factor. There are generally, four differ states of wettability for hydrocarbon fields. These are: water wet, oil wet, mixed and fractional. For determination of wettability both quantitative and qualitative methods are implemented. In presented work, the results of wettability laboratory measurement for Ciężkowice sandstone by Amott–Harvey has been shown. Obtained outcomes underline the influence of wettability phenomena on the recovery factor for Carpathian hydrocarbon fields, where Ciężkowice sandstone is the oil bearing formation. The proper understanding of the wettability of reservoir is essential for determining the most efficient way of oil production.Item type:Article, Access status: Open Access , Oil production technology for unconventional reservoirs(2015) Stopa, Jerzy; Czarnota, Robert; Wojnarowski, Paweł; Janiga, DamianInterest in the subject related to the oil production from unconventional hydrocarbons has increased in recent years. Operation of such reservoirs requires the use of the state-of-the-art technology. Definitely, drilling horizontal and multilateral wells in conjunction with hydraulic fracturing and acidizing meet that requirement. This paper discusses the most important from the author’s view issues, including artificial lift systems, connected with oil production from unconventional reservoirs around the world and its applicability for Polish hydrocarbons reservoir.Item type:Article, Access status: Open Access , Intelligent control of CO₂-EOR process(Wydawnictwa AGH, 2018) Mikołajczak, Edyta; Stopa, Jerzy; Wojnarowski, Paweł; Janiga, Damian; Czarnota, RobertOne of the enhanced oil recovery methods, which enables to recover an additional 15-20% of oil resources is the $CO_2$-EOR method based on carbon dioxide injection into partially depleted reservoirs. Determination of the optimal process control facilitates effective use of natural resources. The idea of this paper is to develop an algorithm that optimizes the $CO_2$-EOR process. This algorithm is based on the combination of artificial intelligence, control theory and computer simulation of hydrocarbon reservoirs. The effect of the proposed solution is the $CO_2$-EOR process control, which is optimal in the case of the adopted objective function expressing the economic value of the project. The obtained results suggest that the use of artificial intelligence methods in the hydrocarbon production allows to improve the process efficiency by an additional 31% compared to the project carried out with the use of engineering knowledge.Item type:Article, Access status: Open Access , Predicting relative permeability from experimental capillary pressure porous plate test for two phase flow(2017) Czarnota, Robert; Janiga, Damian; Stopa, Jerzy; Wojnarowski, PawełRelative permeabilities relationships as a function of fluids saturation are one of the most important parameters for describing multiphase flow processes in reservoir rocks. When direct laboratory tests are not available for investigating oil-water multi-phase flow in rocks, then indirect prediction techniques using relative permeability functions are widely used, e.g. from capillary pressure test. In this study the measurement of capillary pressure was performed on rocks plugs with different characteristics at reservoir conditions using porous plate method. During measurement semi-permeable membrane was used with 15 bar threshold pressure, what allowed to register formation water saturation, at changing differential pressures steps. Desaturation at each pressure stage was continued until no more produced liquid was observed. Water saturation point at maximum capillary pressure applied is assumed to be final irreducible water saturation. Application of porous plate method provides sufficient stabilization time, allowing to achieve uniform saturation distribution. In this research, Brook–Corey model was used to predict relative permeability from experimental measured capillary pressure data for oil-water phase flow in porous media. As a result, it is possible to obtain more accurate capillary pressure outcomes, and relative permeability curves for the two-phase system, than other methods used in practice. Performing capillary pressure measurements at reservoir conditions, allows to restore the processes occurring in the reservoir.