CO2 storage in geological formations represents today one of the main new technological solutions for CO2 emission mitigation. Carbon capture and storage technology (CCS) includes capture of anthropogenic CO2 from various emitters, its transportation and injection in different types of geological formations such as: depleted oil and gas reservoirs, saline formations, unmined coal beds, partially depleted oil reservoirs for enhanced oil recovery (EOR-CO2 method) and others. The analysis of numerous criteria that are determining the success of process implementation from a technical, safety, ecological and economic point of view is necessary for considering the optimal CO2 geological storage option. In this paper, an overview of CO2 geological storage types is presented, with an emphasis on criteria for selection of most adequate CO2 storage option. They include geological, physical, thermodynamic, hydrodynamic, techno economic, social criteria, as well as the regulatory issues that are key factors for CCS technology development and further deployment.

The production of paraffin-base crude is expensive and more complex then of other oil types. In northern Serbia, where majority of oil and gas fields are located, about 25% of oil production accounts for the high paraffin oil. During this oil type production, the paraffin deposition occurs in tubing's upper zone, ranging from 700 m depth upwards. In this article is presented original way of heating cable application, for solving paraffin deposition problem in tubing that can be easy and quickly installed in the well. Paraffin deposition problem is solved by heating, and at the same time the increased temperature causes the oil viscosity reduction resulting with improved oil flow rate. Application of this method and the results are exemplified by the flowing well B-3 where are used two different heating cables. This method, which is very successfully solves the problem of paraffin deposition in the tubing, can also be applied to wells producing by different artificial lift methods.

Tertiary methods in oil production process called 'Enhanced Oil recovery methods' (EOR) are mostly applied in mature oil fields with declining production trend after primary and secondary recovery methods or immediately after primary production phase. These 'Enhanced Oil Recovery' methods implies injection of gases or fluids to mobilize residual oil captured in reservoir rock due to presence of strong viscous and capillary forces and high value of interfacial tension between fluid and rock. Depending on the type of injected fluid, production mechanism, as well as an approach to implementation, EOR methods are divided into thermal methods, chemical methods, miscible/immiscible gas injection methods and other methods that so far have an experimental application. The paper analyzes the key factors influencing the successful implementation of EOR projects: phases of EOR project implementation, the price of crude oil at the world market as a criterion for the beginning and the justification for EOR process application and development of new technologies for more efficient process realization.

Abstract:In this paper is presented the concept of integrated oil production management model. The model's main objective is to provide more efficient tool for oil production process management in terms of the technological and economical aspects. Integrated oil production management model implies multidisciplinary approach which connects oil reservoir development and production with application of risk analysis. Model's task is to simulate behavior of the whole production system, enabling overcoming the weaknesses of conventional deterministic analysis and significantly enhancing oil production, as well as an investment decision making. In the article is presented shortly the application of integrated oil production management model at the oilfield "K". The ultimate goal was techno-economic analysis of managing production process, i.e. determination of production economic limit based on production history data, decline analysis and operating costs.Key words: oil, production, management, integrated model, decision making Apstrakt: U radu je predstavljen koncept modela integralnog upravljanja proizvodnjom nafte. Glavni cilj modela je da obezbedi efikasniji alat za upravljanje procesom proizvodnje nafte uzimajući u obzir tehnološke i ekonomske aspekte. Integralni model upravljanja podrazumeva multidisciplinarni pristup koji povezuje razvoj ležišta i proizvodnju uz primenu analize rizika. Zadatak modela je da simulira ponašanje kompletnog proizvodnog sistema, uz prevazilaženje slabosti konvencionalne determinističke analize, značajno poveća proizvodnju nafte i donošenje odluka. U radu je prikazana primena inegralnog modela na primeru naftnog polja "K". Cij je bila tehno-ekonomska analiza upravljanja proizvodnim procesom, odnosno određivanje ekonomskog limita proizvodnje baziranog na istorijatu proizvodnje, analizi pada proizvodnje i operativnim troškovima.

Danas se u svetu za eksploataciju naftnih ležišta mehaničkim metodama primenjuju različiti tipovi dubinskih pumpi (klipne, centrifugalne, zavojne, hidraulične), hidromlazne pumpe i gas lift (kontinualni, povremeni i klipni). Maksimalne vrednosti proizvodnje fluida, ostvarene mehaničkim metodama eksploatacije, se međusobno veoma razlikuju. U cilju izbora optimalne mehaničke metode koriste se modeli višekriterijumskih analiza. U radu je predstavljena analiza primene višekriterijumskih modela VIKOR, TOPSIS, ELECTRE, AHP i PROMETHEE u cilju izbora optimalne mehaničke metode eksploatacije karakteristične naftne bušotine sa istražnog područja Srbije. Rezultati rangiranja primenljivosti dubinskih pumpi na klipnim šipkama, hidrauličnih pumpi, zavojnih pumpi, gas lifta i električnih uronjenih centrifugalnih pumpi, ukazuju da se kod svih navedenih višekriterijumskih modela, osim u slučaju PROMETHE modela, nalaze na prva dva mesta kao optimalne metode eksploatacije dubinske pumpe na klipnim šipkama i gas lift.