Submit Manuscript | http://medcraveonline.com Introduction A signifcant portion of current hydrocarbon reserves exists in gas/condensate-carrying formations. In analogy to oil reservoirs, the production of condensate felds by pressure depletion only may result in signifcant loss of the heavy ends owing to liquid dropout below the Retrograde Dew Point (RDP) Pressure. 1,2 The condensed liquid increases the fuid saturation in the near-wellbore formation and, therefore, has the potential to decrease the gas relative permeability. 3 The accumulated condensate bank also changes the phase composition, which in turn reshapes the phase diagram and other properties of reservoir fuid. 4 Results from the case study 5–7 showed that the impact of condensate banking would be severe for these reservoirs if the physical processes expected in these reservoirs are not correctly modelled. Unlike others, paper 7 experimentally proved a signifcant improvement in gas relative permeability of the condensate reservoir even by injecting methanol, but one of the primary techniques the gas injection method is widely used to eliminate retrograde condensation or to prevent condensate banking in the formation. 8,9 Constant Composition Expansion (CCE) studies were conducted in the paper 10 to measure the retrograde liquid deposit data for a real reservoir fuid. Subsequently, the effect of adding light hydrocarbon gases on the vaporization of condensed liquid was studied. Results indicated that carbon dioxide (CO 2 ) extracts the condensed liquids in the near-wellbore region and, consequently, increases the productivity upon bringing the well back on-line. In our earlier works 1,11 modelled revalorization process of hydrocarbon condensate by injecting “dry natural gas” with different composition of carbon dioxide and nitrogen. It has been demonstrated that CO 2 gas mixture shows considerable promise as an injected “vaporizer”. In contrast, nitrogen has been shown to be unsuitable for the envisioned application. However, the use of N 2 may prove economically viable in certain circumstances and can be considered as a potential option to improve productivity. Generally, as it was re-confrmed in the papers 1,8 based on evidence that, maintaining gas condensate reservoir pressure above the RDP pressure of the reservoir fuid is the preferable method for gas- condensate reservoir development but according to the some other researches 4 confrmed that, it is possible to maintain reservoir pressure below the RDP pressure whilst reducing the reservoir pressure correspondently, as injected dry gas vaporizes both intermediate and some heavy hydrocarbons, decreases condensate/gas ratio and reduces the RDP pressure. Other facts which were provided in the works 12,13 proved that development of miscibility in gas cycling schemes may be achieved at pressures far below the dew-point pressure of the condensate by injection of CO 2 . The failure of low- miscibility pressure obtained for injection of CO 2 in a retrograde condensate suggests that mature condensate carrying formations may be suitable targets for CO 2 sequestration offset by a possible increase in condensate recovery. The experimental investigations of the natural gas-condensate systems at high pressures determine the existence of gas components well-soluble in hydrocarbon condensate in the initial composition of the formation gas results in the decrease of values of dew point and therefore the prolongation of the development period of the deposit in a single-phase gas regime. 14 Therefore, injected gas or “vaporiser” for gas cycling or re-vaporization of condensate from the core can be controlled for the purpose of increasing its solubility and gas- condensate well deliverability accordingly. 11,14 In point of fact, gas injection method is associated with complex thermodynamic processes or phase transitions, such as the re- Int J Petrochem Sci Eng. 2017;2(6):302‒308 302 © 2017 Fataliyev et al. This is an open access article distributed under the terms of the Creative Commons Attribution License, which permits unrestricted use, distribution, and build upon your work non-commercially. Effective “Vaporizer” for recovering retrograde hydrocarbon condensate from a gas-condensate reservoir Volume 2 Issue 6 - 2017 Vugar M Fataliyev, 1 Natig N Hamidov 2 1 National Academy of Sciences of Azerbaijan, Institute Oil and Gas, Azerbaijan 2 State Oil Company of Azerbaijan Republic (SOCAR), Institute Oil and Gas, Azerbaijan Correspondence: Vugar M Fataliyev, National Academy of Sciences of Azerbaijan, Institute Oil and Gas, Tel 994506834383, Email fatavm@bp.com Received: May 17, 2017 | Published: July 18, 2017 Abstract This paper investigates some fundamental aspects of a “vaporiser” for recovering trapped retrograde condensate in the formation that is formed during exploitation gas- condensate reservoirs in depletion regime. The thermodynamic test of seven different gas-condensate systems and analysis of the liquid and gas phase’s samples which were taken under the same thermobaric conditions was provided wide information about the occurrences in the reservoir fluids. It was identified that the solubility capability of gas mixture in the hydrocarbon condensate is elevated and improved as a “vaporiser” if it’s critical temperature is increased but compressibility factor and critical pressure are decreased. It was determined that, improving the solubility of gas components in the condensate decreases the system fog up and retrograde condensation pressures and improves stability of aerosol condition of gas-condensate fluid. Therefore, injected gas for gas cycling or re-vaporization of condensate from the core can be controlled for the purpose of increasing its solubility. Keywords: gas-condensate, gas injection, fog up pressure, gas solubility, gas solubility, dissolved gas International Journal of Petrochemical Science & Engineering Review article Open Access