Characteristics Curve of Multicontact for CO2 Flood

2013 ◽  
Vol 734-737 ◽  
pp. 1161-1164
Author(s):  
Ju Li ◽  
Chang Lin Liao ◽  
Shi Li
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Accurate Determination ◽  
Gas Injection ◽  
Design And Implementation ◽  
Recovery Techniques ◽  
Miscible Gas Injection ◽  
Successful Design

Miscible and/or near miscible CO2 flood are among the most widely used enhanced oil recovery techniques. The successful design and implementation of a miscible gas injection project is dependent upon the accurate determination of MMP[1]-[9], the pressure above which the displacement process becomes multicontact miscible. This paper presents a method to get the characteristics curve of multicontact. The curve can illustrate the character in the Miscible and/or near miscible gas injection processes, based the curve, From the change of characteristics curve of multicontact ,we can known the type of the displacement, and the influence of injection gas to the MMP.

Key Problems in the Calculation of Minimum Miscibility Pressure Based on Analytical Method

2011 ◽  
Vol 361-363 ◽  
pp. 516-519
Author(s):  
Ju Li ◽  
Xin Wei Liao ◽  
Su Kun
Keyword(s):  
Oil Recovery ◽  
Accurate Determination ◽  
Gas Injection ◽  
Analytical Calculation ◽  
Minimum Miscibility Pressure ◽  
Recovery Techniques ◽  
Miscible Gas Injection ◽  
Tie Lines ◽  
Successful Design ◽  
Complete Set

Miscible and/or near miscible gas injection processes are among the most widely used enhanced oil recovery techniques. The successful design and implementation of a miscible gas injection project is dependent upon the accurate determination of minimum miscible pressure (MMP), the pressure above which the displacement process becomes multi-contact miscible. Analytical methods, which are inexpensive and quick to use, have been developed to estimate MMP for complex fluid characterizations. However, many problems still existed in the analytical calculation, which will lead to the failure of calculation, or wrong result. This paper shows how the initial tie line could be calculated when the component of injection gas doesn’t included in the crude oil. And moreover, how to get a complete set of initial value for the equations of crossover tie lines, and the influence of EOS for the result of key tie lines is analyzed simultaneously.

scholarly journals A New Predictive Method for CO2-Oil Minimum Miscibility Pressure

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-8
Author(s):  
Dangke Ge ◽  
Haiying Cheng ◽  
Mingjun Cai ◽  
Yang Zhang ◽  
Peng Dong
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Accurate Determination ◽  
Contact Process ◽  
Gas Injection ◽  
New Model ◽  
Cell Method ◽  
Minimum Miscibility Pressure ◽  
Miscible Gas Injection ◽  
Tie Lines

Gas injection processes are among the effective methods for enhanced oil recovery. Miscible and/or near miscible gas injection processes are among the most widely used enhanced oil recovery techniques. The successful design and implementation of a miscible gas injection project are dependent upon the accurate determination of minimum miscibility pressure (MMP), the pressure above which the displacement process becomes multiple-contact miscible. This paper presents a method to get the characteristic curve of multiple-contact. The curve can illustrate the character in the miscible and/or near miscible gas injection processes. Based on the curve, we suggest a new model to make an accurate prediction for CO2-oil MMP. Unlike the method of characteristic (MOC) theory and the mixing-cell method, which have to find the key tie lines, our method removes the need to locate the key tie lines that in many cases is hard to find a unique set. Moreover, unlike the traditional correlation, our method considers the influence of multiple-contact. The new model combines the multiple-contact process with the main factors (reservoir temperature, oil composition) affecting CO2-oil MMP. This makes it is more practical than the MOC and mixing-cell method, and more accurate than traditional correlation. The method proposed in this paper is used to predict CO2-oil MMP of 5 samples of crude oil in China. The samples come from different oil fields, and the injected gas is pure CO2. The prediction results show that, compared with the slim-tube experiment method, the prediction error of this method for CO2-oil MMP is within 2%.

Applicability of Enhanced Oil Recovery techniques on mature fields - Interest of gas injection

2005 ◽  
Author(s):  
Frederic Maubeuge ◽  
Danielle Christine Morel ◽  
Jean-Pierre Charles Fossey ◽  
Said Hunedi ◽  
Jacques Albert Danquigny
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Gas Injection ◽  
Recovery Techniques

scholarly journals Thermal Stability and Compatibility of Surfactants in Presence of Formation Water Salinity under Reservoir Conditions

2020 ◽  
Vol 39 (4) ◽  
pp. 826-830
Author(s):  
Muhammad Khan Memon ◽  
Ubedullah Ansari ◽  
Habib U Zaman Memon
Keyword(s):  
Thermal Stability ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Gas Injection ◽  
Surfactant Solution ◽  
Water Salinity ◽  
Formation Water ◽  
Reservoir Temperature ◽  
Gas Mobility ◽  
Formation Water Salinity

In the surfactant alternating gas injection, the injected surfactant slug is remained several days under reservoir temperature and salinity conditions. As reservoir temperature is always greater than surface temperature. Therefore, thermal stability of selected surfactants use in the oil industry is almost important for achieving their long-term efficiency. The study deals with the screening of individual and blended surfactants for the applications of enhanced oil recovery that control the gas mobility during the surfactant alternating gas injection. The objective is to check the surfactant compatibility in the presence of formation water under reservoir temperature of 90oC and 120oC. The effects of temperature and salinity on used surfactant solutions were investigated. Anionic surfactant Alpha Olefin Sulfonate (AOSC14-16) and Internal Olefin Sulfonate (IOSC15-18) were selected as primary surfactants. Thermal stability test of AOSC14-16 with different formation water salinity was tested at 90oC and 120oC. Experimental result shows that, no precipitation was observed by surfactant AOSC14-16 when tested with different salinity at 90oC and 120oC. Addition of amphoteric surfactant Lauramidopropylamide Oxide (LMDO) with AOSC14-16 improves the stability in the high percentage of salinity at same temperature, whereas, the surfactant blend of IOSC15-18 and Alcohol Aloxy Sulphate (AAS) was resulted unstable. The solubility and chemical stability at high temperature and high salinity condition is improved by the blend of AOSC14-16+LMDO surfactant solution. This blend of surfactant solution will help for generating stable foam for gas mobility control in the methods of chemical Enhanced Oil Recovery (EOR).

Sign in / Sign up

Export Citation Format

Share Document