Improvement of approaches for calculating the PVT properties of reservoir fluids of oil and gas, oil-gas-condensate and gas-condensate deposits on the territory of the activity of RN-Purneftegas LLC

2021 ◽  
pp. 92-96
Author(s):  
T.A. Ishmuratov ◽  
◽  
A.I. Khamidullina ◽  
R.R. Islamov ◽  
A.A. Khisamov ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Gas Condensate ◽  
Gas Oil ◽  
Pvt Properties ◽  
Oil Gas

Variations of Gas/Condensate Relative Permeability With Production Rate at Near-Wellbore Conditions: A General Correlation

2006 ◽  
Vol 9 (06) ◽  
pp. 688-697 ◽  
Author(s):  
Mahmoud Jamiolahmady ◽  
Ali Danesh ◽  
D.H. Tehrani ◽  
Mehran Sohrabi
Keyword(s):  
Relative Permeability ◽  
Oil And Gas ◽  
Coupling Effect ◽  
Flow Behavior ◽  
Accurate Determination ◽  
Gas Condensate ◽  
Gas Oil ◽  
Fractional Flow ◽  
General Correlation ◽  
Fluid Saturation

Summary It has been demonstrated, first by this laboratory and subsequently by other researchers, that the gas and condensate relative permeability can increase significantly by increasing rate, contrary to the common understanding. There are now a number of correlations in the literature and commercial reservoir simulators accounting for the positive effect of coupling and the negative effect of inertia at near-wellbore conditions. The available functional forms estimate the two effects separately and include a number of parameters, which should be determined with measurements at high-velocity conditions. Measurements of gas/condensate relative permeability at simulated near-wellbore conditions are very demanding and expensive. Recent experimental findings in this laboratory indicate that measured gas/condensate relative permeability values on cores with different characteristics become more similar if expressed in terms of fractional flow instead of the commonly used saturation. This would lower the number of rock curves required in reservoir studies. Hence, we have used a large data bank of gas/condensate relative permeability measurements to develop a general correlation accounting for the combined effect of coupling and inertia as a function of fractional flow. The parameters of the new correlation are either universal, applicable to all types of rocks, or can be determined from commonly measured petrophysical data. The developed correlation has been evaluated by comparing its prediction with the gas/condensate relative permeability values measured at near-wellbore conditions on reservoir rocks not used in its development. The results are quite satisfactory, confirming that the correlation can provide reliable information on variations of relative permeability at near-wellbore conditions with no requirement for expensive measurements. Introduction The process of condensation around the wellbore in a gas/condensate reservoir, when the pressure falls below the dewpoint, creates a region in which both gas and condensate phases flow. The flow behavior in this region is controlled by the viscous, capillary, and inertial forces. This, along with the presence of condensate in all the pores, dictates a flow mechanism that is different from that of gas/oil and gas/condensate in the bulk of the reservoir (Danesh et al. 1989). Accurate determination of gas/condensate relative permeability (kr) values, which is very important in well-deliverability estimates, is a major challenge and requires an approach different from that for conventional gas/oil systems. It has been widely accepted that relative permeability (kr) values at low values of interfacial tension (IFT) are strong functions of IFT as well as fluid saturation (Bardon and Longeron 1980; Asar and Handy 1988; Haniff and Ali 1990; Munkerud 1995). Danesh et al. (1994) were first to report the improvement of the relative permeability of condensing systems owing to an increase in velocity as well as that caused by a reduction in IFT. This flow behavior, referred to as the positive coupling effect, was subsequently confirmed experimentally by other investigators (Henderson et al. 1995, 1996; Ali et al. 1997; Blom et al. 1997). Jamiolahmady et al. (2000) were first to study the positive coupling effect mechanistically capturing the competition of viscous and capillary forces at the pore level, where there is simultaneous flow of the two phases with intermittent opening and closure of the gas passage by condensate. Jamiolahmady et al. (2003) developed a steady-dynamic network model capturing this flow behavior and predicted some kr values, which were quantitatively comparable with the experimentally measured values.

The Development and Technology Policy for a Gas Cap and Edge Water Reservoir with Narrow Oil Ring

2014 ◽  
Vol 962-965 ◽  
pp. 500-505
Author(s):  
He Hua Wang ◽  
Ling Wu ◽  
Ting Ting Feng ◽  
Yuan Sheng Li ◽  
Jian Yang
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Technology Policy ◽  
Water Reservoir ◽  
Gas Oil ◽  
Gas Distribution ◽  
Oil Water ◽  
Oil Productivity ◽  
Oil Gas

Reservoir with gas cap, edge water is complex. And the oil-water and oil-gas interface will seriously influence the performance. Once out of control, gas and water invasion may occur, then oil productivity will fall sharply and oil recovery will become low. In addition, the oil penetrating into gas cap would lead to oil loss. So, the controlling methods are crucial. In this paper, we study the productive characteristics of a certain reservoir with gas cap, edge water and narrow oil ring. For the phenomenon several productive wells appeared gas breakthrough and water invasion after putting into production, this paper puts up a strategy shutting in high gas-oil ratio wells and blocking off gas breakthrough layers that proved effective. At the same time, adjusting oil and gas distribution underground by gas-water alternate also be proved practicable.

scholarly journals Interconnection of FSES HE on 21.03.01 “Oil and Gas Business” and Professional Standard “Specialist in Production of Oil, Gas and Gas Condensate” on the Example of Implementation Disciplines

2020 ◽  
Vol 6 (9) ◽  
pp. 401-407
Author(s):  
I. Kvach ◽  
S. Kvach
Keyword(s):  
Higher Education ◽  
Oil And Gas ◽  
Professional Competence ◽  
Oil And Gas Industry ◽  
Gas Condensate ◽  
Professional Activity ◽  
Russian Society ◽  
Technological Equipment ◽  
Professional Standard ◽  
Oil Gas

The article makes an attempt to analyze the situation in the labor market in modern Russian society in connection with new conditions, rapidly changing technologies, digitalization of all production and management processes, and what awaits a university graduate in a new labor reality. The article deals with the issue of conjugation of federal educational standards of higher education of generation 3++ and professional standards in the implementation of bachelor’s programs. The study is based on the example of interfacing FSES HE 21.03.01 “Oil and Gas Business” and the professional standard “Specialist in oil, gas and gas condensate production” in the context of the implementation of disciplines Technological equipment of the oil and gas industry and Maintenance and repair of oilfield equipment and the formation of professional competence: able to carry out work for diagnostics, maintenance, repair and operation of technological equipment in accordance with the chosen field of professional activity at the Yugra State University. The positive aspects of the interface between PS and FSES of HE in the implementation of educational programs of higher education, the difficulties arising on the way of this process and possible solutions are noted.

scholarly journals Features of the brine water composition of the Vendian - Lower Cambrian Middle Botuoba oil-gas-condensate field during the catagenesis time

2020 ◽  
Vol 15 (3) ◽  
Author(s):  
N.F. Chistyakova ◽  
◽  
V.V. Dravante ◽  
A.I. Sivtsev ◽  
◽  
...  
Keyword(s):  
Chemical Composition ◽  
Lower Cambrian ◽  
Oil And Gas ◽  
Salt Water ◽  
Water System ◽  
Gas Condensate ◽  
Artesian Basin ◽  
Water Composition ◽  
Genetic Types ◽  
Oil Gas

The salt water omposition of underground brines of the Vendian - Lower Cambrian sections of the Middle Botuoba oil-gas-condensate field during the catagenesis stage is considered; the peculiarity of which is the presence of polygenic waters in certain block traps of B5 and Б1 levels: sodium sulfate, sodium hydrogencarbonate and chlorine-magnesium genetic types together with the prevailing chlorine-calcium genetic type. The zoning of the groundwater of the strata by mineralization and four genetic types of groundwater has been carried out. The directions of water entry into the reservoirs formed at the stage of catagenesis and entering together with hydrocarbons in the corresponding traps are established. It is shown that, while maintaining the mechanism of formation of the salt water composition in the "rock-water" system, the polygenicity of the formation waters present simultaneously in one reservoir layer reflects a regular change in the components of their chemical composition during the transition from the artesian basin to the oil and gas basin. The most sensitive ions of the chemical composition of groundwater, reflecting the transition of the artesian basin to the new geological state of the catagenesis stage, are sulfate, bicarbonate, and sodium ions.

scholarly journals About Relations between Natural Gas and Oil in Connection with Forecast of Their Reserves in Azerbaijan

2021 ◽  
Vol 5 (4) ◽  
pp. 288-296
Author(s):  
A. A. Feizullaev
Keyword(s):  
Natural Gas ◽  
Oil And Gas ◽  
Gas Condensate ◽  
The Other ◽  
Gas Oil ◽  
Oil Reserves ◽  
Ratio Data ◽  
The World ◽  
Deepwater Part ◽  
Deep Water Part

Azerbaijan is one of the oldest oil and gas provinces, where more than 2 bln tons of oil have been extracted over more than a century. At present, the oil production is declining and mainly determined by production from the Azeri-Chirag-Guneshli offshore block (AChG). Compared to oil, the opportunities for further growing natural gas reserves and production are very promising. For the latest years, a number of large gas condensate fields have been discovered in the deep-water part of South Caspian Sea, such as Shakh-Deniz, Apsheron, Umid. There are a number of prospects that have not yet been drilled in this part of the sea basin. The paper assesses their prospectivity, substantiates the priority exploration targets and, on the basis of the statistical analysis of the quantitative gas/oil ratio data for many other Azerbaijanian and world basins, an attempt is made to assess the reserves in the prospects. The total recoverable oil reserves in Azerbaijan are estimated at 3.5 bln tons, of which slightly above 2 bln tons have already been extracted. Based on the statistically estimated ratio between the volumes of gas and oil in various basins of the world, including Azerbaijan, the total possible natural gas reserves in Azerbaijan are estimated at about 4 trillion m3 . This is in agreement with the other available estimates. Of this volume of natural gas, 0.85 trillion m3 has already been extracted, and the approved geological reserves are estimated at 2.55 trillion m3 . Almost 83% of the extracted natural gas belonged to offshore fields. This trend will continue in the future, and, moreover, will be strengthened due to large volumes of gas condensate accumulations in the deepwater part of the basin. In this part of the basin, the most attractive prospects are Mashal, Shafag, and Israfil Huseynov, total reserves of which are expected at 0.6 trillion m3 of natural gas.

Application of multi-stage hydraulic fracturing in the development of Achimov sediments at the Urengoy oil and gas condensate field

2020 ◽  
pp. 38-48
Author(s):  
E. V. Panikarovskii ◽  
V. V. Panikarovskii ◽  
M. M. Mansurova ◽  
M. V. Listak
Keyword(s):  
Hydraulic Fracturing ◽  
Oil And Gas ◽  
Gas Condensate ◽  
Hydraulic Fractures ◽  
High Permeability ◽  
Main Method ◽  
Reservoir Rocks ◽  
New Methods ◽  
Multi Stage ◽  
Oil Gas

The development of deep-lying Achimov deposits makes it possible to extract additional volumes of gas and gas condensate in the fields with decreasing production, as well as implement strategies to introduce new methods to increase oil, gas and condensate production. The decrease in well productivity during the development of gas condensate fields requires the use of new methods of intensification of production. The main method for increasing the productivity of Achimov wells is hydraulic fracturing. The choice of hydraulic fracturing technology for low-permeability Achimov deposits is especially important for creating large hydraulic fractures and high permeability, as well as maintaining the filtration characteristics of reservoir rocks. Multi-stage hydraulic fracturing is the most effective method of intensifying gas and gas condensate production in the development of the Achimov deposits.

Numerical Simulation of Pressure Limits of Gas Storage in North Area of Lamadian Oilfield

2012 ◽  
Vol 229-231 ◽  
pp. 2073-2076
Author(s):  
Dai Yin Yin ◽  
Jian Xin Lu ◽  
Shuai Wang ◽  
Cheng Li Zhang
Keyword(s):  
Numerical Simulation ◽  
Oil And Gas ◽  
Gas Storage ◽  
Simulation Software ◽  
Geological Model ◽  
Gas Oil ◽  
Practical Project ◽  
Production Cycles ◽  
Simulation Results ◽  
Oil Gas

In order to grasp the change of oil-gas interface in north area of Lamadian Oilfield and determine the conditions of gas or oil invasion during the development of gas storage, the precise geological model is established. By simulation software Eclipse immigrations of gas-oil interface are tracing simulated and cases of gas or oil invasion are monitored under various pressure differentials, based on which the limits of pressure are provided at last. Simulation results indicate that when the pressure of gas region is higher than oil region the gas invasion will happen and when the pressure differential between oil and gas region is up to 0.6 MPa the oil invasion will happen after 16 injection-production cycles. This paper is valuable to practical project applications which keep the interface stable and avoid the gas and oil invasions.

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