Analyzing Methods of Determining the Residual Oil and Gas Saturation Factor in Cased Wells

2021 ◽  
pp. 107-113
Author(s):  
Denis SIZOV ◽  
Alexander VDOVKIN
Keyword(s):  
Oil And Gas ◽  
Residual Oil ◽  
Gas Saturation ◽  
Saturation Factor

STUDY OT THE INFLUENCE OT RESIDUAL OIL ON CONDENSATE LOSSES AT SREDNEBOTUOBINSKIY OIL AND GAS CONDENSATE FIELD

2021 ◽  
pp. 39-52
Author(s):  
Ekaterina Ivanovna Inyakina ◽  
Rozalia Kirillovna Katanova ◽  
Vladislav Vitalevich Inyakin ◽  
Mohammed Jawad Zeinalabideen Alsheikhly
Keyword(s):  
Oil And Gas ◽  
Gas Condensate ◽  
Residual Oil

AN EXPERIMENTAL INVESTIGATION OF FACTORS AFFECTING ELASTIC WAVE VELOCITIES IN POROUS MEDIA

Geophysics ◽  
1958 ◽  
Vol 23 (3) ◽  
pp. 459-493 ◽  
Author(s):  
M. R. J. Wyllie ◽  
A. R. Gregory ◽  
G. H. F. Gardner
Keyword(s):  
Experimental Investigation ◽  
Porous Media ◽  
Oil And Gas ◽  
Velocity Data ◽  
Velocity Measurements ◽  
Factors Affecting ◽  
Gas Saturation ◽  
Wave Velocities ◽  
Time Average ◽  
Made In

An experimental investigation has been made of the factors which affect the velocity of vibratory signals in porous media. It is shown from the results of experiments carried out on appropriate natural and synthetic porous systems that the time‐average formula previously suggested by Wyllie, Gregory, and L. W. Gardner is of considerable utility. This formula states that [Formula: see text] where [Formula: see text] measured, [Formula: see text] in saturating liquid, [Formula: see text] in rock solid, and ϕ=volumetric porosity fraction. The effects are examined of differential compacting pressures on the applicability of this formula to consolidated and unconsolidated rocks. It is shown that the time‐average relationship cannot be applied to determine the total volumetric porosity of carbonate rocks which are vugular and fractured. In such rocks, paradoxically, this circumstance may be advantageous because of the lithological information that may be obtained from an appropriate combination of velocity and nuclear log data. The effects of oil and gas saturation on velocity have been examined experimentally and are found to be comparatively minor. The combination of velocity data with information from electric logs in order to locate zones of oil and gas saturation is shown to be generally valuable; this is particularly so when holes are drilled with oil‐base mud. Some discussion is given of the possible effects on velocity measurements of the relative wettability of rock surfaces by various liquids. Owing to instrumental limitations, it cannot necessarily be assumed that measurements made in the laboratory are directly applicable to the interpretation of velocity data obtained under field conditions.

scholarly journals ZONALITY OF WATER-DDISSOLVED GASES IN THE OIL-AND-GAS BEARING SEDIMENTS OF THE NADYM-TAZ INTERFLUVE

2019 ◽  
Vol 2 (1) ◽  
pp. 133-140
Author(s):  
Dmitry Novikov
Keyword(s):  
Middle Jurassic ◽  
Oil And Gas ◽  
Dissolved Gases ◽  
Gas Saturation ◽  
Oil Deposits ◽  
Gas Bearing

The results presented in the work were obtained in the studies of the features and zonality of water-dissolved gases within the boundaries of the oil-and-gas bearing sediments of the Nadym-Taz interfluve. Methane-containing waters with total gas saturation from 0.3 to 5.7 l/l and average CH4 content from 95.5 vol.% in the Aptian-Albian-Senomanian complex to 83.3 vol.% in the Lower and Middle Jurassic complex are developed in the region. With an increase in the depth, an increase in the content of homologues ΣHС (C2H6, C3H8, C4H10, C5H12 and C6H14) occurs from 1.34 vol.% in the Aptian_Albian-Senomanian complex to 11.67 vol.% in the Lower and Middle Jurassic complex. The maximal concentrations of ΣHС up to 30 vol.% were revealed in the lower part of the Neocomian complex in the marginal waters of oil deposits. An increase in CO2 content and a regular decrease in the ΣHС/N2 ratio from 96 in the Aptian-Albian-Senomanian complex to 52 in the Lower and Middle Jurassic complex are observed with an increase in the depth.

scholarly journals Integrated Expert Analytical System for Assessment of Oil-and-Gas Saturation of Strata

2014 ◽  
Vol 05 (04) ◽  
pp. 224-232
Author(s):  
O. G. Nusratov ◽  
G. G. Abdullayeva ◽  
I. A. Ismayilov
Keyword(s):  
Oil And Gas ◽  
Gas Saturation ◽  
Analytical System

scholarly journals Carbonate oil and gas source rocks wettability alteration due to influence of polymer-colloidal drilling mud

2021 ◽  
pp. 17-27
Author(s):  
N. A. Skibitskaya ◽  
◽  
I. O. Burkhanova ◽  
M. N. Bolshakov ◽  
V. A. Kuzmin ◽  
...  
Keyword(s):  
Surface Properties ◽  
Oil And Gas ◽  
Pore Space ◽  
Space Structure ◽  
Source Rocks ◽  
Wettability Alteration ◽  
Drilling Mud ◽  
Rock Samples ◽  
Gas Saturation ◽  
Gas Source

Evaluation of rock wettability is an important task, since this parameter determines the distribution of water and oil in the reservoirs and their relative and phase permeability. The reliability of evaluation the wettability of rock samples depends on the drilling-in conditions during core sampling and core sample preparation methods. The investigation of the surface properties of the core from the Orenburg oil and gas condensate field showed that using of polymer-colloidal drilling mud leads to hydrophilization of the samples' surface. To obtain information on the actual wettability values of rock samples taken from wells drilled with polymer-colloidal drilling mud a method for estimating the relative (predominant) wettability of rocks based on petrophysical and lithological studies data is proposed. The authors suggest that the extraction of oil and gas source rock samples leads to irreversible changes in surface properties that cannot be restored. Keywords: selective wettability; relative wettability; predominant wettability; polymer-colloidal drilling mud; residual gas saturation; trapped gas saturation; pore space structure; extraction.

Classification of residual oil reserves and methods of its recovery

2021 ◽  
pp. 26-33
Author(s):  
D.Yu. Chudinova ◽  
◽  
Y.D.B. Atse ◽  
R.M. Minniakhmetova ◽  
M.Yu. Kotenev ◽  
...  
Keyword(s):  
Late Stage ◽  
Oil And Gas ◽  
Residual Oil ◽  
Oil Reserves ◽  
Oil And Gas Fields ◽  
Stage Of Development ◽  
Distribution Studies ◽  
Water Cut ◽  
Gas Fields ◽  
Technical Measures

Many oil and gas fields are currently at a late stage of development, while most of them are being developed using flooding. These fields are characterized by the decreasing oil and liquid flow rates and accelerating water-cut. During the development process, the majority of oil reserves are extracted not using methods of production enhancement. Though, oil reserves within undeveloped areas are a valuable source for recovery. To involve residual reserves in active development, it is necessary to make a reasonable justification and a choice of the most effective geological and technical measures that take into account various geological field and well reservoir characteristics. Residual oil reserves at the late stage of development are classified as hard-to-recover and are mainly concentrated in areas not covered by flooding laterally and vertically. They belong to various categories that differ in the geological and technological characteristics. In this regard, it is necessary to plan various geological and technical measures taking into account the structure of residual reserves and patterns of their distribution. Studies of complex oil and gas fields were performed and a detailed analysis of the geological and physical characteristics, parameters of reservoir heterogeneity along with operational, geological and commercial assessment of reserves development were conducted.

Three-Phase Imbibition Relative Permeability

10.2118/90-pa ◽  
1961 ◽  
Vol 1 (04) ◽  
pp. 254-258 ◽  
Author(s):  
J. Naar ◽  
R.J. Wygal
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Water Flooding ◽  
Pressure Curve ◽  
Complete Wetting ◽  
Oil Saturation ◽  
Gas Saturation ◽  
Three Phase ◽  
Oil Gas ◽  
Wetting Fluid

Abstract An equation for three-phase (water, oil, gas) imbibition oil permeability is developed, assuming the water to be the dominant wetting fluid. Oil isoperms are obtained for consolidated sandstones characterized by. The evolution of an oil-gas system imbibing water from is shown to proceed along a line of constant oil saturation with increasing oil permeability and decreasing gas saturations. When the gas saturation cannot be reduced further, the system evolves along a line of constant with decreasing oil saturation and permeability. The initial gas saturation is shown to reduce markedly the effect of complete wetting by either oil or water on flow performance. Introduction Imbibition oil isoperms are required for performance prediction when a well is producing water, oil and gas. This situation occurs in multiphase displacements such as underground combustion, steam injection and the water flooding of highly depleted reservoirs. In a recent paper, a model was presented for the prediction of two-phase imbibition characteristics. This paper extends the imbibition model to the case of three phases by assuming that the water is the dominant wetting fluid. The following results were obtained from the model:an analytical expression of oil isoperms;oil isoperms as functions of reduced water, oil and gas saturations, valid for all sandstones having a capillary pressure curve which can be approximated by; andevaluation of the three-phase flow performance as dictated by complete wetting by either oil or water. The agreement between predicted and observed oil recovery in the presence of a gas phase, reported in Ref. 1, is a partial support for the present development. However, experimental data are not available at this time to check fully the model predictions. Perhaps this paper will stimulate the collection of such data. THEORETICAL The imbibition model of a porous medium has been described previously, and the reader is referred to the paper of Naar and Henderson for details. In brief, the model is formed by the random interconnection of straight capillaries, with a provision for the blocking of the non-wetting phase by the invading wetting fluid.

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