Effect of Pore Fluid Type on Perforation Damage and Flow Characteristics

2001 ◽  
Author(s):  
C. Ozgen Karacan ◽  
Abraham S. Grader ◽  
Phillip M. Halleck
Keyword(s):  
Flow Characteristics ◽  
Pore Fluid ◽  
Fluid Type

Lithology discrimination for thin layers using wavelet signal parameters

Geophysics ◽  
1988 ◽  
Vol 53 (12) ◽  
pp. 1512-1519 ◽  
Author(s):  
James N. Lange ◽  
H. A. Almoghrabi
Keyword(s):  
Thin Layer ◽  
Frequency Domain ◽  
Prior Knowledge ◽  
Characteristic Frequency ◽  
Forward Modeling ◽  
Pore Fluid ◽  
Thin Layers ◽  
Modeling Technique ◽  
Fluid Type ◽  
Signal Parameters

A forward modeling technique using Ricker wavelets demonstrates the need for a multiparameter approach in lithology determination using reflections from thin layers. The combination of time‐ and frequency‐domain analyses leads to a set of algorithms which define pore fluid and lithology from wavelet characteristics. The dispersive behavior of the thin layer varies considerably with the environment surrounding the layer, resulting in characteristic frequency‐domain behavior. With a limited prior knowledge of the formation environment, the pore fluid type can be determined using mode‐converted waves in the frequency domain.

Reply by the authors to M. K. Sengupta

Geophysics ◽  
1989 ◽  
Vol 54 (6) ◽  
pp. 789-789
Author(s):  
James N. Lange ◽  
Hamzah A. Almoghrabi
Keyword(s):  
Frequency Domain ◽  
Pore Fluid ◽  
Thin Layers ◽  
P Wave ◽  
Wave Frequency ◽  
Fluid Type ◽  
S Wave ◽  
S Waves ◽  
Domain Information

The method presented in M. Sengupta’s patent provides a means of displaying both frequency and offset information necessary to evaluate the response of thin layers. Although it is developed to view P‐wave behavior, an adaptation of the technique might provide frequency‐domain information on mode‐converted S‐waves. Comparison of the P‐wave and mode‐converted S‐wave frequency‐domain behaviors yields important information on the lithology and pore‐fluid type of thin layers, as shown in Figure 11 of our paper.

On: “Lithology discrimination for thin layers using wavelet signal parameters” by J. N. Lange and H. A. Almoghrabi (GEOPHYSICS, 53, 1512–1519, December 1988).

Geophysics ◽  
1989 ◽  
Vol 54 (6) ◽  
pp. 789-789 ◽  
Author(s):  
M. K. Sengupta
Keyword(s):  
Pore Fluid ◽  
Thin Layers ◽  
Fluid Type ◽  
Frequency Dependent ◽  
Signal Parameters

Lange and Almoghrabi have shown correctly that seismic frequency is an important parameter for discriminating among seismic lithologies and pore‐fluid types for thin layers. I would like to draw attention to Figure 3 of this paper and to the last paragraph of their conclusions, which state, “The crux of the multiparameter algorithms…is the thin layer’s frequency‐dependent reflectivity, which can be used to discriminate reflector lithologies and pore fluid type.”

Time-average equation revisited

Geophysics ◽  
1998 ◽  
Vol 63 (2) ◽  
pp. 460-464 ◽  
Author(s):  
Jack Dvorkin ◽  
Amos Nur
Keyword(s):  
Solid Phase ◽  
Rock Physics ◽  
Pore Fluid ◽  
P Wave ◽  
Well Logs ◽  
Fluid Type ◽  
Wave Velocities ◽  
P Wave Velocity ◽  
Solid Phase Material

Expressions that relate velocity to porosity and to pore-fluid compressibility are among the most important deliverables of rock physics. Such relations are used often as additional controls for inferring porosity from well logs, as well as in-situ indicators of pore fluid type. The oldest and most popular is the Wyllie et al. (1956) equation: [Formula: see text]where [Formula: see text] is the measured traveltime of a P-wave, [Formula: see text] is the traveltime expected in the solid-phase material, and [Formula: see text] is the traveltime expected in the pore fluid. It follows from equation (1) that [Formula: see text]where ϕ is porosity, [Formula: see text] is the measured P-wave velocity, and [Formula: see text] and [Formula: see text] are the P-wave velocities in the solid and in the pore-fluid phases, respectively.

scholarly journals Using Elastic Properties as a Predictive Tool to Identify Pore-Fluid Type in Carbonate Formations

2019 ◽  
Vol 20 (1) ◽  
pp. 53-64
Author(s):  
Mahmoud Jasim Al-Khafaji ◽  
Wafaa’ Mustafa Al-Kattan
Keyword(s):  
Bulk Modulus ◽  
Elastic Properties ◽  
Middle Eastern ◽  
Pore Fluid ◽  
Carbonate Reservoir ◽  
High Porosity ◽  
Fluid Type ◽  
Predictive Tool ◽  
Depth Level ◽  
Sonic Log

The aim of this study is for testing the applicability of Ramamoorthy and Murphy method for identification of predominant pore fluid type, in Middle Eastern carbonate reservoir, by analyzing the dynamic elastic properties derived from the sonic log. and involving the results of Souder, for testing the same method in chalk reservoir in the North Sea region. Mishrif formation in Garraf oilfield in southern Iraq was handled in this study, utilizing a slightly-deviated well data, these data include open-hole full-set logs, where, the sonic log composed of shear and compression modes, and geologic description to check the results. The Geolog software is used to make the conventional interpretation of porosity, lithology, and saturation. Also, include PVT and water analyses as inputs in Batzle and Wang correlations in order to calculate mechanical properties of oil and water at reservoir conditions. The shear velocity and density logs are used to calculate the shear modulus (G), for each (0.1254) meter.  The dry frame bulk modulus correlation of the original method was not followed, instead, a new dry frame bulk modulus correlation of Saxena is used to avoid the uncertainty in the porosity type exist in the formation which needs special core description. Then, Gassmann’s equations were used to determine the bulk moduli of the rock assuming two saturation conditions; the first is 100% water saturated, and the second is 100% oil saturated.  Using elastic properties equations of Love’s, and the resulted bulk moduli, two corresponding ∆t(s), (for oil and for water), were computed for each depth level. Then these ∆t(s) were plotted with sonic ∆t in the same track, and compiled with the conventional log interpretation, to compare the results. The method was a good indicator of the fluid type in the high porosity zones, unlike for the tight or clay-rich zones. The results are very conformable to the conventional interpretation, the OWC in both model and conventional interpretation are so close with error percentage of (0.03%).

Effect of hydrodynamic impact and cavitation on oil flow characteristics

2019 ◽  
pp. 46-50
Author(s):  
V.N. Petrov ◽  
◽  
F.M. Galimov ◽  
L.A. Akhmetzyanova ◽  
S.V. Petrov ◽  
...  
Keyword(s):  
Flow Characteristics ◽  
Hydrodynamic Impact ◽  
Oil Flow
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