Critical entry pressure of a droplet pinning over multitude of pore openings

2021 ◽  
Vol 33 (3) ◽  
pp. 032114
Author(s):  
Amgad Salama
Keyword(s):  
Entry Pressure

Entry pressure correlations in capillary flow

2020 ◽  
Vol 32 (7) ◽  
pp. 073106
Author(s):  
Ziyue Zhang ◽  
Savvas G. Hatzikiriakos
Keyword(s):  
Capillary Flow ◽  
Entry Pressure

scholarly journals Capillary processes increase salt precipitation during CO2 injection in saline formations

2018 ◽  
Vol 852 ◽  
pp. 398-421
Author(s):  
Helena L. Kelly ◽  
Simon A. Mathias
Keyword(s):  
High Salinity ◽  
Volume Fraction ◽  
Injection Rate ◽  
Injection Well ◽  
Co2 Injection ◽  
Salt Precipitation ◽  
Injection Wells ◽  
Tenfold Increase ◽  
Entry Pressure ◽  
Injection Rates

An important attraction of saline formations for CO2 storage is that their high salinity renders their associated brine unlikely to be identified as a potential water resource in the future. However, high salinity can lead to dissolved salt precipitating around injection wells, resulting in loss of injectivity and well deterioration. Earlier numerical simulations have revealed that salt precipitation becomes more problematic at lower injection rates. This article presents a new similarity solution, which is used to study the relationship between capillary pressure and salt precipitation around CO2 injection wells in saline formations. Mathematical analysis reveals that the process is strongly controlled by a dimensionless capillary number, which represents the ratio of the CO2 injection rate to the product of the CO2 mobility and air-entry pressure of the porous medium. Low injection rates lead to low capillary numbers, which in turn are found to lead to large volume fractions of precipitated salt around the injection well. For one example studied, reducing the CO2 injection rate by 94 % led to a tenfold increase in the volume fraction of precipitated salt around the injection well.

scholarly journals Effects of Irreducible Fluid Saturation and Gas Entry Pressure on Gas Production from Hydrate-Bearing Clayey Silt Sediments by Depressurization

Geofluids ◽  
2020 ◽  
Vol 2020 ◽  
pp. 1-20
Author(s):  
Xiaolong Ma ◽  
Youhong Sun ◽  
Wei Guo ◽  
Rui Jia ◽  
Bing Li
Keyword(s):  
Water Saturation ◽  
Gas Production ◽  
Production Volume ◽  
Water Production ◽  
Shenhu Area ◽  
Gas Saturation ◽  
Fluid Saturation ◽  
Entry Pressure ◽  
Clayey Silt ◽  
Irreducible Water Saturation

Gas hydrates in the Shenhu area are mainly hosted in clayey silt sediments, which have the relatively high irreducible fluid saturation and gas entry pressure. And then, they will have an impact on gas production from hydrate-bearing clayey silt sediments, which was evaluated by the numerical simulations of SH2 site in Shenhu area in this paper. The results showed that, with the increase in irreducible water saturation and irreducible gas saturation, the amount of water production and gas production was obviously reduced. When the irreducible water saturation increased from 0.10 to 0.50, the cumulative CH4 production volume decreased from 1668799 m3 to 1536262 m3, and the cumulative water production volume dropped from 620304 m3 to 564797 m3, respectively. When the irreducible gas saturation increased from 0.01 to 0.05, the cumulative CH4 production volume dropped from 1812522 m3 to 1622121 m3, and the cumulative water production volume dropped from 672088 m3 to 600617 m3, respectively. In addition, the capillary pressure increased obviously with the increase in gas entry pressure, but the effect on gas production was small and the effect on water production could be negligible. In conclusion, irreducible water and gas saturation had an important effect on the gas production from gas hydrate, whereas the effects of gas entry pressure could be ignored.

scholarly journals Validation and analysis procedures for juxtaposition and membrane fault seals in oil and gas exploration

2019 ◽  
Vol 496 (1) ◽  
pp. 145-161 ◽  
Author(s):  
Titus A. Murray ◽  
William L. Power ◽  
Anthony J. Johnson ◽  
Greg J. Christie ◽  
David R. Richards
Keyword(s):  
Case Studies ◽  
Cross Sections ◽  
Oil And Gas ◽  
Stochastic Methods ◽  
Fault Rock ◽  
Oil And Gas Exploration ◽  
Hydrocarbon Traps ◽  
Entry Pressure ◽  
Fault Leakage ◽  
Capillary Entry Pressure

AbstractWe propose and validate methods for risk analysis of fault-bounded hydrocarbon traps in exploration. We concentrate on cross-fault leakage and consider lateral seals due to (1) juxtaposition and (2) high capillary-entry-pressure fault rock (membrane seal). We conclude that stochastic methods for fault seal analysis are essential, due to the large number of structural and stratigraphic parameters and the uncertainties. Central to the methods proposed is a Monte Carlo simulation which models geometrical and stratigraphic uncertainty. Multiple Allan maps (fault-parallel cross-sections) are produced and analysed for juxtaposition and shale gouge ratio (SGR). For validation, known discoveries with independently observed hydrocarbon–water contacts (IHWC) have been back-analysed. We present two case studies in this paper, and an additional 40 case studies are summarized (four public domain and 36 confidential case studies). The model outputs were compared with the IHWC. Juxtaposition analysis with no SGR contribution gives the smallest error. The inclusion of any fault rock seal mechanisms (such as SGR) matches or increases predicted hydrocarbon column heights compared to juxtaposition and gives larger errors. We conclude there is no reason to include fault rock membrane seals in exploration prospect risking.

Field determination of mechanical aperture, entry pressure and relative permeability of fractures using NAPL injection

Géotechnique ◽  
2006 ◽  
Vol 56 (1) ◽  
pp. 27-38 ◽  
Author(s):  
A. Steele ◽  
D. A. Reynolds ◽  
B. H. Kueper ◽  
D. N. Lerner
Keyword(s):  
Relative Permeability ◽  
Entry Pressure ◽  
Mechanical Aperture
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