Browsing by Subject "capillary pressure"

Now showing 1 - 4 of 4

Access status: Open Access ,
An evaluation of hydrocarbon deposit tightness in aspect of CO₂ sequestration
(2015) Blicharski, Jacek
Depleted hydrocarbon deposits due to large capacity and proven tightness are often considered as prime candidates for $CO_2$ sequestration in geological structures. The tightness of these structures is mainly connected with the exis-tence of water saturated overbunden rocks of very low permeability which form a natural barrier for the migration of hydrocarbons. This paper explains the sealing mechanisms of caprocks resulting from capillary forces at the interface of hydrocarbon – water and carbon dioxide – water contact. Other ways of caprock leakage due to rock fracturing or reactivation of natural faults and fi ssures were also investigated.
Access status: Open Access ,
Predicting relative permeability from experimental capillary pressure porous plate test for two phase flow
(2017) Czarnota, Robert; Janiga, Damian; Stopa, Jerzy; Wojnarowski, Paweł
Relative permeabilities relationships as a function of fluids saturation are one of the most important parameters for describing multiphase flow processes in reservoir rocks. When direct laboratory tests are not available for investigating oil-water multi-phase flow in rocks, then indirect prediction techniques using relative permeability functions are widely used, e.g. from capillary pressure test. In this study the measurement of capillary pressure was performed on rocks plugs with different characteristics at reservoir conditions using porous plate method. During measurement semi-permeable membrane was used with 15 bar threshold pressure, what allowed to register formation water saturation, at changing differential pressures steps. Desaturation at each pressure stage was continued until no more produced liquid was observed. Water saturation point at maximum capillary pressure applied is assumed to be final irreducible water saturation. Application of porous plate method provides sufficient stabilization time, allowing to achieve uniform saturation distribution. In this research, Brook–Corey model was used to predict relative permeability from experimental measured capillary pressure data for oil-water phase flow in porous media. As a result, it is possible to obtain more accurate capillary pressure outcomes, and relative permeability curves for the two-phase system, than other methods used in practice. Performing capillary pressure measurements at reservoir conditions, allows to restore the processes occurring in the reservoir.
Access status: Open Access ,
The influence of wettability on the petrophysical parameters of reservoir rocks
(Wydawnictwa AGH, 2017) Kulinič, Vitalij
Knowledge of the reservoir rock wettability and its influence on petrophysical properties is a key factor to determine the mechanisms and assess the efficiency of oil recovery. In the reservoir rock at the presence of different liquids, it is very important to obtain information about the type of wettability of the rock. Since the understanding of the relationship between wettability and distribution of water and oil in the pore space is necessary to assess the efficiency of oil recovery. Wettability is one of the main parameters that determines the position of the liquid in the reservoir pore space and fluid flow. Wettability affects the properties of petrophysical rock containing hydrocarbons, among others, saturation, capillary pressure, relative permeability, electrical properties of reservoir rocks. Also affects the multiphase flow in porous media. The aim of this article is to characterize the petrophysical parameters of rocks dependent wettability, an overview of the research state of the impact of wettability on the selected petrophysical parameters and presents directions of the future research.
Access status: Open Access ,
Wyznaczanie położenia konturów złożowych dla złóż ropy naftowej w oparciu o kryteria hydrodynamiczne, z uwzględnieniem zmiennej gęstości płynów złożowych i ciśnień kapilarnych
(2007) Zawisza, Ludwik
The size and magnitude of a reservoir trap are determined by the geologic boundaries of strata and contour of the reservoir. The location of contours is determined by the movement of the fl owing reservoir water, reservoir properties of rocks and properties of reservoir fluids. An original methodics of mapping reservoir traps for oil is presented in the paper. The method employs both the influence of groundwater dynamics and also variability of density of reservoir fluids and the capillary pressure effect on the location of the contours. It enables determining locations of hydrodynamic traps in a 3D space, in the condition of fl owing water and high variability of properties of reservoir rocks and reservoir fluids. The method also enables determining reservoir contours both in the structural and stratigraphic type of reservoir. The realization of the presented method of mapping reservoir traps in presented on the example of oil fields Pomorsko and Czerwieńsk, occurring in the Main Dolomite beds in the Fore-Sudetes area.