Experimental study of spontaneous capillary imbibition in selected carbonate core samples (Record no. 171168)
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| 000 -LEADER | |
|---|---|
| fixed length control field | 02747nab a2200181 4500 |
| 008 - CÓDIGOS DE INFORMACIÓN DE LONGITUD FIJA - INFORMACIÓN GENERAL | |
| Campo de control de longitud fija | 260224s2010 xxu |
| 245 00 - TITULO | |
| Título | Experimental study of spontaneous capillary imbibition in selected carbonate core samples |
| 260 ## - PUBLICACION, DISTRIBUCION, ETC | |
| Lugar de publicación, distribución, etc. | |
| Nombre de publicador, distribuidor, etc. | |
| Fecha de publicación, distribución, etc. | feb. 2010 |
| 270 ## - FECHA DE CARGA | |
| Fecha de carga | 17/06/2010 ; 17/06/2010 |
| 300 ## - DESCRIPCION FISICA | |
| Otra extensión | 7 p. ; 320-326 |
| 520 ## - RESUMEN, ETC | |
| Resumen | Transcripción del resumen del autor. Spontaneous imbibition is of critical importance to oil recovery from fractured reservoirs. Scaling the core test data of spontaneous capillary imbibition with different imbibing fluids is crucial to properly design improved recovery methods and to predict their performances. This paper presents the results of static imbibition tests performed on cylindrical core samples taken from three wells completed in a fractured carbonate oil-wet reservoir located in the UAE. All experiments were conducted at ambient temperature with all faces of the cores open to free imbibition. Core samples were initially saturated with reservoir oil of 3.81 cp viscosity. A synthetic formation brine of 50,000 ppm NaCl concentration was used as the base imbibing phase. The effects of core permeability and the interfacial tension (IFT) of two chemical solutions on the rate of imbibitions and ultimate oil recovery were investigated. Also, the imbibition curves for the two chemical solutions (imbibing fluids) were used for scaling the imbibition data obtained from these experiments. The results of this work show that the core samples of this particular carbonate rock did not respond whatsoever to spontaneous imbibition with brine water, which is indicative of their strong wettability to oil. The ultimate oil recovery by free imbibition from these oil-wet core samples have been found to increase as the IFT is decreased and the core permeability is increased. The maximum observed ultimate oil recoveries are 16.24% and 4.83% of the original oil in place (OOIP) when a nonionic surfactant solution and alkali solution were used as the imbibing fluid, respectively. It is postulated that the nonionic surfactant can remove the adsorbed organic material from the solid surface which can lead to preferentially water-wet or intermediate wettability and an increase in oil relative permeability. Gravitational forces can then pull the oil out of the matrix because of lower capillarity and increased oil relative permeability. Finally, the application of the scaling group proposed by Li and Horne gave satisfactory correlation of all the imbibition data observed in this study. |
| 581 ## - ESTADO DE COLECCIÓN | |
| Estado de colección | 3-4 |
| 773 0# - CORRECCIÓN | |
| Título | Journal of Petroleum Science & Engineering |
| Partes relacionadas | 70 |
| 942 ## - DESC. DE MATERIAL | |
| Tipo de item KOHA | Artículo de Revista |
| 100 1# - RESPONSABLE PERSONAL | |
| Apellido, Nombre | Al-Attar, Hazim H. |
| 9 (RLIN) | 42950 |
| Biblioteca propietaria | Biblioteca actual | Fecha de adquisición | Inventario | Total de préstamos | Inventario | Fecha de carga | Tipo de item KOHA |
|---|---|---|---|---|---|---|---|
| Biblioteca Alejandro Angel Bulgheroni | Biblioteca Alejandro Angel Bulgheroni | 05/03/2026 | 200046026 | 200046026 | 05/03/2026 | Artículo de Revista |
