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Abstract This paper summarizes an integrated field, experiments and computer simulation research program conducted to support a review of the reserves and development plan for the Hamaca Area in the Orinoco Belt (OB), Venezuela. The impact of the foamy oil mechanism on the Hamaca heavy-extra heavy Oil reserves and the importance of understanding this behavior is presented in this paper. The study was conducted in reservoirs with the largest production history (within the OB). The experimental results showed in-situ formation of non-aqueous oil foam with high gas retention, improving oil mobility and leading, therefore, to high well productivity. An experimental recovery factor over 10% was obtained under primary conditions so it was possible to increase oil reserves by approximately 30% over the currently accepted volumes. Experimental results provided input parameters to perform preliminary simulation runs which would allow the modification of well spacing schemes, the generation of a high-probability production profile, and the optimization of artificial lift systems, incorporating larger capacity equipment. Introduction When the exploitation of Hamaca heavy oil reservoirs began, it was assumed that the primary production mechanisms were sand compaction, solution gas drive and thermal effects due to steam cyclic stimulation which improves oil mobility. However, an unexpectedly high cold production lead to research of the drive mechanisms to explain the special production performance. Similar behavior has been observed in the Lloydminster area of Canada. Despite considerable speculation, a number of authors have studied foamy oil behavior and some research has recently been done, yet the mechanism leading to this behavior still remains to be successfully explained. Reservoir properties that were proposed to explain the behavior in the OB and in Canada include unusually high sand permeability and/or critical gas saturation. In Canada, high critical gas saturation is now an accepted property of some reservoirs, the so called Foamy Oil reservoirs. However, a monitoring field program of sand compaction and land subsidence did not show any evidence that this mechanism has taken place in the Hamaca Area. None of these proposed properties and mechanisms are consistent with field observations. On the other hand, numerical models showed high uncertainty when trying to match the reservoir production pressure behavior. As a consequence, a research program was designed as part of an integrated reservoir study. It included a production behavior analysis, an experimental program for fluid/porous media characterization through conventional and nonconventional PVT tests, and solution gas drive experiments at research centers of Venezuela (INTEVEP), Canada (PRI-CMG) and USA (LAB). P. 639
- North America > Canada (1.00)
- South America > Venezuela > Orinoco Oil Belt (0.62)
- Geology > Geological Subdiscipline (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.89)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.69)
- South America > Venezuela > Eastern Venezuela Basin > Hamaca Area > Bare Field (0.99)
- South America > Venezuela > Anzoátegui > Eastern Venezuela Basin > Maturin Basin > Hamaca Area (0.99)
- South America > Venezuela > Orinoco Oil Belt > Eastern Venezuela Basin (0.89)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Integration of geomechanics in models (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- (7 more...)
Integrated Study for the Characterization and Development of the MFB-53 Reservoir, North Hamaca-Orinoco Belt, Venezuela
de Mirabal, M. (Corpoven S.A.) | Gordillo, R. (Corpoven S.A.) | Fuenmayor, M. (Corpoven S.A.) | Rojas, G. (Universidad de Oriente) | Rodriguez, H. (Intevep S.A.) | Sanchez, R. (Intevep S.A.)
Integrated Study for the Characterization and Development of the MFB-53 Reservoir, North Hamaca-Orinoco Belt, Venezuela. Abstract The purpose of this paper is to report the most relevant technical results obtained from a research and development study of Corpoven's MFB-53 extra-heavy crude oil reservoir, located in the Bare block - North Hamaca Area of the Orinoco Belt in Eastern Venezuela. This study was conducted by a Corpoven-Intevep multidisciplinary team with the support of national and international research centers in the development of a 3D numerical simulation model. Foamy Hamaca crude oil behavior modelling has permitted the understanding of the high productivity shown by horizontal wells, which might lead to a primary recovery factor greater than 10% without compaction and/or steaming. An increase of 30% in oil reserves was possible due to the results obtained from the numerical simulation performed by the Corpoven-Intevep team, allowing the total recovery factor to be raised from 10% to 14%. The same results may be applied to other Orinoco Belt areas. Moreover, a geomechanical model was developed for this reservoir using laboratory tests. Consequently, optimum drilling and production strategies for both horizontal and vertical wells in the Hamaca Area were determined. An optimum exploitation scheme has been defined with the use of the 3D model. A pre-defined cold production and larger spacing is anticipated prior to beginning with secondary recovery processes (gas injection and/or thermal activity), leading to a 30% cutback in the overall project cost. Introduction In 1994, an integrated study of the MFB-53 Reservoir was initiated. The reservoir has an extension of 165 km2 and an original oil in place (OOIP) of 1943 MMBLS. The largest extra-heavy crude oil recoverable reserves (194, MMBLS) discovered in North Hamaca belong to this reservoir. Reservoir exploitation began in 1982, as of March 1996, 164 wells have been drilled (45 horizontal and 119 vertical), with an accumulated production of 71 MMBLS (3.6% of OOIP). Reservoir performance has been improved through the use of horizontal wells with an initial production of up to 3000 B/D and an average production of 1500 B/D. Reservoir pressure has decreased only 200 psia from an original pressure of 1220 psia (Table 1). Due to the high productivity index (7 to 12) of horizontal wells, high volume lifting equipment was required in order to handle the produced fluids. Electric submersible pumps have been used successfully, and 62 MBD of the reservoir production are tied to this lifting method. It is important to mention that Corpoven's heavy/extra heavy oil production forecast is 270 MBD for the year 2005, more than double the current production of 125 MBD. The development of the 3D model backs up the growing potential of Corpoven's expansion program. The main objective of this study was the design of an optimum exploitation scheme for the short-, medium- and long-term plans through a multidisciplinary team formed by Corpoven, Intevep and national and international research centers (Fig. 1). Scope The integrated study of the MFB-53 reservoir began in July 1994 under a multidisciplinary team with a technical proposal. To reach the objective, a fastrack in geology and reservoir engineering was implemented, applying novel technologies for the definition and construction of the geological model, seismic interpretation, research lab work on the special behavior of reservoir fluids, and finally the development of a three dimensional dynamic simulation model. P. 225
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type (0.95)
- South America > Venezuela > Eastern Venezuela Basin > Hamaca Area > Bare Field (0.99)
- South America > Venezuela > Anzoátegui > Eastern Venezuela Basin > Maturin Basin > Hamaca Area (0.99)