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An Estimate of Recoverable Heavy Oil Resources of the Orinoco Oil Belt, Venezuela

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An Estimate of Recoverable Heavy Oil Resources of the Orinoco Oil Belt, Venezuela World Petroleum Resources Project An Estimate of Recoverable Heavy Oil Resources of the Orinoco Oil Belt, Venezuela 70° 68° 66° 64° 62° 60° 58° 56° 14° ST. LUCIA ST. VINCENT AND BARBADOS The U.S. Geological Survey ARUBA THE GRENADINES NETHERLANDS ANTILLES estimated a mean volume GRENADA 12° of 513 billion barrels of CARIBBEAN SEA TRINIDAD technically recoverable heavy oil in the Orinoco Oil Belt 10° A' Assessment Unit of the East Venezuela Basin Province; the range is 380 to 652 billion A 8° barrels. The Orinoco Oil Belt East Venezuela Assessment Unit thus contains Basin Province VENEZUELA GUYANA one of the world’s largest SOUTH 6° PACIFIC AMERICA recoverable oil accumulations. OCEAN ATLANTIC OCEAN SURINAME 4° BRAZIL COLOMBIA Introduction 0 50 100 200 KILOMETERS The Orinoco Oil Belt Assessment Unit (AU) of the La Luna−Quercual 0 50 100 200 MILES Total Petroleum System encompasses EXPLANATION 2 approximately 50,000 km of the East Orinoco Oil Belt Assessment Unit Venezuela Basin Province that is under- East Venezuela Basin Province lain by more than 1 trillion barrels of heavy oil-in-place (fig. 1) (Fiorillo, Figure 1. Map showing the location of the Orinoco Oil Belt Assessment Unit (blue line); the 1987). As part of a program directed at La Luna–Quercual Total Petroleum System and East Venezuela Basin Province boundaries are estimating the technically recoverable oil coincident (red line). and gas resources of priority petroleum basins worldwide, the U.S. Geological Venezuela Basin Province. Thrust faults The reservoir sandstones, although porous Survey (USGS) estimated the recover- associated with the fold belt caused litho- and permeable, are characterized by several able oil resources of the Orinoco Oil spheric loading and basin formation, and depositional sequences with considerable Belt AU. This estimate relied mainly on the resulting burial placed Cretaceous and internal fluid-flow heterogeneity caused published geologic and engineering data possibly older petroleum source rocks into by juxtaposition of different facies and for reservoirs (net oil-saturated sandstone the thermal window for the generation of by shale barriers that reduce recovery thickness and extent), petrophysical oil (Parnaud and others, 1995; Summa and efficiency. Sandstone reservoirs range in properties (porosity, water saturation, others, 2003). The oil migrated updip from depth from 150 to 1,400 meters, and they and formation volume factors), recovery the deeper basin to the shallow southern contain heavy oil with a range of gravi- factors determined by pilot projects, and basin platform, forming the Orinoco Oil ties from 4 to 16 degrees API. Viscosities estimates of volumes of oil-in-place. Belt. The oil is considered to be concen- are generally low, ranging from 2,000 to The East Venezuela Basin is a fore- trated along a forebulge that formed south 8,000 centipoises (Dusseault, 2001). land basin south of a fold belt (fig. 2). The of the foreland basin (Bartok, 2003). progressive west-to-east collision of the The heavy oil in the Orinoco Oil Methodology and Input Data Caribbean plate with the passive margin of Belt AU is largely contained within fluvial, northern South America in the Paleogene nearshore marine, and tidal sandstone res- In addition to the standard USGS and Neogene formed a thrust belt and fore- ervoirs of the Miocene Oficina Formation methodology for assessing continuous land basin that together compose the East (Kopper and others, 2001; Bejarano, 2006). oil accumulations such as those in the U.S. Department of the Interior Fact Sheet 2009–3028 U.S. Geological Survey Printed on recycled paper October 2009 Orinoco Oil Belt (Crovelli, 2000), we (OOIP) at 1,180 billion barrels of oil AU and in other areas, particularly used reservoir data, petrophysical data, (BBO), a commonly cited estimate for California, west Texas, and western oil-in-place estimates, and recovery fac- the Orinoco Oil Belt (Fiorillo, 1987); Canada. The minimum recovery factor tors taken from studies of the Orinoco PDVSA recently revised this value to was estimated to be 15 percent, the Oil Belt to develop five other approaches more than 1,300 BBO (Gonzalez and recovery expected for cold production for estimating recoverable resources and others, 2006). In this study the median using horizontal wells. The median to adequately represent the geologic and OOIP was estimated at 1,300 BBO recovery factor was estimated to be engineering uncertainty in the assess- and the maximum at 1,400 BBO. 45 percent, on the assumption that ment. Key data used in the assessment The minimum OOIP was estimated horizontal drilling and thermal recovery are summarized in table 1. The estimates at 900 BBO, given the uncertainty of methods might be widely used. The of volumes of recoverable oil and associ- regional sandstone distribution and oil maximum recovery factor was esti- ated gas reported here reflect the distribu- saturation (Fiorillo, 1987). mated to be 70 percent, on the assump- tion of mean estimates obtained by the tion that other recovery processes, six methodologies applied to the Orinoco Estimates of Recovery Factor in addition to horizontal drilling and Oil Belt AU (table 2). Recovery factor, or that percent- steam-assisted gravity drainage, might eventually be applied on a large scale Estimates of Original Oil-in-Place age of the OOIP that is determined to be technically recoverable, was in the Orinoco Oil Belt AU (Dusseault, A comprehensive study by Petroleos estimated from what is currently 2001; Curtis and others, 2002; Acasio de Venezuela S.A. (PDVSA) established known of the technology for recovery and Regardiz, 2006; Fernandez and the magnitude of the original oil-in-place of heavy oil in the Orinoco Oil Belt Bashbush, 2008). A A' SE NW EAST VENEZUELA BASIN ORINOCO OIL BELT MAIN PRODUCING AREA SEA LEVEL KILOMETERS 0 5 EXPLANATION Middle Miocene Jurassic and/or 10 to present Paleozoic? Lower Miocene Pre-Cretaceous basement Cretaceous to Paleogene Fault passive margin Oil field 15 VERTICAL EXAGGERATION X 5 0 25 50 KILOMETERS 0 15.6 31 MILES Figure 2. Schematic structural cross section of the East Venezuela Basin showing the updip position of the Orinoco Oil Belt relative to the deeper part of the East Venezuela Basin. Oil generated from thermally mature Cretaceous and possibly older source rocks in the deeper part of the basin migrated updip to form the accumulation in the Orinoco Oil Belt (after Jacome and others, 2003). Table 1. Key input data for assessment of Orinoco Oil Belt Assessment Unit. [%, percent; BBO, billion barrels of oil; ft, feet; scf/bbl, standard cubic foot per barrel] Minimum Median Maximum Orinoco oil-in-place (BBO) 900 1,300 1,400 Recovery factor (%) 15 45 70 Net oil-saturated sandstone thickness (ft) 1 150 350 Porosity (%) 20 25 38 Water saturation (%) 10 20 25 Formation volume factor 1.05 1.06 1.08 Gas/oil ratio (scf/bbl) 80 110 600 Table 2. Orinoco Oil Belt Assessment Unit assessment results. [BBO, billion barrels of oil; TCFG, trillion cubic feet of gas; NGL, natural gas liquids; BBNGL, billion barrels natural gas liquids. Results shown are fully risked esti- mates. F95 represents a 95 percent chance of at least the amount tabulated. Other fractiles are defined similarly] Total Petroleum System Total Undiscovered Resources (TPS) Field Oil (BBO) Gas (TCFG) NGL (BBNGL) and Assessment Unit Type F95 F50 F5 Mean F95 F50 F5 Mean F95 F50 F5 Mean (AU) La Luna–Querecual TPS Orinoco Oil Belt AU Oil 380 512 652 513 53 122 262 135 0 0 0 0 Probability Distributions of resources or reserves within the Orinoco Bejarano, C., 2006, Tertiary stratigraphy Petrophysical and Reservoir Oil Belt AU. Most important, these results and sedimentary environments of the oil bearing sands of the Orinoco Oil Properties do not imply anything about rates of heavy oil production or about the likelihood of Belt, Venezuela, South America: World Heavy Oil Conference, Beijing, China, Oil-saturated sandstones in the heavy oil recovery. Also, no time frame November 12–15, 2006, Proceedings, Orinoco Oil Belt AU are largely uncon- is implied other than the use of reasonably Paper 2006–770, 7 p. solidated (Dusseault, 2001). The values foreseeable recovery technology. used in the assessment for porosity, Crovelli, R.A., 2000, Analytic resource water saturation, net oil-saturated sandstone References Cited assessment method for continuous thickness, and formation volume factor are (unconventional) oil and gas shown in table 1. Net thickness and extent Acasio, Y., and Regardiz, K., 2006, accumulations—The “ACCESS” of oil-saturated sandstone were obtained Opportunity for a SAGD pilot test method: U.S. Geological Survey from a published map that resulted from implementation in a zone in initial Open-File Report 00–044, 34 p. a comprehensive PDVSA study of the phase of operation, Ayacucho Curtis, Carl, Kopper, Robert, Decoster, Orinoco Oil Belt (Fiorillo, 1987). area, Orinoco Belt: World Heavy Eric, Guzman-Garcia, Angel, Huggins, Oil Conference, Beijing, China, Cynthia, Knauer, Larry, Minner, Mike, Summary of Results November 12–15, 2006, Proceedings, Kupsch, Nathan, Linares, Luz M., Paper 2006–771, 13 p. Rough, Howard, and Waite, Mike, 2002, The assessment of technically Heavy-oil reservoirs: Oilfield Review, recoverable heavy oil and associated gas Bartok, Peter, 2003, The peripheral bulge Autumn 2002, Schlumberger Oilfield resources is shown in table 2. The mean of the Interior Range of the Eastern Services Company, p. 30–51. Venezuela basin and its impact on of the distribution of heavy oil resources Dusseault, M.B., 2001, Comparing is about 513 BBO, with a range from oil accumulations, in Bartolini, C., Venezuelan and Canadian heavy oil 380 to about 652 BBO. The mean estimate Buffler, R.T., and Blickwede, J., eds., and tar sands, in Canadian Interna- of associated dissolved-gas resource is The Circum-Gulf of Mexico and the tional Petroleum Conference, Calgary, 135 trillion cubic feet of gas (TCFG), Caribbean—Hydrocarbon habitats, basin Alberta, Canada, June 12–14, 2001, with a range from 53 to 262 TCFG.
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