Fluid-Flow Characterization of Dolomitized Carbonate-Ramp Reservoirs: San Andres Formation (Permian) of Seminole Field and Algerita Escarpment, Permian Basin, Texas and New Mexico

Lucia, F. Jerry; Kerans, Charles; Wang, Fred P.

doi:10.2110/scn.95.34.0129

Cited by 17 publications

(10 citation statements)

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“…However, evaluation of 3 composite cores after an extensive water-alternating miscible CO 2 injection showed that Klinkenberg-corrected permeability increased by 65% to 6 folds (600%). Porosity increased by 0.5 to 1.0 porosity unit, while the grain density reduced by 0.007 to 0.019 g/cm 3 . This might suggest that appreciable formation alteration occurred due to dissolution of carbonates by the weak carbonic acid formation.…”

Section: Remaining Oil Saturation Vs Permeabilitymentioning

confidence: 91%

“…Core data reveal that the lower 750 ft of the San Andres contains skeletal grainstone and packstone and an open-marine fauna. The highstand systems tract is represented by (1) A number of detailed reservoir characterization studies have been undertaken on the Seminole Field as well as the San Andres in general and reported by several authors [3][4][5][6] . Eleven high-frequency cycles (HFCs) have been identified and twelve dolomitic facies ranging from deep subtidal argillaceous mudstone and fusulinid wackestone, to peritidal laminites and microkarst residuum have been described.…”

Section: B) Geologic Setting (Structure and Reservoir)mentioning

confidence: 99%

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Rock-Fluid Characterization for Miscible CO2 Injection: Residual Oil Zone, Seminole Field, Permian Basin

Honarpour

Nagarajan

Cuenca

et al. 2010

SPE Annual Technical Conference and Exhibition

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Low to moderate remaining oil saturation exists in deeper zones of several Permian Basin oil reservoirs. The Residual Oil Zone (ROZ) in the Seminole San Andres Unit (SSAU) is found below its traditional producing oil-water contact and contains significant (20-40%) immobile oil. ROZ production is not technically or economically feasible through primary or secondary oil recovery mechanisms. However, miscible flooding with carbon dioxide, CO 2 , has emerged as a viable enhanced oil recovery mechanism with a high potential to mobilize significant portions of this resource. Reliable rock and fluid characterizations are critical to evaluate the CO 2 flood potential and an optimum design of CO 2 flood strategy.The critical rock-fluid parameters and processes influencing the feasibility of producing the remaining oil in the ROZ are:Reliable estimates of Remaining Oil Saturation (ROS) -obtained from pressure core, sponge cores and laboratory waterflood tests at reservoir conditions Characterization of formation anisotropy and scale-dependency of permeability through whole core analysis and potential formation damage during CO 2 flood Residual oil saturation to miscible CO 2 flood (Sorm)-obtained from miscible CO 2 flood tests at reservoir conditions using live oil and field observation Reservoir oil/ CO 2 PVT properties -obtained by basic oil PVT tests, oil swelling and multi contact tests Minimum miscibility pressure to CO 2 -obtained through slim tube and coreflood laboratory CO 2 flow tests Equation of state compositional fluid characterization to capture key mechanisms of CO 2 miscible flooding Compositional CO 2 flood simulation using geocellular models and the above rock and fluid data and models Significant variation in remaining oil saturation of 20-40% were observed field-wide in ROZ, but through data integration, it was shown that the most probable average value of the remaining oil saturation is 28-32%. The residual oil saturation to waterflood from centrifuge imbibition capillary pressure tests were shown to be in the range of 20-28% with an average of 25%. Residual oil saturation to miscible CO 2 flood was measured in 6.0" to 12.0" long core composite found to be moderately low, ~12%. Coreflood tests showed no formation damage due to CO 2 injection after water flooding but significant porosity and permeability enhancement during WAG process. Laboratory measurements showed that the MMP of ROZ oil with CO 2 is below the current reservoir pressure and the oil swelling is nearly 75%. This result indicates that miscibility development is achievable under current operational conditions. However, there is a possibility of a second liquid phase, rich in CO 2 appearing over a small pressure window, that may complement the miscible recovery process through liquid-liquid extraction. Compositional simulation with reliable rock and fluid data input was used in the design and implementation of the CO 2 flood in Seminole ROZ.Significant improvement in data quality and reduction in rock and fluid data uncertainty for miscibl...

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Section: Remaining Oil Saturation Vs Permeabilitymentioning

confidence: 91%

Section: B) Geologic Setting (Structure and Reservoir)mentioning

confidence: 99%

Rock-Fluid Characterization for Miscible CO2 Injection: Residual Oil Zone, Seminole Field, Permian Basin

Honarpour

Nagarajan

Cuenca

et al. 2010

SPE Annual Technical Conference and Exhibition

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“…10 presents saturation above the transition zone estimated from resistivity logs, porosity from core plugs, and rock-fabric class determined from thin sections. Data are included from Seminole San Andres (Permian) field of West Texas, 19 South Cowden Grayburg (Permian) field in West Texas, 20 and Ghawar Arab D (Jurassic) field in Saudi Arabia. 21 Seminole and South Cowden fields produce from dolostone and Ghawar field produces from both limestone and dolostone.…”

Section: Comparison With Other Permeability Modelsmentioning

confidence: 99%

“…11). 19,22 This is a dolomite reservoir where the precursor limestone fabrics are preserved in the dolostone. Results from the Jurassic Arab D reservoir in the Haradh area of Ghawar field, Saudi Arabia, clearly identify the class 1 large crystalline dolostone (Fig.…”

Section: (7b) Ln(s W ) = C(l) + D(l)ln(f)mentioning

confidence: 99%

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Predicting Permeability From Well Logs in Carbonates With a Link to Geology for Interwell Permeability Mapping

Jennings

Lucia

2001

SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractA fundamental component in the construction of most reservoir performance models is an empirical relationship between permeability as measured in a limited number of cored wells and other petrophysical properties measured in well logs. This paper presents a permeability model specially designed for carbonates. The model relates permeability to interparticle porosity, makes special accommodation for separate-vug porosity, and includes a rock-fabric classification scheme with an important dual petrophysical-geological significance. Methods to estimate the separate-vug porosity from sonic logs and the rock-fabric from initial saturation are presented.The dual petrophysical-geological significance of the rockfabric classification is important for providing a link to geological models for use in distributing permeabilities between wells. Porosity and permeability are highly variable and difficult to predict spatially in most carbonate reservoirs, but rock-fabric changes tend to be systematically organized in a predictable manner within a sequence stratigraphic framework. Carbonate Rock-Fabric Petrophysical ClassificationPermeability and capillary properties of interparticle pore space can be related to interparticle porosity and geologic descriptions of particle size and sorting called rock fabrics. 1,2 These rock fabrics were initially grouped into three categories called rock-fabric petrophysical classes on the basis of porosity, permeability, and capillary properties 1 (Fig. 2):Class 1 is composed of grainstones, dolograinstones, and large crystalline dolostones.Class 2 is composed of grain-dominated packstones, fine and medium crystalline, grain-dominated dolopackstones, and medium crystalline, mud-dominated dolostones.Class 3 includes mud-dominated limestones and fine crystalline, mud-dominated dolostones.

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Carbonate Reservoir Characterization

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Fluid-Flow Characterization of Dolomitized Carbonate-Ramp Reservoirs: San Andres Formation (Permian) of Seminole Field and Algerita Escarpment, Permian Basin, Texas and New Mexico

Cited by 17 publications

References 0 publications

Rock-Fluid Characterization for Miscible CO2 Injection: Residual Oil Zone, Seminole Field, Permian Basin

Rock-Fluid Characterization for Miscible CO2 Injection: Residual Oil Zone, Seminole Field, Permian Basin

Predicting Permeability From Well Logs in Carbonates With a Link to Geology for Interwell Permeability Mapping

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