Browsing by Subject "permeability"

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Analysis of Low-Permability Gas Sands Suitable for Future Research Programs
(1982) Finley, Robert J.; Han, Jong H.
Research on tight gas sands has traditionally focused on lenticular sands, but blanket-geometry sands, deposited by different processes, present distinct external and internal reservoir geometries requiring unique exploration and production techniques. To ensure the applicability of research findings across various reservoirs, a survey was conducted with a focus on elastic depositional systems and the potential transferability of results between different stratigraphic units. Based on the survey results, five stratigraphic units were selected for further study, and data collection efforts were initiated during the contract period. A comprehensive work plan was developed for the analysis of these units, which includes the preparation of geologic cross sections and maps, review of productive areas, resource analysis, and documentation of findings. The five selected units for study are the Travis Peak Formation, the Corcoran and Cozzette Sandstones, the Mancos "B" interval of the Mancos Shale, the upper Almond Formation, and the Frontier Formation. Data collection efforts have yielded a significant number of well logs from Colorado and Wyoming, with additional logs identified from Bureau files for the Travis Peak Formation. Wells suitable for cross-sectional analysis have been identified for the Travis Peak and Corcoran/Cozzette trends, and initial cross sections have been prepared for the latter trend. These efforts aim to enhance understanding and exploration potential of blanket-geometry tight gas sand reservoirs.
Assessing the value of permeability data in a carbon capture and storage project
(2013) Puerta-Ortega, C.; Bickel, J.E.; Hovorka, Susan D.
Characterization of Facies and Permeability Patterns in Carbonate Reservoirs Based in Outcrop Analogs
(1992) Kerans, C. (Charles), 1954-; Lucia, F. Jerry; Senger, Rainer K.; Fogg, Graham E.; Nance, Hardie Seay, 1948-; Hovorka, Susan D.
More than 13 billion barrels (Bbbl) of mobile oil and 17 Bbbl of residual oil will remain in San Andres and Grayburg reservoirs at abandonment under current development practices. Through the development and application of new recovery technology, a large part of this resource can be recovered. This report focuses on research for the development and testing of new techniques for improving the recovery of this resource. Outcrop and subsurface geologic and engineering data are utilized to develop new methodologies through the integration of geologic observations and engineering data for improving numerical models that predict reservoir performance more accurately. Extensive regional mapping of the 14-mile by 1,200-foot San Andres outcrop, located on the Algerita Escarpment, Guadalupe Mountains, New Mexico, demonstrates that the San Andres carbonate-ramp complex is composed of multiple depositional sequences that have significant basinward shifts in reservoir-quality facies tracts occurring across sequence boundaries. Detailed geologic and petrophysical mapping of three reservoir-quality facies tracts demonstrates that the fundamental scale of geologic description for reservoir characterization is the parasequence and its component rock-fabric-based facies. Descriptions of cores from the Seminole San Andres Unit illustrate that the parasequence is also the fundamental geologic scale for reservoir mapping in the subsurface.
Characterization of Facies and Permeability Patterns in Carbonate Reservoirs Based on Outcrop Analogs
(1993) Kerans, C. (Charles), 1954-; Lucia, F. Jerry; Senger, Rainer K.
More than 13 billion barrels (Bbbl) of mobile oil and 17 Bbbl of residual oil will remain in the San Andres and Grayburg reservoir at abandonment under current development practices. Through the development and application of new recovery technology, a large part of this resource can be recovered. This report focuses on research for the development and testing of new techniques for improving recovery of this resource. Outcrop and subsurface geologic and engineering data are utilized to develop new methodologies through the integration of geologic observations and engineering data for improving numerical models that predict reservoir performance more accurately. Extensive regional mapping of the 14-mile by 1,200-foot San Andres outcrop, located on the Algerita Escarpment, Guadalupe Mountains, New Mexico, demonstrates that the San Andres carbonate-ramp complex is composed of multiple depositional sequences that have significant basinward shifts in reservoir-quality facies tracts occurring across sequence boundaries. Detailed geologic and petrophysical mapping of three reservoir-quality facies tracts demonstrates that the fundamental scale of geologic description for reservoir characterization is the parasequence and its component rock-fabric-based facies. Descriptions of cores from the Seminole San Andres Unit illustrate that the parasequence is also the fundamental geologic scale for reservoir mapping in the subsurface.
Chararcterization of Heterogeneity Style and Permeability Structure in Fluvial Reservoirs
(1995) Barton, Mark D.; Angle, Edward S.; Yeh, Joseph S.
The Cretaceous Acu Formation was investigated as an analog to a heterogeneous group of reservoirs having significant potential for reserve growth in the Potiguar Basin of Brazil. Architectural, lithologic, and petrophysical information was collected from an outcrop exposing a fluvially deposited sandstone body located in the state of Rio Grande do Norte, Brazil. Sedimentologic descriptions of the sandstone body were collected from a series of vertical transects spaced evenly across the outcrop. Stratal surfaces traced between transects were recorded on photomosaics. Measurements of permeability were obtained from each transect by use of a portable probe-style mechanical field permeameter. A cross-section depicting bedding architecture, sedimentologic attributes, and permeability values was constructed, and the information incorporated into a two-dimensional representation of reservoir architecture using Stratamodel's Stratigraphic Geocellular Modeling software (SGM). The SGM technique deterministically interpolates permeability data between transect locations using a lithologic or stratigraphic framework.
Constraining CO2 simulations by coupled modeling and inversion of electrical resistance and gas composition data
(2013) Doetsch, J.; Kowalsky, M.B.; Doughty, C.; Finsterle, S.; Ajo-Franklin, J.B.; Carrigan, C.R.; Yang, X.; Hovorka, Susan D.; Daley, T.M.
The cross-scale science of CO2 capture and storage: from pore scale to regional scale
(2012) Middleton, R.S.; Keating, G.N.; Stauffer, P.H.; Jordan, A.B.; Viswanathan, H.S.; Kang, Q.J.; William Carey, J.; Mulkey, M.L.; Sullivan, E.J.; Chu, S.P.; Esposito, R.; Meckel, Tip A.
Diagenesis and Burial History of the Lower Cretaceous Travis Peak Formation, East Texas: Controls on Permeability in a Tight Gas Sandstone
(1987) Dutton, Shirley P.
Petrographic and geochemical studies were used to determine the diagenetic and burial history of Travis Peak sandstones in East Texas and to relate the diagenesis to permeability variations within the formation. Permeability in much of the formation has been reduced to less than 0.1 md by compaction, cementation, and minor pressure solution. Travis Peak sandstone is quartzarenite and subarkose, having an average composition of Q95F4R1. The first authigenic cements to precipitate were illite, which coated detrital grains with tangentially oriented crystals, and dolomite. Next, extensive quartz cement, averaging 17% of the rock volume in well-sorted sandstone, occluded much of the primary porosity. Quartz is most abundant in the lower Travis Peak, in well-connected sandstone beds that were deposited in braided streams. Dissolution of orthoclase and albitization of plagioclase followed quartz cementation and occurred prior to mid-Cretaceous movement of the Sabine Uplift. Illite, chlorite, and ankerite precipitated after feldspar diagenesis. Oil migrated into Travis Peak reservoirs in the Late Cretaceous from Jurassic source rocks. Later deasphalting of the oil filled much of the remaining porosity in some zones near the top of the formation with reservoir bitumen.
Geology and Engineering Characteristics of Selected Low-Permability Gas Sands: A Survey
(1982) Finley, Robert J.
Research on tight gas sands has traditionally focused on lenticular sands, but there is growing recognition of the importance of blanket-geometry sands, which are deposited by different systems and have distinct reservoir characteristics. To ensure that research findings are applicable across various reservoir types, this survey emphasizes elastic depositional systems and the potential for extrapolating results between different stratigraphic units. Information was gathered for 16 sedimentary basins, focusing on the general attributes, economic factors, geologic parameters of the basin, and specific geologic and engineering parameters of selected blanket-geometry tight gas sands. These sands are primarily associated with deltaic barrier-strandplain systems and, to a lesser extent, shelf elastic depositional systems. For example, formations like the Travis Peak and Frontier Formations, representing fan delta and deltaic systems, respectively, show high operator interest and good extrapolation potential. Within the Mesaverde Group in basins like the San Juan, Piceance Creek, Uinta, and Greater Green River Basins, several formations exhibit good extrapolation potential, particularly those associated with barrier-strandplain systems. Offshore bars and other minor facies are also present in these systems. Examples include the Cozzette and Corcoran Sandstones, which are of interest to explorationists and merit further study. Among shelf systems, the Mancos "B" Formation and adjacent intervals warrant examination alongside formations like the Cozzette and Corcoran Sandstones to ensure that potential tight gas resources in shelf systems are adequately considered. This comprehensive approach aims to broaden understanding and facilitate effective exploration and development strategies for blanket-geometry tight gas sands.
Permeability Analysis of Polymeric Porous Media Obtained by Material Extrusion Additive Manufacturing
(University of Texas at Austin, 2019) Shigueoka, M.O.; de M. Junqueira, S.L.; Alves, T.A.; Volpato, N.
Porous media (PM) are used in many applications, and their geometry and hydraulic properties are essential in flow analysis, especially in geology (oil and gas) and medical (tissue engineering) applications. Additive Manufacturing (AM) enables the production of planned porosity and the material extrusion AM allows working with process parameters to produce lattice type geometries, without the need to have a 3D model of the internal porous structure. This work presents a preliminary study on the permeability of some PM designs obtained in PLA using an in-house process-planning software. Two main filling variations of the raster strategies were studied, one considering the displacement of staggered layers and the other involving a new joined filaments proposal. The permeability obtained experimentally is compared with numerical outputs. The results indicate that both filling strategies influence the PM permeability, but this was more significant with the joined filaments approach.
Preliminary Results of Porosity and Permeability of Cores From Doe Wells in the Palo Duro Basin, Texas Panhandle
(1984) Senger, Rainer K.; Smith, D. Anderson; Conti, Robert Downey
Information on permeability and porosity of the Deep-Basin Brine Aquifer is important for describing flow pattern and flow velocity of deep-basinal fluids. Permeabilities were estimated from drill-stem tests, pumping tests, and published values of equivalent geologic materials. In addition, permeabilities and porosities of different lithologies were determined from laboratory tests of cores. The objectives of core analysis are: 1. Determine porosities and permeabilities of the different geologic lithofacies. 2. Relate porosities to petrographic description of pore types and lithology. 3. Obtain vertical and horizontal distribution of porosity and permeability from the analyzed core intervals. 4. Compare core permeabilities to drill-stem test and pumping test analyses. 5. Compare core-derived porosity values with porosities from neutron-density cross plots.
Revisiting Mississippian Barnett Shale: Lithological and Geochemical Control on Varied Reservoir Heterogeneity and Fluid Saturation from Late Oil to Dry Gas Window, Fort Worth Basin, Texas
(American Association of Petroleum Geologists Southwest Section (AAPG SWS), 2023-05-06) Ko, L.T.; Peng, S.; Fu, Q.; Periwal, P.; Sivil, E.
Textures, Mineralogy, and Reservoir Properties of an Altered Mafic Tuff Core from the Upper Cretaceous (Lower Campanian) of Central Texas
(GeoGulf conference, 2023-04-23) Reed, R.M.; Loucks, R.G.