SPE- 187889-MS Determination Techniques of Archie’s Parameters, a, m and n and its relevant Impact on Water Saturation Values in Sandstone and Carbonate Core Samples
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WhatsAppGet PriceGet A QuoteThe microsphere injection had higher oil production in the oil-wet carbonate cores than the water-wet sandstone cores with similar permeability. It was supported by the differential pressure data that indicated that microspheres reduced the permeability in carbonates more effectively than that in sandstone cores.
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WhatsAppGet PriceGet A QuoteCore samples (70 mm × 35 mm) were selected from the carbonate and sandstone core samples of various Malaysian fields and characterized by different ranges of permeability and porosity. Most of the carbonate cores have a different pore space distribution known as vugs, shown in figure 1.
WhatsAppGet PriceGet A QuoteThe core analysis presented in this study for carbonate rocks showed that a is in the range of 0.74 to 1.81 with an average of 1.12 and m varies from 1.41 to 2.79 and giving an average of 2.03. Saturation exponent n has a range of 1.83 to 2.59, with an average of n 2.08, indicating that the studied reservoir is predominantly water wet.
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WhatsAppGet PriceGet A QuoteCore samples (70 mm × 35 mm) were selected from the carbonate and sandstone core samples of various Malaysian fields and characterized by different ranges of permeability and porosity. Most of the carbonate cores have a different pore space distribution known as vugs, shown in figure 1.
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WhatsAppGet PriceGet A QuoteAN INVESTIGATION OF NEW IN-SITU-GENERATED ACID FOR CARBONATE MINERAL DISSOLUTION IN SANDSTONE AND CARBONATE CORES A Thesis by THANAKRICH PUMMARAPANTHU Submitted to the Office of Graduate and Professional Studies of Texas A&M University in partial fulfillment of the requirements for the degree of MASTER OF SCIENCE
WhatsAppGet PriceGet A QuoteThe dataset consists of 730 thickness measurements, of which 313 are from 68 faults in carbonate rocks, and 417 are from 120 deformation band/microfaults and faults in sandstones. These data show that the increase in fault core thickness with displacement for the two lithologies is, overall, similar in log–log space, consistent with a power-law trend with an exponent of 0.5.
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WhatsAppGet PriceGet A QuoteDifferences between sandstone and carbonate reservoirs influence the way we study them (Table 1). Sandstone porosity is mainly interparticle; therefore, it is related geometrically to depositional texture and fabric. Because permeability usually correlates rather well with interparticle porosity in sandstones, it can be related to depositional
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