Abstract
Formation evaluation is one of the most important parts of a reservoir study. This process is mainly performed using wire-line logs. These data are usually available from all wells and reservoir intervals. Various formulas and parameters are used for calculating porosity, water saturation and lithology from logs. Reservoir heterogeneities may considerably change these formulas and their parameters. Matrix responses, pore types, permeabilities and other petrophysical properties are different for each unit or rock type. Therefore, applying one formula for all samples yields erroneous results. These results are used for calculating the final amount of oil in place. The results of these calculations change future development plans and investments in the field. After partitioning the reservoir into different rock types or reservoir units, the appropriate parameters are used in the relevant calculations. These include the log responses for various lithologies of different units as well as special petrophysical characters (such as Archie’s cementation factor) for the unit. In deterministic approach, these are different for each step. In other words, unique parameters are used for each formula in different units or rock types. Then, the results of the previous stage are used for the next calculation. In a stochastic approach, different mathematical models are developed for calculating the reservoir properties in each homogeneous unit. Parameters are different for each model. For example, if pore types control the distribution of water saturation in a reservoir, the reservoir is classified into various parts according to its pore types. Then, a separate model is developed for each part and laboratory-derived data for each rock type are combined with wire-line logs for calculating the water saturation of the entire reservoir interval.
This is a preview of subscription content, log in via an institution.
Buying options
Tax calculation will be finalised at checkout
Purchases are for personal use only
Learn about institutional subscriptionsReferences
Kolodizie SJ (1980) Analysis of pore throat size and use of the Waxman-Smits equation to determine OOIP in Spindle Field, Colorado. SPE paper 9382 presented at the 1980 SPE Annual Technical Conference and Exhibition, Dallas, Texas
Lucia FJ (2007) Carbonate reservoir characterization: an integrated approach. Springer, Berlin, Heidelberg
McPhee C, Reed J, Zubizarreta I (2015) Core analysis: a best practice guide. Elsevier, London
Nazemi M, Tavakoli V, Rahimpour-Bonab H, Hosseini M, Sharifi-Yazdi M (2018) The effect of carbonate reservoir heterogeneity on Archie’s exponents (a and m), an example from Kangan and Dalan gas formations in the central Persian. Gulf J Nat Gas Sci Eng 59:297–308
Nooruddin HA, Hossain ME, Al-Yousef H, Okasha T (2014) Comparison of permeability models using mercury injection capillary pressure data on carbonate rock samples. J Petrol Sci Eng 12:9–22
Nooruddin HA, Hossain ME, Al-Yousef H, Okasha T (2016) Improvement of permeability models using large mercury injection capillary pressure dataset for middle east carbonate reservoirs. J Porous Media 19(5):405–422
Tavakoli (2018) Geological core analysis: application to reservoir characterization. Springer, Cham
Tiab D, Donaldson EC (2015) Petrophysics, theory and practice of measuring reservoir rock and fluid transport properties. Gulf Professional Publishing, Houston
Author information
Authors and Affiliations
Corresponding author
Rights and permissions
Copyright information
© 2020 The Author(s), under exclusive license to Springer Nature Switzerland AG
About this chapter
Cite this chapter
Tavakoli, V. (2020). Petrophysical Evaluations. In: Carbonate Reservoir Heterogeneity. SpringerBriefs in Petroleum Geoscience & Engineering. Springer, Cham. https://doi.org/10.1007/978-3-030-34773-4_5
Download citation
DOI: https://doi.org/10.1007/978-3-030-34773-4_5
Published:
Publisher Name: Springer, Cham
Print ISBN: 978-3-030-34772-7
Online ISBN: 978-3-030-34773-4
eBook Packages: EnergyEnergy (R0)