Skip to main content
SpringerLink
Log in

A comparison of permeability prediction methods using core analysis data for sandstone and carbonate reservoirs

  • Original Article
  • Published:
Geomechanics and Geophysics for Geo-Energy and Geo-Resources Aims and scope Submit manuscript

Abstract

Permeability is one of the most important parameters of reservoir rocks, it illustrates the capacity of rock to transmit fluids (oil, gas, water) in pore spaces. Permeability data can be obtained from routine core analysis in laboratory on 1.5 in core plugs and sidewall core. However, most of the wells are not coring due to problems during coring and higher costs, so permeability prediction in uncored sections play a significantly important role. The variety of methods developed to estimate permeability at pore scale, such as Kozeny–Carman, Swanson and Pittman. In fact, those equations are applied individually to estimate permeability. In this research, permeability estimation methods will be used on the same rock (sandstone or carbonate rock) to detect the suitable method for each rock type. Porosity, permeability data from routine core analysis and pore throat size from mercury injection capillary pressure on sandstone and carbonate rocks from Cuu Long and Song Hong basins in Vietnam will be gathered and permeability estimation conducted by using Hydraulic Flow Unit, Mercury Injection Capillary Pressure and Pittman methods based on that data. Estimated permeability obtained from each method will be compared with core permeability, the method with the highest R-squared be selected. The research shows that Hydraulic Flow Unit is optimized method for permeability prediction on sandstone with R-squared > 0.9. Mercury injection capillary pressure is the most accurate method to estimate permeability on carbonate rocks related to heterogeneity and complicated pore system with R-squared > 0.96. That results will help engineers have a fast and accurate decision for permeability prediction methods selection on sandstone and carbonate rocks. In addition, the empirical equations were derived to predict permeability on sandstone and carbonate rocks with the highest coefficient of correlation in multiple regression analysis and based on the relationship between porosity, permeability and pore throat size.

This is a preview of subscription content, log in via an institution to check access.

Access this article

Log in via an institution

Price excludes VAT (USA)
Tax calculation will be finalised during checkout.

Instant access to the full article PDF.

Institutional subscriptions

Fig. 1
Fig. 2
Fig. 3
Fig. 4
Fig. 5
Fig. 6
Fig. 7
Fig. 8
Fig. 9
Fig. 10
Fig. 11
Fig. 12
Fig. 13
Fig. 14
Fig. 15
Fig. 16
Fig. 17

Similar content being viewed by others

Abbreviations

∅e :

Effective porosity, (%)

∅z :

Pore volume to grain volume ratio

rmh :

Mean hydraulic radius, (μm)

τ:

Tortuosity

Fτ2 :

Kozeny constant

Sgv :

Surface area per unit grain volume, (μm−1)

Pc :

Capillary pressure, (psia)

\(\sigma\) :

Interfacical tension of mercury, (dynes/cm)

θ:

Contac angle between mercury and the pore surface, (°)

rc:

Pore throat radius, (μm)

Rapex:

Pore radius corresponding to the apex, (μm)

k:

Permeability, (md)

∅:

Porosity, (%)

References

  • Amaufule JO, Altunbay M, Tiab D, Kersey DG, Keelan DK (1993) Enhanced Reservoir description: using core and log data to indentify hydraulic (flow) units and predict permeability in uncored intervals/wells”, paper SPE 26436 presented at the 1993 SPE annual technical conference and exhibition, Houston, Texas, October 3–6.

  • AutoPore IV 9500 (2001) Automated Mercury Porosimeter Manual, Micrometitics. Operation’s Manual, V 1.04

  • Ebanks WJ, Tye RS, Ranganahan V (1984) Geological factor influencing reservoir performance of the hartzog draw field, wyoming. J Pet Technol 36:1335–1344

    Article  Google Scholar 

  • Pittman ED (1992) Relationship of porosity and permeability to various parameters derived from mercury injection-capillary pressure curves for sandstone. AAPG Bulletin 76:191

    Google Scholar 

  • Pittman ED (2001) Estimating Pore Throat Size in Sandtones from Routine Core Analysis Data. Search and Discovery Article 40009:20

    Google Scholar 

  • Shafer J, Neasham J (2001) Mercury porosimetry protocal for rapid dertermination of petrophysical and reservoir quality properties. Reservoir Management Group, Poro Technology, Houston

    Google Scholar 

  • Washburn EW (1921) Note on a method of determining the distribution of pore sizes in a porous material. Proc Natl Acad Sci 7:115

    Article  Google Scholar 

Download references

Acknowledgements

The authors would like to thank the manager of Core and PVT Department (Vietnam Petroleum Institute) for supporting this research.

Author information

Authors and Affiliations

  1. Vietnam Petroleum Institute, Ho Chi Minh City, Vietnam

    Vuong Thanh Ngo

  2. Politecnico di Torino, Turin, Italy

    Vi Dinh Lu

  3. Lam Son JOC, Ho Chi Minh City, Vietnam

    Vu Minh Le

Authors
  1. Vuong Thanh Ngo
    View author publications

    You can also search for this author in PubMed Google Scholar

  2. Vi Dinh Lu
    View author publications

    You can also search for this author in PubMed Google Scholar

  3. Vu Minh Le
    View author publications

    You can also search for this author in PubMed Google Scholar

Corresponding author

Correspondence to Vuong Thanh Ngo.

Rights and permissions

Reprints and permissions

About this article

Check for updates. Verify currency and authenticity via CrossMark

Cite this article

Ngo, V.T., Lu, V.D. & Le, V.M. A comparison of permeability prediction methods using core analysis data for sandstone and carbonate reservoirs. Geomech. Geophys. Geo-energ. Geo-resour. 4, 129–139 (2018). https://doi.org/10.1007/s40948-017-0078-y

Download citation

  • Received:

  • Accepted:

  • Published:

  • Issue Date:

  • DOI: https://doi.org/10.1007/s40948-017-0078-y

Keywords

Search

Navigation