Imperial College London
Portrait Picture

Dr James Lawrence

Faculty of Engineering, Department of Civil and Environmental Engineering

Reader in Geological Engineering
 
 
 
//

Contact

 

+44 (0)20 7594 0700j.lawrence Website

 
 
//

Assistant

 

Ms Sue Feller +44 (0)20 7594 6077

 
//

Location

 

528ASkempton BuildingSouth Kensington Campus

//

Summary

 

Publications

Citation

BibTex format

@article{Rashid:2015:10.1016/j.petrol.2015.05.009,
author = {Rashid, F and Glover, PWJ and Lorinczi, P and Collier, R and Lawrence, J},
doi = {10.1016/j.petrol.2015.05.009},
journal = {Journal of Petroleum Science and Engineering},
pages = {147--161},
title = {Porosity and permeability of tight carbonate reservoir rocks in the north of Iraq},
url = {http://dx.doi.org/10.1016/j.petrol.2015.05.009},
volume = {133},
year = {2015}
}
Download

RIS format (EndNote, RefMan)

TY  - JOUR
AB  - The distribution of reservoir quality in tight carbonates depends primarily upon how diagenetic processes have modified the rock microstructure, leading to significant heterogeneity and anisotropy. The size and connectivity of the pore network may be enhanced by dissolution or reduced by cementation and compaction. In this paper we have examined the factors which affect the distribution of porosity, permeability and reservoir quality in the Turonian-Campanian Kometan Formation, which is a prospective low permeability carbonate reservoir rock in northern Iraq. Our data includes regional stratigraphy, outcrop sections, well logs and core material from 8 wells as well as a large suite of laboratory petrophysical measurements. These data have allowed us to classify the Kometan Formation into three lithological units, two microfacies and three petrofacies. Petrofacies A is characterized by dense and compacted and cemented wackstone/packstone with nanometer size intercrystalline pores and stylolites and presents a poor reservoir quality (porosity range 0.005±0.01 to 0.099±0.01, permeability range 65nD-51μD). Occasional open fractures in Petrofacies A improve reservoir quality resulting in a 2-3 order of magnitude increase in permeability (up to 9.75mD). Petrofacies B is a dissolved wackstone/packstone that contains moldic and vuggy pores (porosity range 0.197±0.01 to 0.293±0.01; permeability range 0.087-4.1mD), with both presenting good reservoir quality, while Petrofacies C is a carbonate mudstone that has undergone dissolution and possibly some dolomitization (porosity range 0.123±0.01 to 0.255±0.01; permeability range 0.065-5mD). All three petrofacies can be distinguished from wireline log data using porosity and NMR measurements. A poroperm plot of all of the data is fitted by a power law of the form k(mD)=a<sup>b</sup> with a=28.044 and b=2.6504 with coefficient of determination, R<sup>2</sup>=0.70
AU  - Rashid,F
AU  - Glover,PWJ
AU  - Lorinczi,P
AU  - Collier,R
AU  - Lawrence,J
DO  - 10.1016/j.petrol.2015.05.009
EP  - 161
PY  - 2015///
SN  - 0920-4105
SP  - 147
TI  - Porosity and permeability of tight carbonate reservoir rocks in the north of Iraq
T2  - Journal of Petroleum Science and Engineering
UR  - http://dx.doi.org/10.1016/j.petrol.2015.05.009
UR  - https://www.sciencedirect.com/science/article/pii/S0920410515002004
VL  - 133
ER  -
Download