Khwaja Ghori

Khwaja Ghori

Senior Geologist 13829 Khwaja Desktop /Portals/0/PackFlashItemImages/WebReady/ghori-khwaja.jpg?width=200&height=235&quality=75&mode=crop&encoder=freeimage&progressive=true

Ameed Ghori is a geoscientist with a BSc (Honor; 1967) and an MSc (1968) in Applied Geology at the University of Karachi; a Postgraduate Diploma (1991) and an MSc (1994) in Applied Petroleum Geology at Curtin University of Technology, Perth, Australia. He started his career at Geological Survey of Pakistan, Quetta, Pakistan as an Assistant Chemist and gradually progressed to current position of Acting Manager Energy Geoscience at Geological Survey of Western Australia, Perth, Australia.

He has joined the Geological Survey of Western Australia in 1994 as a Project Geologist. He has worked as a Senior Geochemist at Oil and Gas Development Corporation, Pakistan (OGDCL); Geochemistry Specialist at Arabian Gulf Oil Company (AGOCO), Libya; Consultant Geologist at Lasmo Oil (Australia) Ltd, SAGASCO Resources (Australia), and Discovery Petroleum (Australia) N.L; Project Manager at Petrochemex (Australia); and Petroleum Geochemistry Specialist/ Advisor at Petroleum Exploration and Production Department (PEPD), Uganda. He initiated setup of Petroleum Geochemistry Laboratory at OGDCL, AGOCO, and PEPD.

He presented short courses and lectures on various topics related to petroleum: systems, geology, modeling and analysis. He attended various short courses and workshops presented by Roger Summons, Chris Sutton and Nigel Bailey on organic geochemistry, Douglas Waples on basin modeling, Les Magoon on petroleum systems. He has authored many papers and confidential reports on basins of Pakistan, Libya, Uganda, and Australia. He is a Mentor at Next Generation Program of Western Australian Petroleum Club for Year 10 students, introducing oil and gas industry.

Ameed is a member of AAPG/ EMD (American Association of Petroleum Geologists/ Energy Mineral Division), FESAus (Formation Evaluation Society of Australia), PESA (Petroleum Exploration Society of Australia), and PAPG (Pakistan Association of Petroleum Geoscientists).



  • 28752 Production from unconventional petroleum reservoirs includes petroleum from shale, coal, tight-sand and oil-sand. These reservoirs contain enormous quantities of oil and natural gas but pose a technology challenge to both geoscientists and engineers to produce economically on a commercial scale. These reservoirs store large volumes and are widely distributed at different stratigraphic levels and basin types, offering long-term potential for energy supply. Most of these reservoirs are low permeability and porosity that need enhancement with hydraulic fracture stimulation to maximize fluid drainage. Production from these reservoirs is increasing with continued advancement in geological characterization techniques and technology for well drilling, logging, and completion with drainage enhancement. Currently, Australia, Argentina, Canada, Egypt, USA, and Venezuela are producing natural gas from low permeability reservoirs: tight-sand, shale, and coal (CBM). Canada, Russia, USA, and Venezuela are producing heavy oil from oilsand. USA is leading the development of techniques for exploring, and technology for exploiting unconventional gas resources, which can help to develop potential gas-bearing shales of Thailand. The main focus is on source-reservoir-seal shale petroleum plays. In these tight rocks petroleum resides in the micro-pores as well as adsorbed on and in the organics. Shale has very low matrix permeability (nano-darcies) and has highly layered formations with differences in vertical and horizontal properties, vertically non-homogeneous and horizontally anisotropic with complicate natural fractures. Understanding the rocks is critical in selecting fluid drainage enhancement mechanisms; rock properties such as where shale is clay or silica rich, clay types and maturation , kerogen type and maturation, permeability, porosity, and saturation. Most of these plays require horizontal development with large numbers of wells that require an understanding of formation structure, setting and reservoir character and its lateral extension. The quality of shale-gas resources depend on thickness of net pay (>100 m), adequate porosity (>2%), high reservoir pressure (ideally overpressure), high thermal maturity (>1.5% Ro), high organic richness (>2% TOC), low in clay ( During the past decade, unconventional shale and tight-sand gas plays have become an important supply of natural gas in the US, and now in shale oil as well. As a consequence, interest to assess and explore these plays is rapidly spreading worldwide. The high production potential of shale petroleum resources has contributed to a comparably favourable outlook for increased future petroleum supplies globally. Application of 2D and 3D seismic for defining reservoirs and micro seismic for monitoring fracturing, measuring rock properties downhole (borehole imaging) and in laboratory (mineralogy, porosity, permeability), horizontal drilling (downhole GPS), and hydraulic fracture stimulation (cross-linked gel, slick-water, nitrogen or nitrogen foam) is key in improving production from these huge resources with low productivity factors. Unconventional Petroleum Reservoirs: An Overview
    Unconventional Petroleum Reservoirs: An Overview

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