Is water saturation a fracability indicator for organic‐rich, yet low‐clay content, tight carbonate source rock reservoirs?

2021 ◽  
Author(s):  
Hui‐Hai Liu ◽  
Jilin Zhang ◽  
Feng Liang ◽  
Mustafa Basri ◽  
Cenk Temizel ◽  
...  
Keyword(s):  
Source Rock ◽  
Water Saturation ◽  
Clay Content ◽  
Tight Carbonate ◽  
Carbonate Source Rock ◽  
Carbonate Source

Petrophysical and Fluid Flow Properties of a Tight Carbonate Source Rock Using Digital Rock Physics

2015 ◽  
Author(s):  
Moustafa Dernaika ◽  
Osama Ali Aljallad ◽  
Safouh Koronfol ◽  
Michael Suhrer ◽  
Woan Jing Teh ◽  
...  
Keyword(s):  
Fluid Flow ◽  
Source Rock ◽  
Rock Physics ◽  
Flow Properties ◽  
Digital Rock Physics ◽  
Digital Rock ◽  
Tight Carbonate ◽  
Carbonate Source Rock ◽  
Carbonate Source

Petrophysical and Fluid Flow Properties of a Tight Carbonate Source Rock Using Digital Rock Physics

2015 ◽  
Author(s):  
Moustafa Dernaika ◽  
Osama Al Jallad ◽  
Safouh Koronfol ◽  
Michael Suhrer ◽  
Woan Jing Teh ◽  
...  
Keyword(s):  
Organic Matter ◽  
Fluid Flow ◽  
Source Rock ◽  
Rock Physics ◽  
Flow Properties ◽  
Digital Rock Physics ◽  
The Core ◽  
Tight Carbonate ◽  
Carbonate Source Rock ◽  
Carbonate Source

Abstract The evaluation of shale is complicated by the structurally heterogeneous nature of fine-grained strata and their intricate pore networks, which are interdependent on many geologic factors including total organic carbon (TOC) content, mineralogy, maturity and grain-size. The ultra-low permeability of the shale rock requires massive hydraulic fracturing to enhance connectivity and increase permeability for the flow. To design an effective fracturing technique, it is necessary to have a good understanding of the reservoir characteristics and fluid flow properties at multiple scales. In this work, representative core plug samples from a tight carbonate source rock in the Middle East were characterized at the core- and pore-scale levels using a Digital Rock Physics (DRP) workflow. The tight nature of the carbonate rocks prevented the use of conventional methods in measuring special core analysis (SCAL) data. Two-dimensional Scanning Electron Microscopy (SEM) and three-dimensional Focused Ion Beam (FIB)-SEM analysis were studied to characterize the organic matter content in the samples together with (organic and inorganic) porosity and matrix permeability. The FIB-SEM images in 3D were also used to determine petrophysical and fluid flow (SCAL) properties in primary drainage and imbibition modes. A clear trend was observed between porosity and permeability related to identified rock fabrics and organic matter in the core. The organic matter was found to have an effect on the imbibition two-phase flow relative permeability and capillary pressure behavior and hysteresis trends among the analyzed samples. The data obtained from DRP provided information that can enhance the understanding of the pore systems and fluid flow properties in tight formations, which cannot be derived accurately using conventional methods.

Petrophysical and Fluid Flow Properties of a Tight Carbonate Source Rock Using Digital Rock Physics

2015 ◽  
Author(s):  
Moustafa Dernaika ◽  
Osama Al Jallad ◽  
Safouh Koronfol ◽  
Michael Suhrer ◽  
Woan Jing Teh ◽  
...  
Keyword(s):  
Fluid Flow ◽  
Source Rock ◽  
Rock Physics ◽  
Flow Properties ◽  
Digital Rock Physics ◽  
Digital Rock ◽  
Tight Carbonate ◽  
Carbonate Source Rock ◽  
Carbonate Source

First Successful Proppant Fracture for Unconventional Carbonate Source Rock in Saudi Arabia

2014 ◽  
Author(s):  
Nayef Ibrahim Al-Mulhim ◽  
Ali Hussein Al-Saihati ◽  
Ahmed M. Hakami ◽  
Moataz Al-Harbi ◽  
Khalid Saeed Asiri
Keyword(s):  
Saudi Arabia ◽  
Source Rock ◽  
Carbonate Source Rock ◽  
Carbonate Source

A practical petrophysical model for a source rock play: The Mancos Shale

2017 ◽  
Vol 5 (3) ◽  
pp. T423-T435
Author(s):  
Jesús M. Salazar ◽  
Ron J. M. Bonnie ◽  
William W. Clopine ◽  
G. Eric Michael
Keyword(s):  
Source Rock ◽  
Water Saturation ◽  
Clay Content ◽  
Source Rocks ◽  
Crushed Rock ◽  
Organic Carbon Content ◽  
Hydrocarbon Generation ◽  
Niobrara Formation ◽  
Mancos Shale ◽  
Petrophysical Model

Recently, the focus in source rock exploration has moved from gas-rich to liquid-rich plays and warrants revisiting “bypassed” hydrocarbon charged source rocks, which were deemed uneconomic when first drilled. In North America’s oil fields, there are thousands of wells with different vintages of nuclear and electrical logs, yet these wells generally lack any advanced logs beyond the traditional triple combo. We have developed a workflow that uses a considerable amount of laboratory measurements made on crushed rock to upscale a petrophysical model based on a triple combo logging suite only. The model divides the field (laterally) in oil window and gas window fairways and (vertically) in petrophysical units. The remaining hydrocarbon generation potential is based on geochemical measurements, such as thermal maturity and total organic carbon content (TOC), from core and cuttings in the area. The petrophysical units reflect major geologic intervals with similar porosity and clay content. The workflow was sequentially built by correlating logs with core measurements, using TOC and maturity for organic matter, X-ray diffraction for mineralogy and grain density, porosity, and water saturation from fluids extraction, for volumetrics. The model is applied to the Mancos Shale (New Mexico, USA), a Cretaceous-age source rock, which includes the Niobrara Formation. The Mancos Shale has been penetrated in various fields while developing conventional sandstone reservoirs. The model is validated with measurements on a core recently acquired in the anticipated high-hydrocarbon-yield window. Petrophysical properties predicted from logs agree well with core measurements in blind tests, demonstrating the robustness of the model despite being based on a basic suite of logs and a simple deterministic approach. This model is now routinely used by the asset team as an automated workflow to generate fairway maps, locate sweet spots, and for landing lateral wells.

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