Permeability measurements using rate-transient analysis (RTA): Comparison with different experimental approaches

Shabani, Mohammadebrahim; Ghanizadeh, Amin; Clarkson, Christopher R.

doi:10.1016/j.fuel.2021.122010

Cited by 8 publications

(1 citation statement)

References 16 publications

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“…Furthermore, it is worth noting that a fast and new core analysis method based on rate transient analysis theory (rate transient analysis permeameter (RTAPK)) has been developed to evaluate the absolute fluid permeability of core plugs under field operation conditions. , The apparent gas permeability can be estimated within 3–10 min for the Montney samples with permeability in the range of 100–3000 nD and is currently being tested for samples with much smaller permeabilities. The liquid permeability evaluation results will be published as a separate study in the near future.…”

Section: Comparison Of Liquid Permeability Determination Methodsmentioning

confidence: 99%

Liquid Permeability Determination from Vacuum Imbibition in Tight/Shale Core Plugs

et al. 2023

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Liquid permeability is a key petrophysical parameter that quantifies the ability of a liquid to flow through porous rock/ soil and can be used in determining the efficiency of many subsurface processes, including enhanced hydrocarbon recovery, groundwater transport, carbon dioxide geostorage, underground hydrogen storage, etc. However, it is time-consuming (usually >16−240 h) and challenging to measure the liquid permeability for tight/shale rocks, particularly when the permeability is 100 nD or lower. The objective of this study is to develop a rapid and simple approach to determine liquid (brine or oil) permeability in tight siltstones/shales. Specifically, the developed method is based on the combination of one-dimensional (1D) vacuum imbibition experiments in tight/shale core plugs and a modified Lucas− Washburn model. For our proof-of-concept study, the results have demonstrated that (1) only 44−116 h are required to determine the liquid permeability (98−608 nD) for the analyzed samples from the Montney and Yanchang Formations; and (2) the acquired brine permeability was 28.3−28.5% lower than the slip-corrected nitrogen (N 2 ) permeability derived from the pulse-decay permeability tests. This is the first attempt to determine the absolute permeability of a liquid according to a 1D vacuum imbibition experiment and theory. This study provides a promising technique for the fast characterization of ultratight formation permeability of around 100 nD.

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Section: Comparison Of Liquid Permeability Determination Methodsmentioning

confidence: 99%

Liquid Permeability Determination from Vacuum Imbibition in Tight/Shale Core Plugs

et al. 2023

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Estimation of fracture half-length with fast Gaussian pressure transient and RTA methods: Wolfcamp shale formation case study

Ibrahim,

Weijermars

2023

J Petrol Explor Prod Technol

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Accurate estimation of fracture half-lengths in shale gas and oil reservoirs is critical for optimizing stimulation design, evaluating production potential, monitoring reservoir performance, and making informed economic decisions. Assessing the dimensions of hydraulic fractures and the quality of well completions in shale gas and oil reservoirs typically involves techniques such as chemical tracers, microseismic fiber optics, and production logs, which can be time-consuming and costly. This study demonstrates an alternative approach to estimate fracture half-lengths using the Gaussian pressure transient (GPT) Method, which has recently emerged as a novel technique for quantifying pressure depletion around single wells, multiple wells, and hydraulic fractures. The GPT method is compared to the well-established rate transient analysis (RTA) method to evaluate its effectiveness in estimating fracture parameters. The study used production data from 11 wells at the hydraulic fracture test site 1 in the Midland Basin of West Texas from Upper and Middle Wolfcamp (WC) formations. The data included flow rates and pressure readings, and the fracture half-lengths of the 11 wells were individually estimated by matching the production data to historical records. The GPT method can calculate the fracture half-length from daily production data, given a certain formation permeability. Independently, the traditional RTA method was applied to separately estimate the fracture half-length. The results of the two methods (GPT and RTA) are within an acceptable, small error margin for all 5 of the Middle WC wells studied, and for 5 of the 6 Upper WC wells. The slight deviation in the case of the Upper WC well is due to the different production control and a longer time for the well to reach constant bottomhole pressure. The estimated stimulated surface area for the Middle and Upper WC wells was correlated to the injected proppant volume and the total fluid production. Applying RTA and GPT methods to the historic production data improves the fracture diagnostics accuracy by reducing the uncertainty in the estimation of fracture dimensions, for given formation permeability values of the stimulated rock volume.

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Experimental determination of gas-water relative permeability for ultra-low-permeability reservoirs using crushed-rock samples: Implications for drill cuttings characterization

Yang

Shabani

Solano

et al. 2023

Fuel

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Permeability measurements using rate-transient analysis (RTA): Comparison with different experimental approaches

Cited by 8 publications

References 16 publications

Liquid Permeability Determination from Vacuum Imbibition in Tight/Shale Core Plugs

Liquid Permeability Determination from Vacuum Imbibition in Tight/Shale Core Plugs

Estimation of fracture half-length with fast Gaussian pressure transient and RTA methods: Wolfcamp shale formation case study

Experimental determination of gas-water relative permeability for ultra-low-permeability reservoirs using crushed-rock samples: Implications for drill cuttings characterization

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