Fluid flow characteristics of Bandanna Coal Formation: a case study from the Fairview Field, eastern Australia

Yarmohammadtooski, Zahra; Salmachi, Alireza; White, Adrian; Rajabi, Mojtaba

doi:10.1080/08120099.2017.1292316

Cited by 38 publications

(12 citation statements)

References 41 publications

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“…Permeability of the coal formation is a very important parameter for the effective production of CBM reservoirs (Clarkson et al 2011;Yan et al 2015;Sun et al 2018bSun et al , 2018c. Currently, there are some methods for determining the permeability of the coal formation, such as core laboratory test (Gash 1991;Wang et al 2011;Adeboye and Bustin 2013;Li et al 2014), well logging (Li et al 2011;Fu et al 2009;Karacan 2009), well testing (Al-Khalifa et al 1989;Conway et al 1995;Salmachi et al 2019), and production performance analysis (Clarkson et al 2007;Yarmohammadtooski et al 2017;Zhu et al 2018). Core laboratory test is time consuming, expensive, and limited in sampling: sometimes for the coal formation with a complex cleat system under high stress condition, the coal cores used in laboratory deviate from the actual situations from downhole to surface, resulting in a larger deviation of the measured permeability from the actual value (Yan et al 2015).…”

Section: Introductionmentioning

confidence: 99%

“…However, the well testing method needs to inject water into the well or to shut in the well for a period; it is time consuming and affects the production schedule; more importantly, it is impossible to shut in all wells to test the permeability; so other methods are needed to be proposed. Fortunately, production performance analysis method (Clarkson et al 2007;Yarmohammadtooski et al 2017;Zhu et al 2018;Shi et al 2018bShi et al , 2019a can handle the aforementioned issues; it is not required to shut in the well and hence it does not affect the production schedule. The evaluated permeability is the average value within the control area of the CBM well, so it is more accurate and rational.…”

Section: Introductionmentioning

confidence: 99%

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Methods for simultaneously evaluating reserve and permeability of undersaturated coalbed methane reservoirs using production data during the dewatering stage

Shi

Sun

et al. 2020

Pet. Sci.

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In this work, a flowing material balance equation (FMBE) is established for undersaturated coalbed methane (CBM) reservoirs, which considers immobile free gas expansion effect at the dewatering stage. Based on the established FMBE, five straight-line methods are proposed to determine the control area, initial water reserve, initial free gas reserve, initial adsorbed gas reserve, original gas in place, as well as permeability at the same time. Subsequently, the proposed FMBE methods for undersaturated CBM reservoirs are validated against a reservoir simulation software with and without considering free gas expansion. Finally, the proposed methods are applied in a field case when considering free gas expansion effect. Validation cases show that the straight-line relationships for the proposed five FMBE methods are excellent, and good agreements are obtained among the actual reserves and permeabilities and those evaluated by the proposed five FMBE methods, indicating the proposed five FMBE methods are effective and rational for CBM reservoirs. Results show that a small amount of free gas will result in a great deviation in reserve evaluation; hence, the immobile free gas expansion effect should be considered when establishing the material balance equation of undersaturated CBM reservoirs at the dewatering stage.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Methods for simultaneously evaluating reserve and permeability of undersaturated coalbed methane reservoirs using production data during the dewatering stage

Shi

Sun

et al. 2020

Pet. Sci.

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“…If the rate of drainage pressure reduction is too fast, there will be stress sensitive effect and speed sensitive formation, and may enter the gaswater two-phase flow stage too early, resulting in porosity and permeability deterioration, coal crushing, formation of fine coal and pulverized coal, seepage resistance enhancement and other issues. It will slow down the propagation of pressure drop (Palmer and Mansoori, 1998;Teyssedou et al, 2005;Li et al, 2009;Salmachi and Karacan, 2017;Yarmohammadtooski et al, 2017). The seam permeability, porosity and compression coefficient as well as the water drainage time would have high influences to the pressure drop speed at each point in the seam.…”

Section: Introductionmentioning

confidence: 99%

Propagation of pressure drop in coalbed methane reservoir during drainage stage

Qiu

et al. 2019

Adv. Geo-Energ. Res.

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Numerical simulation was employed to investigate the propagation speed of pressure drop at the drainage stage in coalbed methane (CBM) reservoirs. A seepage model of singlephase water in CBM reservoirs was generated with the parameter from CBM well ZS39 in the Zhengzhuang block of the southern Qinshui Basin. The effects of stress sensitivity and reservoir properties on the pressure drop propagation process were analysed. Moreover the pressure drop funnel scale index was introduced to quantitatively characterize the propagation process. The results indicate that stress sensitivity cause the permeability form the permeability drop funnel, which is consistent with the shape of the pressure drop funnel. Under the constant bottom pressure, the propagation speed of the funnel will gradually decrease in both longitudinal and lateral direction. And the overall propagation speed rapidly increases first and then gradually decreases. In the scenario of steady decrease in the bottomhole pressure, the pressure drop speed shows an increasing trend in the longitudinal direction, and a decreasing trend in the lateral direction. The overall propagation speed of the pressure drop funnel increases all along. The reservoir pressure drop is positively correlated with the initial porosity, the initial permeability and the elastic modulus. For Poisson ratio, when the ratio is small, the reservoir pressure drop has a negative correlation. As Poisson ratio increases over 0.35, a positive correlation exists. It was found from the sensitivity analysis of reservoir pressure drop that petrophysical parameters have strong sensitivity to pressure drop, especially for permeability. Therefore, this work may provide insights into the CBM reservoir properties, and thus will be favorable for improving CBM recovery.

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“…By fitting the permeability data of Figure 5 Cove, respectively. A reported mean value of cleat compressiblity= 0.2117 MPa -1 (0.00146 psi -1 ) is reported by Yarmohammadtooski, et al (2017) based on the data form the USA and Australia coal basin. In chapter 4 the cleat compressibility of coal sample UQ-B1 Cf1=0.1102-0.0333MPa -1 perpendicular to the face cleats and Cf2=0.0588-0.0251MPa -1 perpendicular to the butt cleats calculated at effective stresses of σeff = 0.5 -4.0 MPa, which are comparable to the cleat compressibility of American coal more closely than Australian coal.…”

Section: Constant Stress Experimentsmentioning

confidence: 99%

Dynamics of anisotropic permeability in coal seam gas reservoirs

Raza¹

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In this work, the effect of stresses and the reservoir boundary conditions on the permeability anisotropy, mechanical properties and swelling/shrinkage of the coals will be examined.Permeability is the fundamental parameter to understanding and modelling the fluid flow in the porous coal, and thus crucial to estimating the commercial gas and water production from coal seam gas (CSG) reservoir. Although permeability is a primary parameter to determine the reservoir production, the fundamental research behind the permeability change during pressure drawdown is not extensively examined in context with reservoir stresses and boundaries which can directly affect the reservoir production estimates. This project provides a mean to understand permeability change in CSG reservoir by conducting experiments and modelling studies to relate coal permeability, mechanical properties and sorption behaviour to different reservoir stresses and boundary conditions.The first objective of this project was to manage the design, construct, and demonstrate a state of the art triaxial stress permeameter (TSP) to measure anisotropic-permeability and stress-strain on coal sample simultaneously. The TSP was designed to measure anisotropic permeability by rotating a 40 mm cubic coal sample in orthogonal direction so that permeability can be measured in directions that align with face cleats, butt cleats, and bedding-plane of the coal. TSP is used in a series of experiments on coal sample UQ-B1 from the Surat Basin to determine in the modulus of elasticity (E) and cleat compressibility (Cf) of the coal sample UQ-B1 (Chapter 4), measure permeability using helium and methane gases (Chapter 5), and the effect of using either constant-stress (free swelling) or constant-volume boundary conditions on the observed relationship between net stresses and permeability changes (Chapter 5).Chapter 4 reports experiments in the TSP to determine the modulus of elasticity (E) and cleat compressibility (Cf) of coal sample UQ-B1 at effective stresses of 0.5 -4.0 MPa. These experiments confirm that these coal properties are anisotropic and stress-dependent. The experimental data also shows that cleats become 'softer' as stress is reduced on the sample which can result in the permeability rise by increasing the cleat width. The calculated modulus of elasticity of the bulk coal was E1 = 4.35 GPa, E2 = 4.90 GPa and E3 = 7.06 GPa perpendicular to face cleat, butt cleat, and bedding-plane directions, respectively. The cleat compressibilities (Cf) calculated from the relationship of pore size to pore compressibility were Cf1=0.1102-0.0333MPa -1 perpendicular to the face cleats and Cf2=0.0588-0.0251MPa -1 perpendicular to butt cleats at effective stresses of σeff = 0.5 -4.0 MPa.

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Fluid flow characteristics of Bandanna Coal Formation: a case study from the Fairview Field, eastern Australia

Cited by 38 publications

References 41 publications

Methods for simultaneously evaluating reserve and permeability of undersaturated coalbed methane reservoirs using production data during the dewatering stage

Methods for simultaneously evaluating reserve and permeability of undersaturated coalbed methane reservoirs using production data during the dewatering stage

Propagation of pressure drop in coalbed methane reservoir during drainage stage

Dynamics of anisotropic permeability in coal seam gas reservoirs

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