Coalbed methane producibility from the Mannville coals in Alberta, Canada: A comparison of two areas

Gentzis, Thomas; Goodarzi, Fariborz; Cheung, F.K.; Laggoun‐Défarge, Fatima

doi:10.1016/j.coal.2008.01.004

Cited by 70 publications

(29 citation statements)

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“…The consequence of this uncertainty means that it is difficult to predict with accuracy a well's performance until it is online and producing (Acuna, et al, 2015;Gentzis, et al, 2008;Howell, et al, 2014;Karacan, 2013;Xie, et al, 2013). However, a pipe network to gather the gas needs to be in place before the wells begin producing, and as the performance of the wells are not accurately known until they are producing, this presents a design challenge.…”

Section: Unconventional Gas Reservoir Uncertaintymentioning

confidence: 99%

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Developing synthetic reservoir type curve model for use in evaluating surface facility and gathering pipe network designs

Dennis

2017

Journal of Natural Gas Science and Engineering

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Please cite this article as: Dennis, M., Developing synthetic reservoir type curve model for use in evaluating surface facility and gathering pipe network designs, Journal of Natural Gas Science & Engineering (2017), doi: 10.1016/j.jngse.2017 This is a PDF file of an unedited manuscript that has been accepted for publication. As a service to our customers we are providing this early version of the manuscript. The manuscript will undergo copyediting, typesetting, and review of the resulting proof before it is published in its final form. Please note that during the production process errors may be discovered which could affect the content, and all legal disclaimers that apply to the journal pertain. M A N U S C R I P T A C C E P T E D ACCEPTED MANUSCRIPT AbstractSurface facilities and unconventional gas gathering networks are typically designed to collect gas from a large number of wells to a central location. The unit operations that make up the surface network need to be installed before the wells are producing and thus need to be sized on predicted performance rather than actual performance which is not known until production data is available. This means each reservoir's production profile which is based on uncertain input parameters and imperfect reservoir models forms the sizing basis for the surface facilities.In this study a method is developed to generate synthetic reservoir flow type curves based on a set of input parameters that is independent of reservoir parameters. The main qualitative characteristics of an unconventional gas reservoir type curve are described such as gas ramp to peak, peak gas flow and production decline, along with the discontinuities and variations from expected performance seen in operating trends. The synthetic type curve proposed in this work can be parameterised to mimic these characteristics, along with a well deliverability mechanism and subsurface communication between wells.The method of being able to describe a type curve by means of input parameterisation allows an unconventional gas surface facility of gathering pipe network and in-field booster compressors to be designed against many sets of synthetic type curves rapidly generated by randomisation of those input parameters.

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Section: Unconventional Gas Reservoir Uncertaintymentioning

confidence: 99%

“…There are many physical factors that are related to coal permeability but are difficult to quantify (Gentzis, et al, 2008). Even in a laboratory setting, it is not easy to measure the relative permeability of coal mainly because of the difficulty in reproducing results (Ham & Kantzas, 2013).…”

Section: Unconventional Gas Reservoir Uncertaintymentioning

confidence: 99%

Developing synthetic reservoir type curve model for use in evaluating surface facility and gathering pipe network designs

Dennis

2017

Journal of Natural Gas Science and Engineering

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“…The micro-pilot test results showed that the gas saturation is 40.8% in the anthracitic coals of the South Qinshui basin, China [58]. Seam 4 in the Lower Cretaceous Gates Formation, Inner Foothills of Alberta showed gas saturation levels of 90% in the in situ reservoir conditions [53]. Unsaturated CBM reservoirs initially produce CBM only when the reservoir pressure is reduced below the critical desorption pressure [59,60].…”

Section: Recovery Mechanism Of Unsaturated Cbm Reservoirsmentioning

confidence: 99%

“…Thus, unsaturated CBM reservoirs refer to those reservoirs in which gas content is less than their maximum gas adsorption in the reservoir conditions. Most coal reservoirs can be substantially unsaturated with thermogenic gas [45][46][47][48][49][50][51][52][53][54][55][56][57][58]. Gas saturation of coal reservoirs in the Weibei CBM field ranges from 39.2%~87.2% [55,56].…”

Section: Recovery Mechanism Of Unsaturated Cbm Reservoirsmentioning

confidence: 99%

“…Additionally, the third Klinkenberg effect has seldom been considered in permeability variation of the recovery of CBM reservoirs. It is widely thought that coal can be substantially unsaturated with thermogenic gas if not augmented by hydrocarbon migration or late-stage bacterial methanogenesis [45][46][47][48][49][50][51][52][53][54][55][56][57][58]. In consideration of this fact, we improved the existing permeability models in this paper to make them more suitable for describing permeability dynamic variation in unsaturated CBM reservoirs based on the production performance of those reservoirs, and discuss the sensitivity of various parameters, including the gas content, initial reservoir pressure, Langmuir volume and pressure, Poisson's ratio, Young's modulus, Langmuir strain, and Klinkenberg coefficient, to permeability dynamic variation in the recovery of unsaturated CBM reservoirs.…”

Section: Introductionmentioning

confidence: 99%

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Permeability Variation Models for Unsaturated Coalbed Methane Reservoirs

Tang

et al. 2015

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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-A large number of models have been established to describe permeability variation with the depletion of reservoir pressure to date. However, no attempt has been made to draw enough attention to the difference in the effect of various factors on permeability variation in different production stages of unsaturated CoalBed Methane (CBM) reservoirs. This paper summarizes the existing and common permeability models, determines the relationship between various effects (effective stress effect, matrix shrinkage effect and Klinkenberg effect) and desorption characteristics of the recovery of unsaturated CBM reservoirs, then establishes two improved models to quantificationally describe permeability variation, and finally discusses the effects of various factors (gas saturation, cleat porosity, Poisson's ratio and shrinkage coefficient) on permeability variation. The results show that permeability variation during the recovery of unsaturated CBM reservoirs can be divided into two stages: the first one is that permeability variation is only affected by the effective stress effect, and the second is that permeability variation is affected by the combination of the effective stress effect, matrix shrinkage effect and Klinkenberg effect. In the second stage, matrix shrinkage effect and Klinkenberg effect play much more significant role than the effective stress effect, which leads to an increase in permeability with depletion of reservoir pressure. Sensitivity analysis of parameters in the improved models reveals that those parameters associated with gas saturation, such as gas content, reservoir pressure, Langmuir volume and Langmuir pressure, have a significant impact on permeability variation in the first stage, and the important parameters in the second stage are the gas content, reservoir pressure, Langmuir volume, Langmuir pressure, Poisson's ratio, Young's modulus and shrinkage coefficient during the depletion of reservoir pressure. A comparative study of the improved models indicates that the improved SD model has a greater sensitivity to various parameters than the improved PM model and the improved models describe permeability dynamic variation more exactly than the original ones.Résumé -Modèles de variation de perméabilité pour des réservoirs de gaz de houille insaturé -Un grand nombre de modèles ont été établis à ce jour pour décrire la variation de perméabilité en fonction de l'épuisement de la pression du réservoir. Toutefois, aucune tentative n'a été faite pour attirer suffisamment l'attention sur la différence d'effet des différents facteurs sur la variation de perméabilité dans différentes phases de production des réservoirs de gaz de houille insaturés (CoalBed Methane, CBM). Le présent article résume les modèles de perméabilité existants et usuels, détermine la relation entre les différents effets (effet de contrainte effective, effet du rétrécissement

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Current status and key factors for coalbed methane development with multibranched horizontal wells in the southern Qinshui basin of China

Chen

Tang

Tao

et al. 2019

Energy Science & Engineering

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The Qinshui basin is the most successful area for coalbed methane (CBM) development in China. Since 2008, 45 multibranched horizontal wells (MBHWs) have been put into production in the Fanzhuang block, of which 10 wells have an average daily gas rate (DGR) of >10 000 m3/d. Well 4‐5 with the total gas production of 1.054 × 108 m3 achieved the China's highest DGR of 63 744 m3/d. Compared with vertical wells, MBHW is an effective way to develop CBM in low permeability reservoirs in China. However, there are still 23 wells have an average DGR of <3000 m3/d, of which 18 wells are below 1000 m3/d. The results show that shallow depth (<600 m), high gas content (>16 m3/t) and saturation (>80%), long coal seam interval (>3000 m), reasonable branch spread, and stable wellbore are the basis for achieving high production. The encountered faults connected to the aquifer will cause a high water production and an extremely low gas rate (<1000 m3/d). In the inclined coal seam, the up‐dip MBHW is more favorable for the formation water drainage and the pressure drop funnel expansion than the down‐dip MBHW, and the horizontal well should be drilled perpendicular to the high‐permeability direction to achieve a higher recovery ratio. MBHW is more sensitivity to drainage rate due to the coal fine migration in the horizontal segments, and the high pressure drop rate will lead to high frequency of stunk pump and eventually affect the gas production. Currently, the biggest challenge for CBM development with MBHW is wellbore stability. 57% of inefficient wells are caused by wellbore collapse during drilling and production processes. Here, a new type of “Roof Drilling‐Tree Shaped” horizontal well structure was presented in this work. The first “Roof Drilling‐Tree Shaped” horizontal well with a total length of 12 288 m and a coal seam interval of 9408 m was successfully applied without drilling accidents.

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Coalbed methane producibility from the Mannville coals in Alberta, Canada: A comparison of two areas

Abstract: The Mannville coals in the Fenn area, Alberta Plains, have desorbed gas content averaging 8.57 cm 3 /g (275 scf/t

Cited by 70 publications

References 14 publications

Developing synthetic reservoir type curve model for use in evaluating surface facility and gathering pipe network designs

Developing synthetic reservoir type curve model for use in evaluating surface facility and gathering pipe network designs

Permeability Variation Models for Unsaturated Coalbed Methane Reservoirs

Current status and key factors for coalbed methane development with multibranched horizontal wells in the southern Qinshui basin of China

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