Petroleum Source-Rock Evaluation and Hydrocarbon Potential in Montney Formation Unconventional Reservoir, Northeastern British Columbia, Canada

Egbobawaye, Edwin I.

doi:10.4236/nr.2017.811045

Cited by 8 publications

(5 citation statements)

References 46 publications

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“…This charge is assumed to have been generated in-situ, within the Montney Formation, and from the kerogen contained in this rock (potentially gas-prone kerogen type III or kerogen type II-III [3,[6][7]). The carbon isotope trend (C8-C19 in Figure 11) is consistent with condensates (and oils) formed from kerogencracking, which will be referred to as normal condensates, and consists of decreasing to relatively flat trends of δ 13 C values with increasing carbon number [34][35][36][37].…”

Section: Charge 1 -Normal Condensatementioning

confidence: 99%

Organic and isotope geochemistry analysis of petroleum condensates from the unconventional portion of the Montney Formation, Western Canada

César

Becker

Mayer

2020

Fuel

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Section: Charge 1 -Normal Condensatementioning

confidence: 99%

Organic and isotope geochemistry analysis of petroleum condensates from the unconventional portion of the Montney Formation, Western Canada

César

Becker

Mayer

2020

Fuel

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“…Figure4(b)) illustrated that both samples occur within the gas window[24].Further analyses show samples were kerogen types III and IV[9], respectively.The sampled depths (1713 m and 2680 m) had fair-good and mature source rocks[23] [25] [26] but with minimal ratios of kerogen type III. (Figure4(c)) ranked both samples as poor and non-producible[24] [27][28].Sirius-1 well had high TOC in the range of 1.77% -5.945% displayed from 1106 -1725 m depth section, thus very good source rocks[21] [22]. Pyrolysis data portrayed that free HCs (S1) are in the order of 0.16 and 0.98 mg HC/g while thermally extractable HCs (S2) span from 2.96 -60.01 mg HC/g[17].…”

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confidence: 99%

Geochemical Evaluation for the Hydrocarbon Potential of Source Rocks in the Anza Basin

Bett¹,

Olago²,

Ichang'I³

et al. 2021

IJG

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Anza basin is located in the extensional arm of the central African rift system in the North-Eastern part of Kenya. Cretaceous sedimentary rocks were sampled from the four wells namely, Chalbi-3, Sirius-1, Ndovu-1 and Kaisut-1. Anza basin occurs on a fault block within a Paleocene-Cretaceous rift basin. The methodological approach used for the evaluation of source rocks included petrophysical and geochemical methods to ascertain their potential. Well sections with a higher shale-volume ratio were sampled for geochemical screening to determine the organic richness and thermal maturity of potential source rocks, respectively. Source rock with organic richness ≥ 0.5% were evaluated further for their petroleum potential using Rock-Eval pyrolysis to determine their thermal maturity, organo-facies and in-situ generated hydrocarbons present in sedimentary facies. The geochemical evaluation of rock samples from the drilled wells' sections of Chalbi-3 and Sirius-1 confirmed both oil and gas potential. Gas Chromatography and Mass Spectrometry (GCMS) were used to characterize the biomarker signatures and oil-oil correlation of Sirius-1 samples. A predictive model was developed to integrate the petrophysical and geochemical data to reveal hydrocarbons' potential in the Anza basin.

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“…Here, we use θ hb = 125°in Eq. ( 12) because the majority of Montney Formation has high level of thermal maturity and lies within gas generating window (Egbobawaye, 2017). Based on the selected values of σ and θ hb , water can intrude into the hydrophobic pore with diameter of 1 nm under P in j of 167 MPa.…”

Section: Model Applicationmentioning

confidence: 99%

A fractal effective permeability model for dual-wet porous Media

Shi

Guo

Dehghanpour

et al. 2023

Adv. Geo-Energy Res.

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Recent studies have shown that the pores of some unconventional rocks can be categorized into hydrophilic pores that boarded by inorganic minerals such as quartz and hydrophobic pores that within the organic matter. The rock which consists of both hydrophilic and hydrophobic pores shows a dual-wettability behavior. The previously-proposed imbibition transient analysis technique has been applied in characterizing the pore size distribution of the dual-wet rocks by analyzing comparative oil and water imbibition data. On the basis of the determined pore size distribution, a fractal model for estimating effective permeability of the dual-wet rock was proposed. The proposed model, together with the imbibition transient analysis technique, is able to estimate effective permeability of the dual-wet rocks by using imbibition data. The proposed model can also estimate the effective permeability of hydrophilic pores and hydrophobic pores. The proposed model takes injection pressure, wettability behavior and pore size distribution of the dual-wet rock into the consideration. Our sensitivity analyses show that injection pressure affects effective permeability and hydrophobic permeability by controlling the water saturation within hydrophobic pores. The rock with higher volumetric fraction of hydrophilic pores tends to have higher hydrophilic permeability and lower hydrophobic permeability. By keeping the porosity constant, effective permeability decreases as the volumetric fraction of small pores increases.

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Petroleum Source-Rock Evaluation and Hydrocarbon Potential in Montney Formation Unconventional Reservoir, Northeastern British Columbia, Canada

Cited by 8 publications

References 46 publications

Organic and isotope geochemistry analysis of petroleum condensates from the unconventional portion of the Montney Formation, Western Canada

Organic and isotope geochemistry analysis of petroleum condensates from the unconventional portion of the Montney Formation, Western Canada

Geochemical Evaluation for the Hydrocarbon Potential of Source Rocks in the Anza Basin

A fractal effective permeability model for dual-wet porous Media

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