Geochemical characteristics, depositional environment and hydrocarbon generation modeling of the upper cretaceous Pakawau group in Taranaki Basin, New Zealand

Jumat, Nurhazwana; Shalaby, Mohamed Ragab; Haque, Akm Eahsanul; Islam, Md. Aminul; Hoon, Lim Lee

doi:10.1016/j.petrol.2017.12.088

Cited by 21 publications

(10 citation statements)

References 30 publications

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“…The ratio between S 1 and PY makes up the PI, where it is the proportion of the amount of free hydrocarbons already generated to the total amount of hydrocarbon that the organic matter is capable of generating. This parameter can be used to measure source rock thermal maturity (Peters 1986;Shalaby et al 2011Shalaby et al , 2012aEl Nady et al 2015;Qadri et al 2016;Jumat et al 2018;Osli et al 2018). In this study, PI values range from 0.0642 to 0.117.…”

Section: Toc and Rock-eval Pyrolysis Resultsmentioning

confidence: 99%

“…Therefore, Cretaceous source rocks are within the mature oil and condensate wet gas windows due to their higher vitrinite reflectance values. Vitrinite reflectance can also be plotted with T max to identify the state of thermal maturity for the organic matter (Qadri et al 2016;Jumat et al 2018). Both parameters are plotted together in Fig.…”

Section: Thermal Maturity and Hydrocarbon Generation Potentialmentioning

confidence: 99%

“…This was done based on the formation temperature and maturation history (Qadri et al 2016;Jumat et al 2018). The top of oil window for the Taratu Formation in Tara-1 well was encountered 51 Ma ago at 3100 m depth from the surface (Fig.…”

Section: Timing Of Hydrocarbon Generation and Expulsion Of The Taratumentioning

confidence: 99%

“…Various techniques of assessing a source rock as performed by Shalaby et al (2011), Qadri et al (2016 and Jumat et al (2017Jumat et al ( , 2018 have been referred to in this research. Following geochemical analysis, this study also constructs a onedimensional basin model using stratigraphic, temperature, and vitrinite reflectance data to investigate the exact timing and depth of hydrocarbon generation windows for the Taratu Formation.…”

Section: Introductionmentioning

confidence: 99%

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Hydrocarbon generation modeling and source rock characterization of the Cretaceous–Paleocene Taratu Formation, Great South Basin, New Zealand

Osli

Shalaby

Islam

2018

J Petrol Explor Prod Technol

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Hydrocarbon generation modeling and source rock characterization have been carried out on rock samples of the Taratu Formation in the Great South Basin, New Zealand. The Paleocene and Late Cretaceous Taratu Formation samples from Tara-1 well are utilized for geochemical studies. Rock-Eval pyrolysis results show that Taratu formation accommodates organic matter of excellent quantity and quality, with proliferous kerogen type II-III (oil and gas prone) and minor kerogen type III (gas prone). Hydrogen index (HI) of this formation ranges from 165.0 to 327.5 mg HC/g TOC and only Late Cretaceous source rock samples are thermally mature, with maximum pyrolysis temperature (T max ) up to 459 °C and vitrinite reflectance (% R o ) from 0.40 to 1.15% R o . One-dimensional basin modeling shows a best fit in a calibration of measured and modeled temperatures and vitrinite reflectance. The top of oil window was encountered 51 Ma ago at 3100 m and gas generation took place at 4132 m in 8 Ma ago.

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Section: Toc and Rock-eval Pyrolysis Resultsmentioning

confidence: 99%

Section: Thermal Maturity and Hydrocarbon Generation Potentialmentioning

confidence: 99%

Section: Timing Of Hydrocarbon Generation and Expulsion Of The Taratumentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Hydrocarbon generation modeling and source rock characterization of the Cretaceous–Paleocene Taratu Formation, Great South Basin, New Zealand

Osli

Shalaby

Islam

2018

J Petrol Explor Prod Technol

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“…According to the data displayed in Table 4, the isoprenoids/n-alkanes ratios used in this study are the Pr/nC 17 and Ph/nC 18 ratios (Table 4). These two parameters indicate biodegradation, maturation and diagenetic state of a source rock (Peters et al 2005;Jumat et al 2018;Osli et al 2019). Correlation of the two ratios by cross-plot can define the paleodepositional environment of the Narimba Formation (Peters et al 2005).…”

Section: Thermal Maturitymentioning

confidence: 99%

Geochemical characteristics and depositional environments of the Narimba Formation source rock, Bass Basin, Australia

Shalaby

Irwan

Osli

et al. 2020

J Petrol Explor Prod Technol

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This research aims to conduct source rock characterization on the Narimba Formation in the Bass Basin, Australia, which is made of mostly sandstone, shale and coal. The geochemical characteristics and depositional environments have been investigated through a variety of data such as rock–eval pyrolysis, TOC, organic petrography and biomarkers. Total organic carbon (TOC) values indicated good to excellent organic richness with values ranging from 1.1 to 79.2%. Kerogen typing of the examined samples from the Narimba Formation indicates that the formation contains organic matter capable of generating kerogen Type-III, Type-II-III and Type-II which is gas prone, oil–gas prone and oil prone, respectively. Pyrolysis maturity parameters (Tmax, PI), in combination with vitrinite reflectance and some biomarkers, all confirm that all samples are at early mature to mature and are in the oil and wet gas windows. The biomarkers data (the isoprenoids (Pr/Ph), CPI, isoprenoids/n-alkanes distribution (Pr/nC17 and Ph/nC18), in addition to the regular sterane biomarkers (C27, C28 and C29) are mainly used to evaluate the paleodepositional environment, maturity and biodegradation. It has been interpreted that the Narimba Formation was found to be deposited in non-marine (oxygen-rich) depositional environment with a dominance of terrestrial plant sources. All the analyzed samples show clear indication to be considered at the early mature to mature oil window with some indication of biodegradation.

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Organic geochemical characteristics of the Late Cretaceous coal and carbonaceous shale succession from the Taranaki Basin, New Zealand: Implications for sedimentary environmental setting and petroleum generation potential

Lathbl,

Haque,

Hakimi

et al. 2024

Geological Journal

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This comprehensive study investigates the organic matter characteristics within the Late Cretaceous Rakopi and Taniwha formations, based on data from four exploration wells situated in New Zealand's Taranaki Basin. It employs a multifaceted approach, integrating bulk geochemical analyses, biomarker measurements and carbon isotopes to unveil the geological history of these formations. Analytical results include total organic carbon content, ranging from 7.27 to 75.78 wt%, and generation potentials spanning from 28.24 to 309.16 mg hydrocarbon/g rock. These observations underscore the source rock potential of these Late Cretaceous strata. These rocks show a mixed organic matter of hydrogen‐rich Type II and Type II/III kerogens, as evidenced by hydrogen index values (HI) between 237 to 428 mg hydrocarbon/g rock. These formations demonstrate promise potential for both oil and gas generation. Biomarker analysis uncovers distinct signatures, featuring a pristane/phytane (Pr/Ph) ratio ranging from 3.27 to 10.91, a Tm/Ts ratio surpassing 7 and elevated concentrations of C29 regular steranes relative to C27 and C28 regular steranes. These biomarker characteristics suggest a composite organic matter composition, influenced by terrigenous organic matter, likely deposited in oxygenated fluvial deltaic environments. Bulk carbon isotopic data corroborate these findings, highlighting the abundance of terrigenous organic matter. Collectively, these insights reveal that the coal and carbonaceous shale intervals in the examined wells are in the early stages of oil generation. Therefore, the Rakopi and Taniwha formations have not yet yielded commercially viable oil and/or gas quantities. In this case, these formations hold substantial promise for future exploration activities in relatively deep wells, with limited oil expulsion from coals.

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Geochemical characteristics, depositional environment and hydrocarbon generation modeling of the upper cretaceous Pakawau group in Taranaki Basin, New Zealand

Cited by 21 publications

References 30 publications

Hydrocarbon generation modeling and source rock characterization of the Cretaceous–Paleocene Taratu Formation, Great South Basin, New Zealand

Hydrocarbon generation modeling and source rock characterization of the Cretaceous–Paleocene Taratu Formation, Great South Basin, New Zealand

Geochemical characteristics and depositional environments of the Narimba Formation source rock, Bass Basin, Australia

Organic geochemical characteristics of the Late Cretaceous coal and carbonaceous shale succession from the Taranaki Basin, New Zealand: Implications for sedimentary environmental setting and petroleum generation potential

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