Organic petrography and petroleum source rock evaluation of the Cretaceous Mamfe Formation, Mamfe basin, southwest Cameroon

Ndip, Edwin Ayuk; Agyingi, Christopher M.; Nton, M. E.; Hower, James C.; Oladunjoye, Michael A.

doi:10.1016/j.coal.2018.11.005

Cited by 20 publications

(7 citation statements)

References 25 publications

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“…However, most of the shale samples have fair potential for gaseous hydrocarbon which has not been generated at the present outcrop level until the samples attain appropriate burial depth and thermal maturity. Similar geochemical study on Cretaceous outcrop samples of the Mamfe Basin [16] yielded moderate to fair potential for gaseous hydrocarbon generation as a result of the prevalence of Type 111/ Type 1V kerogen. This is in agreement with our submission.…”

Section: Discussionmentioning

confidence: 73%

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Source Rock Evaluation of Shale in Parts of Ini Local Government Area, Akwa Ibom State, Southeastern Niger Delta Basin, Nigeria

Asuaiko

Bassey

Harry

et al. 2022

EJGEO

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Total organic carbon and Rock – Eval pyrolysis studies were conducted on seven (7) shale samples outcropping in parts of Ini Local Government Area of Akwa Ibom State, Southeastern Niger Delta, Nigeria. The studies were done to determine the quantity and quality of organic matter in the shale source rock, and their hydrocarbon generation potential. Total organic carbon (TOC) values indicate poor to excellent organic richness with values ranging from 0.46 wt.% to 5.98 wt.%. The free oil content (S1) values range from 0.02-0.21 mg HC/g rock, (mean = 0.07 mg HC/g rock), while the source rock potential (S2) ranges from 0.08-1.09 mg HC/g rock with an average value of 0.45 mg HC/g rock both indicating poor source rock generative potential. The Hydrogen Index (HI) and the Oxygen Index (OI) range from 11 mg HC/g TOC to 59 mg HC/g TOC and 41 mg CO/g TOC to 74 mg CO/g TOC with an average value of 27.28 mg HC/g TOC and 55.71 mg CO/g TOC respectively. HI versus OI and S2 versus TOC cross plot results indicate that shale in parts of Ini Local Government Area contains organic matter capable of generating kerogen type III to type 1V which is gas prone.

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Section: Discussionmentioning

confidence: 73%

“…To determine the organic richness and organic matter type, the shale samples were analyzed using the methods and procedures outlined by [1]- [5], [12]- [16]. Total organic carbon was determined using LECO C230 carbon analyzer while Rock -Eval pyrolysis was done using a Rock-Eval 6 analytical instrument.…”

Section: Methodsmentioning

confidence: 99%

Source Rock Evaluation of Shale in Parts of Ini Local Government Area, Akwa Ibom State, Southeastern Niger Delta Basin, Nigeria

Asuaiko

Bassey

Harry

et al. 2022

EJGEO

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“…The study also in volved palynological and geochem i cal re search. Such re search pro ce dures are com monly ap plied to de ter mine both the hy dro car bon po ten tial and the depositional en vi ron ments of po ten tial source rocks (Carvajal-Ortiz and Gentzis, 2018;Ndip et al, 2019;Deaf et al, 2020;Körmösa et al, 2020;Mansour et al, 2020;Mohamed et al, 2020;Abou El-Anwar et al, 2021). We in clude a dis cus sion of re la tion ships be tween the con tent and types of macerals, palynofacies and Rock-Eval data for de ter mi na tion of the hydro car bon po ten tial of the Anthracosia Shales.…”

Section: Introductionmentioning

confidence: 93%

Petrographic, palynological and geochemical recognition of dispersed organic matter in the black Anthracosia Shales (Sudetes, south-west Poland)

NOWAK¹,

GÓRECKA-NOWAK²,

Karcz

2022

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As so ci ate Ed i tor: Dariusz Wiêc³aw We de scribe the or ganic pe trog ra phy, palynology and Rock-Eval py rol y sis val ues of lac us trine black shales termed the Anthracosia Shales (Up per Car bon if er ous/Lower Perm ian) in the Intrasudetic Ba sin (Sudetes, SW Po land). Sam ples were taken from cores of two bore holes: Rybnica Leoena PIG 1 and OEcinawka OErednia PIG 1. Maceral com po si tion, miospore assem blage com po si tion, palynofacies and geo chem i cal char ac ter is tics of dis persed or ganic mat ter in the Anthracosia Shales were used to de ter mine con di tions of the en vi ron ment and to eval u ate their pe tro leum po ten tial. Data from both or ganic petrog ra phy and palynology anal y ses en abled rec og ni tion of three broadly dis tinct or ganic as so ci a tions in these shales: bi tu minous, humic, and in ter me di ate, while Rock-Eval py rol y sis re vealed the pres ence of bi tu mi nous and humic kerogen types I and III. Type I cor re sponds to the bi tu mi nous as so ci a tion, with amor phous or ganic mat ter (AOM) dom i nant in the palynofacies, and type III cor re sponds to the humic as so ci a tion with phytoclasts pre vail ing in the palynofacies. The ther mal ma tu rity of the or ganic mat ter is de ter mined by the val ues of: (1) vitrinite reflectance V Ro = 0.53-0.73%, (2) palynomorph 3-4 col our in dex, and (3) T max = 443-447°C, which in di cate oil win dow ma tu rity. Some of the TOC re sults (1.6-2.9 wt.%) in di cate that the Anthracosia Shales are good and very good pe tro leum source rocks, though the thick ness of this in ter val is low (4-5 m). Shales with TOC val ues <0.5 wt.% pre vail, and may be classifed as poor source rocks.

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“…Source rocks are the material factors that control petroleum generation and accumulation; furthermore, they are prerequisites in hydrocarbon exploration and prospect appraisal (Ghassal et al, 2018; Hakimi & Abdullah, 2014; Hu et al, 2018; Jia, Zou, Li, Li, & Zheng, 2012; Katz, 2001; Katz, 2005; Ndip, Agyingi, Nton, Hower, & Oladunjoye, 2019), especially for unconventional resources, which are mainly retained within the source rock (Chen & Osadetz, 2013; Ehsan, Gu, Akhtar, Abbasi, & Ullah, 2018; Fu, Yan, Meng, & Liu, 2019; Jarvie, Hill, Ruble, & Pollastro, 2007; Katz & Lin, 2014; Kumar et al, 2017; Li et al, 2019; Liu et al, 2020; Ndip et al, 2019; Schmoker, 2002; Zou et al, 2019). Tight oil is an unconventional resource produced from source rocks and stored in tight sandstone, carbonate, and mixed rocks reservoirs that are adjacent to source rocks (Cao et al, 2017; Hu et al, 2018; Jia et al, 2012; Li et al, 2015; Liu et al, 2019; Smith & Bustin, 2000).…”

Section: Introductionmentioning

confidence: 99%

“…Tight oil is an unconventional resource produced from source rocks and stored in tight sandstone, carbonate, and mixed rocks reservoirs that are adjacent to source rocks (Cao et al, 2017; Hu et al, 2018; Jia et al, 2012; Li et al, 2015; Liu et al, 2019; Smith & Bustin, 2000). If superior source rocks are not present, further prospecting for tight oil may be avoided (Hu et al, 2018; Ndip et al, 2019). Therefore, it is very important to determine the quality of source rock and the characteristics of hydrocarbon generation and expulsion (Katz, 2005; Lu et al, 2017; Wang, Wang, Li, & Zhang, 2019; Zou et al, 2013, 2019).…”

Section: Introductionmentioning

confidence: 99%

The hydrocarbon generation and expulsion features of source rocks and tight oil potential of the second member of the Qiketai Formation, Shengbei area in the Turpan–Hami Basin, NW China

et al. 2020

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Significant progress in tight oil exploration has been reported in the second member of the Qiketai Formation (J2q2) in the Shengbei area of the Turpan–Hami Basin. Geochemical analyses were conducted to assess the quality of the J2q2 source rocks. The improved hydrocarbon generation potential method was utilized to quantify the hydrocarbon generation and expulsion features of the source rocks. The results showed that J2q2 source rocks were deposited in a reduced lacustrine setting with a high palaeoproductivity. The J2q2 source rocks are widely distributed (approximately 1,000 km2) and have a thickness that varies from 50 to 130 m. Moreover, they can be identified as a set of high‐quality source rocks (thermally mature rocks with Ro values >0.5%, consisting mainly of types I and II kerogen and possessing an average total organic carbon content of 2.68%). The oil–source correlation results reveal that the source of crude oil in the studied area is J2q2. The improved hydrocarbon generation potential method is established for different kerogen types to limit the influence of the kerogen type on the calculation. The hydrocarbon expulsion threshold of the type I model is located at Ro = 0.6%. The type II kerogen rocks have different characteristics, and the hydrocarbon expulsion threshold is located at Ro = 0.62%. The maximum hydrocarbon generation and expulsion intensities are 700 × 104 t/km2 and 400 × 104 t/km2, respectively. The hydrocarbon generation and expulsion amount of the J2q2 source rocks are 21.4 × 108 t and 12.3 × 108 t, respectively. The tight oil potential of the J2q2 tight oil in the Shengbei area is 4.09 × 108 t. The SB10 and SB6 well areas are favourable J2q2 tight oil exploration areas in the Shengbei area. The SB10 well area has the highest hydrocarbon generation and expulsion intensities in the study area and is the best tight oil exploration target.

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Organic petrography and petroleum source rock evaluation of the Cretaceous Mamfe Formation, Mamfe basin, southwest Cameroon

Cited by 20 publications

References 25 publications

Source Rock Evaluation of Shale in Parts of Ini Local Government Area, Akwa Ibom State, Southeastern Niger Delta Basin, Nigeria

Source Rock Evaluation of Shale in Parts of Ini Local Government Area, Akwa Ibom State, Southeastern Niger Delta Basin, Nigeria

Petrographic, palynological and geochemical recognition of dispersed organic matter in the black Anthracosia Shales (Sudetes, south-west Poland)

The hydrocarbon generation and expulsion features of source rocks and tight oil potential of the second member of the Qiketai Formation, Shengbei area in the Turpan–Hami Basin, NW China

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