Quantitative hydrocarbon generation and charge risk assessment in the NW Persian Gulf: A 3D basin modeling approach

Baniasad, Alireza; Littke, Ralf; Froidl, Felix; Grohmann, Sebastian; Soleimany, Bahman

doi:10.1016/j.marpetgeo.2021.104900

Cited by 14 publications

(16 citation statements)

References 71 publications

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“…14). There is also considerable truncation of the Cenomanian to early Turonian stratigraphy along the Safaniyah-Nowrooz-Hendijan Arch in the northern Arabian Gulf (Al-Laboun, 1977;Baniasad et al, 2021). The Mishrif Formation is absent from the area around the Lekhwair Arch in SE UAE (Franco et al, 2018), indicating erosion into the Albian or the underlying succession.…”

Section: Turonian Uplift and Tectonic Overprintmentioning

confidence: 99%

“…This emphasizes the importance of characterizing the extent and nature of karstified surfaces which may potentially act both as carrier beds and thief zones to breached traps. The latter mechanism may explain exploration failures in offshore eastern Abu Dhabi (Burchette and Britton 1985) and offshore Iran (Baniasad et al, 2021(Baniasad et al, ). al., 2017.…”

Section: Exploration Opportunities In Stratigraphic Trapsmentioning

confidence: 99%

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Sequence Stratigraphy, Palaeogeography and Petroleum Plays of the Cenomanian – Turonian Succession of the Arabian Plate: An Updated Synthesis

Bromhead

Buchem

Simmons

et al. 2022

Journal of Petroleum Geology

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The Cenomanian -Turonian succession of the Arabian Plate By contrast in the Najaf intrashelf basin (Iraq), there is a significant siliciclastic component sourced from the Arabian Shield. This influx resulted in a mixed carbonatesiliciclastic ramp depositional system on the proximal, western margin of the basin, and an apparent absence of organic-rich intervals within the central basin succession. Grainy carbonate reservoir rocks are restricted to the eastern margin and are charged by older source rocks within the underlying stratigraphy.The GDE maps record the configuration of these petroleum systems elements within the Cenomanian-Turonian interval and form the basis for play screening. The Cenomanian-Turonian interval is punctuated by the major mid-Turonian unconformity which is a tectonostratigraphic boundary of considerable geological and economic significance. In the southern and eastern part of the Arabian Plate, this unconformity has a differential erosion profile that facilitates a subcrop play with exploration potential. Identifying subtle stratigraphic traps is challenging, but by combining GDE facies with the mapped preservation limit for each sequence, it is possible to identify areas where rudist-rich reservoir facies with potential karst enhancement are overlain by a regional claystone seal, high-grading areas with subcrop trap potential.

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Section: Turonian Uplift and Tectonic Overprintmentioning

confidence: 99%

Section: Exploration Opportunities In Stratigraphic Trapsmentioning

confidence: 99%

Sequence Stratigraphy, Palaeogeography and Petroleum Plays of the Cenomanian – Turonian Succession of the Arabian Plate: An Updated Synthesis

Bromhead

Buchem

Simmons

et al. 2022

Journal of Petroleum Geology

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“…Structural traps, which may involve basement, together with stratigraphic traps occur throughout the study area (Pollastro, 2003;Bordenave and Hegre, 2005). The type and volumes of the accumulated hydrocarbons are controlled by the location, development history and complexity of migration pathways (Wender et al, 1998;Baniasad et al, 2021b). Hydrocarbon entrapment and preservation was facilitated by the late timing of peak oil generation (Paleocene to Miocene or Pliocene/Pleistocene) relative to the growth of structures (Pollastro, 2003;Pitman et al, 2004;Ahlbrandt, 2014;Hakami and İnan, 2016;Baniasad et al, 2021b) and by efficient migration pathways over short distances (less than 20 km) from source kitchens to structural closures (Ahlbrandt, 2014).…”

Section: Petroleum Systems Elementsmentioning

confidence: 99%

“…Petroleum generation and expulsion from these source rocks at different levels of thermal maturity (Aqrawi and Badics, 2015;Sfidari et al, 2016;Baniasad et al, 2021a), together with complexities of charge history and petroleum mixing (e.g. Baniasad et al, 2017;Hassanzadeh et al, 2018) and often complex migration pathways (Ahlbrandt, 2014;Bordenave, 2014;Baniasad et al, 2021b), make geochemical characterization of the petroleum systems in this area challenging. Although numerous geochemical studies have been made at different scales in different sub-basins (e.g.…”

Section: Introductionmentioning

confidence: 99%

Petroleum Systems Analysis of the Eastern Arabian Plate: Chemometrics Based on a Review of the Geochemical Characteristics of Oils in Jurassic – Cenozoic Reservoirs

Baniasad

Littke

Abeed

2022

Journal of Petroleum Geology

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This paper presents the results of an integrated geochemical study of oils in Jurassic – Cenozoic reservoirs in the eastern region of the Arabian Plate. The main objective was to analyze the active petroleum systems at a regional scale across the study area which extends from NE Iraq to SE Oman and includes the entire Persian Gulf. The dataset for the study consisted of more than 500 crude oil samples from 112 oil fields and 11 different reservoir units. This dataset was compiled from both the literature and re‐evaluated geochemical and stable isotope analyses, augmented by new analytical studies. The study documents regional variations and trends in the bulk and molecular properties and stable isotope ratios of the oil samples. Two overall clans and twelve genetic oil families and sub‐families were distinguished using multivariate statistical analysis (chemometrics) based on biomarker parameters. The age, lithology, depositional setting and organic matter type of the respective source rocks for each family/sub‐family was inferred from oil geochemical fingerprints. The results provide insights into the key geological factors that control the number, size and geochemical character of oil fields in the eastern Arabian Plate. The geographical extent of the various oil families was assessed and used to evaluate charge access and to predict migration directions and migration pathways in the study area. The results indicate the value of implementing multivariate statistical analysis on “big data” along with state‐of‐the‐art geological petroleum systems analysis and interpretation of biomarker and oil composition data to investigate complex and extended petroleum systems.

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“…In recent years, great progress has been made in the study of hydrocarbon accumulation stages. Some new analytical techniques and methods, such as fluid inclusion analysis 25 , autogenic mineral isotopic dating 26 , hydrocarbon-generation kinetics 27 , and hydrocarbon geochemistry 28 , have provided more accurate analytical means for determining hydrocarbon accumulation stages. Fluid inclusions are the parts of materials that are encapsulated in the crystal lattice defects or holes of the diagenetic and ore-forming fluids and during the process of mineral crystallization and growth.…”

Section: Introductionmentioning

confidence: 99%

Effects of interactions in natural gas/water/rock system on hydrocarbon migration and accumulation

Jiang

Zhao

Huang

et al. 2021

Sci Rep

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The study of natural gas accumulation process in tight formation has become the focus of the petroleum industry. One of the priorities is the effects of interactions in natural gas/water/rock system on hydrocarbon migration and accumulation process. On the macroscopic scale, we investigate the interactions in natural gas/water/rock system by formation fluorescence test and production data analysis. One the microscopic scale, the mechanisms are revealed by mathematical analysis and experimental methods considering the variation of geological temperature and pressure. The effects of interactions in natural gas/water/rock system are also simulated by numerical simulation. The results are visualized and quantified. A novel semi-analytical method based on a physical experiment is proposed to calculate the temperature- and pressure-dependent contact angle and interface tension which reflect the interactions in the natural gas–water–rock system. This semi-analytical is embedded in the numerical simulation during the simulation of the natural gas charging process. The results indicate that with the increase of geological temperature and pressure, the contact angle will increase and the interface tension between natural gas and water will decrease. The capillary resistance in the formation will be reduced. Since the decrease of capillary resistance, the natural gas can be charged into smaller pores, so that the actual charging threshold is lower than the one originally obtained under present reservoir conditions. After considering the temperature and pressure during the accumulation process, some sand bodies that were thought not to be charged may have natural gas accumulate.

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Quantitative hydrocarbon generation and charge risk assessment in the NW Persian Gulf: A 3D basin modeling approach

Cited by 14 publications

References 71 publications

Sequence Stratigraphy, Palaeogeography and Petroleum Plays of the Cenomanian – Turonian Succession of the Arabian Plate: An Updated Synthesis

Sequence Stratigraphy, Palaeogeography and Petroleum Plays of the Cenomanian – Turonian Succession of the Arabian Plate: An Updated Synthesis

Petroleum Systems Analysis of the Eastern Arabian Plate: Chemometrics Based on a Review of the Geochemical Characteristics of Oils in Jurassic – Cenozoic Reservoirs

Effects of interactions in natural gas/water/rock system on hydrocarbon migration and accumulation

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