High-resolution sequence divisions and stratigraphic models of the Amu Darya right bank

Wu, Chongyang; Yu, Bingsong; Wang, Hongjun; Cheng, Chuanjie; Ruan, Zhuang; Guo, Tongcui; Zhang, Liang-Jie; Cheng, M.

doi:10.1007/s12517-019-4416-y

Cited by 5 publications

(6 citation statements)

References 7 publications

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“…The platform was generally submerged, and it retreated, and a rimmed shelf-type carbonate platform formed. The two 2 Geofluids stages of platform facies deposition in the ADRBB have resulted in the development of superimposed intraplatform mound-beach carbonate reservoirs in the western section and the development of longitudinally aggradational gentle-slope reef-beach carbonate reservoirs in the mideastern section [14,15]. The deposited carbonate reservoirs are mostly argillaceous limestones with high organic matter content and are a set of main source rocks in the Jurassic in the ADRBB.…”

Section: Geology Overviewmentioning

confidence: 99%

Study on Hydrocarbon Accumulation Periods Based on Fluid Inclusions and Diagenetic Sequence of the Subsalt Carbonate Reservoirs in the Amu Darya Right Bank Block

et al. 2022

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In order to provide paleofluid evidence of hydrocarbon accumulation periods in the Amu Darya Right Bank Block, microexperiments and simulations related to the Middle-Upper Jurassic Callovian-Oxfordian carbonate reservoirs were performed. On the basis of petrographic observation, the diagenetic stages were divided by cathodoluminescence, and the entrapment stages of fluid inclusions were divided by laser Raman experiment and UV epifluorescence. The hydrocarbon generation (expulsion) curve and burial (thermal) history curve of source rocks were simulated by using real drilling data coupled with geochemical parameters of source rocks, such as total organic carbon (TOC) and vitrinite reflectance ( R o ). The above results were integrated with microthermometry of fluid inclusions by inference the timing of hydrocarbon migration into the carbonate reservoirs. The horizon-flattening technique was used to process the measured seismic profile and restore the structural evolution profile. Four diagenetic periods and three hydrocarbon accumulation periods were identified. (i) For Syntaxial stage, the fluid captured by the overgrowing cement around particles is mainly seawater; (ii) for (Early) Mesogenetic burial stage, the calcite cements began to capture hydrocarbon fluids and show yellow fluorescence under UV illumination; (iii) for (Late) Mesogenetic burial stage, two sets of cleavage fissures developed in massive calcite cements, and oil inclusions with green fluorescence were entrapped in the crystal; (iv) for Telogenetic burial stage, blue fluorescent inclusions along with hydrocarbon gas inclusions developed in dully luminescent calcite veins. Based on the accurate division of hydrocarbon migration and charging stages, combined with the structural evolution history of the traps, the hydrocarbon accumulation model was established. Because two of the three sets of source rocks are of marine origin, resulting in the lack of vitrinite in the kerogen of those source rocks, there may be some deviation between the measured value of R o and the real value. Some systematic errors may occur in the thermal history and hydrocarbon generation (expulsion) history of the two sets of source rocks. Due to the limitations of seismic horizon-flattening technique—such as the inability to accurately recover the inclined strata thickness and horizontal expansion of strata—the final shape of the evolution process of structural profile may also deviate from the real state in geological history. The accumulation model established in this study was based upon the fluid inclusion experiments, which can effectively characterize the forming process of large condensate gas reservoirs in the Amu Darya Right Bank Block and quantify the timing of hydrocarbon charging. However, the hydrocarbon migration and accumulation model does not take the oil-source correlation into account, but only the relationship between the mature state of source rocks and the timing of hydrocarbon charging into the reservoirs. Subsequent research needs to conduct refined oil-source correlation to reveal the relationship between gas, condensate, source rocks, and recently discovered crude oil and more strictly constrain and modify the accumulation model, so as to finally disclose the origin of the crude oil and oil reservoir forming process in the Amu Darya Right Bank Block, evaluate the future exploration potential, and point out the direction of various hydrocarbon resources (condensate gas and crude oil).

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Section: Geology Overviewmentioning

confidence: 99%

Study on Hydrocarbon Accumulation Periods Based on Fluid Inclusions and Diagenetic Sequence of the Subsalt Carbonate Reservoirs in the Amu Darya Right Bank Block

et al. 2022

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“…The middle section includes Carlabekaul depression, Sandykly uplift, and Bieshikent depression. The eastern section consists of the Gissar piedmont thrust belt [66,67].…”

Section: Geological Settingmentioning

confidence: 99%

“…Furthermore, at the end of the Oxfordian period, a set of black mudstones with high gamma values developed in the east-central part of the basin, which is the secondary source rocks in the Amu Darya basin. In the ADRBB, the black mudstone layer, also known as the gap layer, is developed only in the middle-east of the block, with a small thickness, mostly between 5 and 20 m [66,67]. From bottom to top, the Lower to Middle Jurassic coal-bearing mudstone, the Callovian-Oxfordian carbonates, the gap layer, and the Kimmeridgian-Tithonian gypsum-salt layer form a set of the good reservoir forming assemblage, which provides a material basis for the formation of large gas fields on the ADRBB [75][76][77].…”

Section: Stratigraphic Backgroundmentioning

confidence: 99%

“…During the Oxfordian period (J 3 o), the ADRBB experienced another transgression. The carbonate platform was generally submerged and retreated and then evolved to a rimmed shelf-type carbonate platform with marginal reefs (Figure 4) [64,66]. In the Late Jurassic Kimmeridgian period, the ADRBB began to enter the gypsum deposition stage and the carbonate platform gradually degenerated into an evaporitic platform [80].…”

Section: Sedimentary Faciesmentioning

confidence: 99%

“…The carbonate reservoirs and evaporite strata were deposited on the paleo-uplift in the Jurassic Callovian-Oxfordian and Kimmeridgian-Tithonian stages, respectively, and traps that could capture the passing hydrocarbon were formed at the WB gas field and WES gas field [66,80].…”

Section: Hydrocarbon Accumulation Modelmentioning

confidence: 99%

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Origin and Characteristics of the Crude Oils and Condensates in the Callovian-Oxfordian Carbonate Reservoirs of the Amu Darya Right Bank Block, Turkmenistan

et al. 2022

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The Amu Darya Right Bank Block is located northeast of the Amu Darya basin, a large petroliferous sedimentary basin, with abundant natural gas resources in carbonate rocks under the ultra-thick gypsum-salt layer. Oil fields producing crude oils have recently been found around large gas fields. Unraveling the origins of the crude oils is crucial for effective petroleum exploration and exploitation. The origin of gas condensates and crude oils was unraveled through the use of comprehensively analytical and interpretative geochemical approaches. Based on oil-source correlation, the reservoir forming process has been restored. The bulk geochemical parameters of the local source rocks of the ADRBB indicated that the local sources have hydrocarbon generation and accumulation potential. The middle-lower Jurassic coal-bearing mudstone is gas prone, while the mudstone of the Callovian-Oxfordian gap layer is oil prone, and the organic matter type of Callovian-Oxfordian carbonate rocks is the mixed type between the two previous source rocks. The interpretation schemes for compositions of n-alkanes, pristane and phytane, C27–C28–C29 sterane distributions, C19+C20–C21–C23 tricyclic terpane distributions, extended tricyclic terpane ratio, and δ13C indicated that crude oil is likely from marine organic matter, while condensates mainly originate from terrestrial organic matter. However, from the perspective of the 18α-trisnorneohopane/17α-trisnorhopane and isomerization ratio of C29 sterane, condensates are too mature to have originated in the local source rocks of the ADRBB, whose maturity is well comparable with that of crude oils. The geochemical, geologic, and tectonic evolutions collectively indicate that the crude oils were most likely generated and migrated from the relatively shallow, lowly mature gap layer and Callovian-Oxfordian carbonate rocks of the ADRBB, while the condensates mostly originated from the relatively deep and highly mature middle-lower coal-bearing mudstone and Callovian-Oxfordian carbonate rocks in the Murgab depression in the southeast of the basin. Basement faults are the key factors affecting the types of oil and gas reservoirs. During the periods of oil and gas migration, traps with basement faults mainly captured natural gas and condensates and traps without basement faults were enriched with crude oils generated from local source rocks.

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Middle Jurassic evolution of a northern Tethyan carbonate ramp (Alborz Mountains, Iran)

Zohdi

Immenhauser

Rabbani

2021

Sedimentary Geology

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High-resolution sequence divisions and stratigraphic models of the Amu Darya right bank

Cited by 5 publications

References 7 publications

Study on Hydrocarbon Accumulation Periods Based on Fluid Inclusions and Diagenetic Sequence of the Subsalt Carbonate Reservoirs in the Amu Darya Right Bank Block

Study on Hydrocarbon Accumulation Periods Based on Fluid Inclusions and Diagenetic Sequence of the Subsalt Carbonate Reservoirs in the Amu Darya Right Bank Block

Origin and Characteristics of the Crude Oils and Condensates in the Callovian-Oxfordian Carbonate Reservoirs of the Amu Darya Right Bank Block, Turkmenistan

Middle Jurassic evolution of a northern Tethyan carbonate ramp (Alborz Mountains, Iran)

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