Diagenetic and Reservoir Quality Variation of Miocene Sandstone Reservoir Analogues from Three Basins of Southern California, USA

Okunuwadje, Sunday E.; Macdonald, David I. M.; Bowden, Stephen

doi:10.1007/s12583-020-1289-7

Cited by 8 publications

(6 citation statements)

References 65 publications

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“…Similar with conventional reservoirs (e.g., sandstone and carbonates rocks), porosity and permeability are two key parameters that control reservoir quality in shale rocks, which are primarily controlled by the shale composition and diagenetic processes. − For example, a large volume of primary pores was lost during the compaction, while abundant tiny OM pores could be generated during the kerogen thermal maturation and hydrocarbon expulsion. ,,, Table shows that the examined samples have similar thermal maturity levels; thus thermal maturity is not the main factor to the variations in pore structure between samples. Mineral composition results show that the samples from Ek 2 have various contents of analcite minerals (average 33%) among different shale lithofacies, which is quite different compared to the widely reported marine and transitional shales (e.g., Longmaxi Shale, Niutitang Shale, and Longtan-Dalong Shales). ,,− Thus, the effect of analcite mineral on pore development and preservation could be of importance for the evaluation of reservoir quality evaluation, which was mainly discussed in this work.…”

Section: Results and Discussionmentioning

confidence: 96%

Pore Structure Characterization and Reservoir Quality Evaluation of Analcite-Rich Shale Oil Reservoir from the Bohai Bay Basin

Yang

Jia

et al. 2021

Energy Fuels

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Pore characteristics and shale oil reservoir quality strongly influences the petroleum occurrence, enrichment, and economic production. In this work, to characterize the pore system and evaluate the reservoir quality of analcite-rich shale oil reservoir, a total of 33 shale samples from the second member of the Paleogcene Kongdian Formation (Ek2) of Bohai Bay Basin were examined using a suite of techniques, including total organic carbon (TOC) content, X-ray diffraction (XRD), field emission SEM, gas (CO2 and N2) physisorption, and mercury injection porosimetry (MIP). Six typical shale lithofacies are identified, and their pore characteristics are compared to reveal the factors affecting shale reservoir quality. The mineral matrix-related pore (e.g., intergranular and intragranular pores) is the dominant pore type in different shale lithofacies, with few organic matter (OM)-hosted pores being observed. Analcite-rich siliceous shale exhibits the largest specific surface area (SSA) and micropore volume, while the smallest is observed in analcite-rich mixed shale lithofacies. In contrast, the volume and SSA values of mesopores for siliceous shale are the largest, while mixed shale has the smallest values. Multipermeabilities of five connected pore networks were determined using the Katz-Thompson equation, and the permeability of microfractures or interlayer bedding cracks is at the micro-Darcy scale, as reflected by the first two inflection points. Permeability values for the other three inflection points reflect the matrix pore system within a nano-Darcy range. Siliceous shale has the high matrix permeability and good pore connectivity, which is favorable for fluid flow. Authigenic analcite mineral has different effects on pore development and reservoir quality depending on the shale mineral composition and diagenesis processes. Some primary pores were lost during the filling of analcite mineral in the early diagenesis period, but some intergranular pores were also protected by the rigid framework formed by analcite minerals. In addition, some secondary dissolution pores are generated during the reaction between analcite and organic acids discharged from the source rocks within the oil generation window, and the reservoir porosity and permeability can be greatly improved. Except for analcite, the TOC content is also an important factor controlling reservoir quality.

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Section: Results and Discussionmentioning

confidence: 96%

Pore Structure Characterization and Reservoir Quality Evaluation of Analcite-Rich Shale Oil Reservoir from the Bohai Bay Basin

Yang

Jia

et al. 2021

Energy Fuels

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“…Eodiagenesis of these sandstones is evident by the presence of isolated to pointed‐grain boundaries. These diagenetic fabrics are interpreted to have formed at very shallow burial depths due to light to moderate overlying sediment loads (Okunuwadje, Macdonald, et al, 2020), and may be associated with sediment dewatering, grain adjustment, grain packing and densification (Bjørlykke & Jahren, 2010; Rahman & Worden, 2016).…”

Section: Discussionmentioning

confidence: 99%

“…These diagenetic fabrics are developed by intense mechanical compaction following increased sediment load and vertical stress, squeezing grains together and reducing inter‐grain pore spaces. These diagenetic features have been linked to mesodiagenesis (Figure 14a), which typically occurs at depths exceeding 2 km (Bjørlykke & Jahren, 2010; Morad et al, 2000; Okunuwadje, 2019; Okunuwadje, Bowden, et al, 2020; Okunuwadje, Macdonald, et al, 2020; Oluwadebi et al, 2018; Schmidt & McDonald, 1984; Worden & Burley, 2003; Zeng, 2010).…”

Section: Discussionmentioning

confidence: 99%

“…Hydrocarbon incursion into petroleum reservoirs coats sandstone grains, preventing interactions between mineral grains and water medium leading to inhibition of diagenetic reactions, diffusion, and diagenetic cementation (H. Chen et al, 2017; Marchand et al, 2000; Wilkinson et al, 2004; Worden & Morad, 2003). This retards these diagenetic cements thereby preserving reservoir porosity and permeability (Okunuwadje, Bowden, et al, 2020; Okunuwadje, Macdonald, et al, 2020). However, subsequent leakages and migration from these reservoir compartments induce water ingression into the reservoir, which activates diagenetic reactions, forming cement that deteriorates reservoir porosity and permeability.…”

Section: Discussionmentioning

confidence: 99%

“…Porosity determines the hydrocarbon storage capacity, whereas permeability controls the hydrocarbon flow and production capacity (Haile et al, 2018; Ogbe, 2020; Wang et al, 2017). Unfortunately, these petrophysical properties can vary considerably within sandstone bodies and can be controlled by depositional parameters (Adepehin et al, 2022; Lai et al, 2015; Lan et al, 2016; Ogbe, 2021; Okunuwadje et al, 2017; Price et al, 2020; Saiag et al, 2016; Zahid et al, 2016), mineralogical composition (Adepehin et al, 2022; Dutton et al, 2012; Fadipe et al, 2011; Griffiths et al, 2019; Jeans, 2000; Zaid, 2013), and diagenetic fabrics (Bjørlykke, 2014; Gier et al, 2008; Henares et al, 2016; Lai et al, 2015, 2018; Okunuwadje, Bowden, et al, 2020; Okunuwadje, Macdonald, et al, 2020; Rossi et al, 2002; Sun et al, 2020; Zhao et al, 2022). Variations in these controlling factors often result in reservoir heterogeneity at different scales, ranging from micrometres to hundreds of meters (Morad et al, 2010).…”

Section: Introductionmentioning

confidence: 99%

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Influence of reservoir oil charging on diagenesis and reservoir quality: An example from Dunlin Reservoir Sandstones, East Shetland Basin, North Sea, UK

Okunuwadje,

Ogbe,

Odokuma‐Alonge

2023

Geological Journal

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The sandstone facies from two reservoir blocks (extensional fault walls) of the Dunlin Field have been studied to evaluate the impact of the reservoir charge history on the diagenesis and reservoir quality of these sandstones. The study has identified seven main reservoir sandstone facies (D1–D7) from the reservoir crestal block (oil leg) to the flank block (water leg). These sandstone facies exhibited similar diagenetic patterns, controlled by their depositional parameters, hence having the same porosity and permeability values in both reservoir blocks (legs) until hydrocarbon charging in the Late Cretaceous‐Pliocene. The burial and thermal model indicates that these reservoirs were charged at a temperature of 60–75°C during the 80–50 Ma and 95–100°C during the 10 Ma to Present, and significantly controlled the mesodiagenetic output, notably illite, and quartz authigenesis. The reservoir oil leg recorded a higher amount of recovered bitumen (ca. 95%) than the water leg (ca. 5%), indicating that hydrocarbon charging of the sandstone reservoir was progressive rather than instantaneous, first filling the water leg (palaeo‐oil leg). Subsequent leak‐off depleted this reservoir block and remigrated to fill the reservoir leg (palaeo‐water). The fluctuating oil charging and leakage between these two reservoir fault blocks modulated diagenetic alteration of these reservoir sandstones; hence is the cause of the minor disparity in porosity values between these reservoir legs contrary to the wide variation between conventional reservoir oil‐ and water‐legs distinguished by hydrocarbon emplacement with no such complex history. This study, therefore, demonstrates the importance of evaluating the depositional and diagenetic controls on reservoir quality and charging of hydrocarbon‐bearing sandstones for optimum oil production and recovery in clastic depositional settings.

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Connectivity and permeability of Zhuhai tight sandstone heterogeneous reservoirs from western Pearl River Mouth Basin (China) by nuclear magnetic resonance

Zhou

Deng²,

Wang

et al. 2022

Applied Geochemistry

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Diagenetic and Reservoir Quality Variation of Miocene Sandstone Reservoir Analogues from Three Basins of Southern California, USA

Cited by 8 publications

References 65 publications

Pore Structure Characterization and Reservoir Quality Evaluation of Analcite-Rich Shale Oil Reservoir from the Bohai Bay Basin

Pore Structure Characterization and Reservoir Quality Evaluation of Analcite-Rich Shale Oil Reservoir from the Bohai Bay Basin

Influence of reservoir oil charging on diagenesis and reservoir quality: An example from Dunlin Reservoir Sandstones, East Shetland Basin, North Sea, UK

Connectivity and permeability of Zhuhai tight sandstone heterogeneous reservoirs from western Pearl River Mouth Basin (China) by nuclear magnetic resonance

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