Sandstones and Sandstone Reservoirs

Bjørlykke, Knut; Jahren, Jens

doi:10.1007/978-3-642-34132-8_4

Cited by 22 publications

(17 citation statements)

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“…The identified diagenetic reactions are the transformation of kaolinite to dickite, formation of euhedral chlorite coatings, formation of illite and mixed layer illite/smectites, and quartz and ankerite cementation (Figures and ). These diagenetic reactions occur within the diagenetic zone commonly defined as intermediate burial depths of ~2.0–3.5 km, corresponding to temperatures between 65 and 120°C (Bjørlykke & Jahren, ) or equivalently regarded as the zone of intense diagenesis between ~80–120°C (Surdam et al., ).…”

Section: Resultsmentioning

confidence: 99%

“…Rock‐Eval Tmax show a range of thermal maturity although all data fall in the oil window (Figure ) that corresponds to the background maturity of the Botneheia Formation in Edgeøya (Brekke et al., ; Krajewski, ). The oil window is found in the geological temperature range of 70–150°C (approximately 2–4 km depth) while the late burial diagenesis regime is between 65–120°C (Bjørlykke & Jahren, ; Surdam et al., ). Each sample shows a specific thermal alteration rank indicated by Tmax, while HI represents the remaining hydrocarbon generation potential (Figure ).…”

Section: Discussionmentioning

confidence: 99%

“…Diagenetic processes occurring in sedimentary rocks are routinely linked to specific burial depth and temperature (Bjørlykke & Jahren, ; Worden & Burley, ). Therefore, accurate authigenic mineral identification is necessary since their presence reveals that the sedimentary rocks have reached certain threshold temperatures.…”

Section: Methodsmentioning

confidence: 99%

“…Temperature plays a crucial role during diagenesis in sedimentary basins and is important for assessing a range of different parameters including: chemical compaction, fluid flow, estimates of the amount of uplift and erosion, heat dissipation, organic matter maturation and petroleum generation (Allen & Allen, ; Bjørkum & Nadeau, ; Bjørlykke & Jahren, ; Surdam, Crossey, Hagen, & Heasler, ; Tissot, Pelet, & Ungerer, ). Therefore, constraining the thermal history of rocks in a sedimentary basin is fundamental in forecasting reservoir quality (porosity and permeability), and evolution and maturity of source rocks, which represent common uncertainties in petroleum exploration.…”

Section: Introductionmentioning

confidence: 99%

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Thermal history of a Triassic sedimentary sequence verified by a multi‐method approach: Edgeøya, Svalbard, Norway

et al. 2018

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Temperature impacts the quality of reservoir and source rocks, thereby representing an important aspect of petroleum prospect assessments of any basin. This case study of the Triassic basin of Edgeøya, eastern Svalbard, reevaluate earlier burial estimates that were solely based on organic matter maturation data from organic rich shales. Here, we estimate temperatures using a multi‐method approach: Rock‐Eval pyrolysis parameters, fluid inclusions in diagenetic quartz, and inorganic diagenesis signatures of sandstones. Data were collected from organic rich shales of the Botneheia and Tschermakfjellet formations and coal bearing sandstones of the De Geerdalen Formation. Rock‐Eval pyrolysis data indicate that Botneheia and Tschermakfjellet formations experienced burial temperatures of about 124–138°C while the De Geerdalen Formation experienced temperatures ≥92°C. Homogenization temperatures of the De Geerdalen Formation sandstones give similar diagenetic temperatures, from 70 to 124°C, while the kaolinite to dickite transformation implies the temperatures >90°C. Furthermore, the absence of illite formation associated with kaolinite suggest that temperature have never exceed 130°C. Integrating various methods validate spatial variations in temperature proxies and constrain the thermal history of this basin. Cretaceous intrusions have locally affected the temperatures and have obscured regional subsidence and uplift trends. The effect of igneous intrusions on inorganic matter is very limited, but intensive on organic matter. These differences between organic and inorganic thermal indices help in distinguishing of magmatic from burial heating. This study has therefore relevance in deciphering the thermal history of sandstones experiencing magmatic activity coupled with multiple burial and uplift events.

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Section: Resultsmentioning

confidence: 99%

Section: Discussionmentioning

confidence: 99%

Section: Methodsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Thermal history of a Triassic sedimentary sequence verified by a multi‐method approach: Edgeøya, Svalbard, Norway

et al. 2018

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“…The methods of diagenesis in sedimentary basins are generally well understood (Bjørlykke & Jahren, 2010;Bjørlykke & Jahren, 2012;Burley & Worden, 2003;Morad, 2009;Worden & Morad, 2009;Khawaj et al, 2018). However, there is uncertainty regarding a) whether the geochemical system is open or closed during diagenesis in sedimentary basins (Bjørkum & Gjelsvik, 1988;Bjørlykke & Jahren, 2010;Gluyas&Coleman, 1992;Sullivan et al, 1990;Usman et al, 2018), and b) the origin and formation process of authigenic minerals, including clay minerals, and carbonate and quartz cements in sandstone Dowey, 2012;Worden & Morad, 2000). The Chang 7 sandstone is primarily fine-grained with extremely low permeability (typically <0.3 x 10 -3 um 2 ).…”

Section: Introductionmentioning

confidence: 99%

Diagenetic controls on reservoir quality of tight sandstone: A case study of the Upper Triassic Yanchang formation Chang 7 sandstones, Ordos Basin, China

et al. 2018

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Through a range of petrological techniques, the petrology, diagenesis, pore characteristics, and controlling factors on the regional variations of reservoir quality of the Chang 7 sandstones were studied. These sandstones, mainly arkoses, lithic arkoses, and feldspathic litharenites, were deposited in a delta front and turbidites in semi-deep to deep lacustrine. The detrital constituents were controlled by the provenance and sedimentary condition, which resulted in a spatially variable composition; e.g., high biotite and feldspar contents in the northeast (NE) of the study area, and high contents of rock fragments, especially dolomite, matrix, and quartz in the southwest (SW). Diagenesis includes intense mechanical compaction, cementation, and dissolution of unstable minerals. Diagenetic minerals which were derived internally include quartz, ankerite, ferrous calcite, albite, illite, kaolinite, and chlorite. Thus the original sandstone composition hadfirm control over the development and distribution of cement. Mechanical compaction and late-stage cementations contribute to the porosity loss of sandstones of Chang7 member. The dissolution porosity in major sandstone, slightly higher than primary porosity is principally dependent on the accessibility of acid fluid. The high content of plastic component facilitated the reduction of primary porosity and limited the mineral dissolution. The best reservoir sandstones are found in W, and partly from NE, M districts, with porosity are primary. The relatively high textural maturity of these sandstones reduces the impact of compaction on primary pores, and commonly existed chlorite rims limited the precipitation of pore filling quartz and carbonate cementation in late stage. A través de una gama de técnicas petrológicas se estudió la petrología, la diagénesis, las características de poro y los factores que controlan las variaciones regionales de la calidad del yacimiento de las areniscas Chang 7. Estas areniscas, principalmente arcosas, arcosas líticas y arenitas líticas feldespáticas, se depositaron en un frente deltáico mientras las turbiditas se depositaron en ambientes lacustres profundos y semi-profundos. Los componentes detríticos dependen de la procedencia y la condición sedimentaria, lo que resultó en una composición variable en el espacio; por ejemplo, altos contenidos de biotita y feldespato en el noreste (NE) del área de estudio, y altos contenidos de fragmentos de roca, especialmente dolomita, matriz y cuarzo en el suroeste (SW). La diagénesis incluye compactación mecánica intensa, cementación y disolución de minerales inestables. Los minerales diagenéticos que se derivaron internamente incluyen cuarzo, ankerita, calcita ferrosa, albita, illita, caolinita y clorita. Por lo tanto, la composición original de arenisca tenía un firme control sobre el desarrollo y la distribución del cemento. La compactación mecánica y las cementaciones de la última etapa contribuyen a la pérdida de porosidad de las areniscas del miembro Chang7. La porosidad de disolución en la pi...

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Sedimentary facies and reservoir characteristics of the Western Sulige field Permian He 8 tight sandstones, Ordos Basin, China

et al. 2020

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The He 8 sandstone unit in the Western Sulige field is one of the most prolific gas‐producing intervals in the Ordos Basin. Sedimentologic and reservoir characteristics analysis were conducted to investigate the reservoir's petrological, diagenetic, petrophysical properties, and production characteristics. Three sandstone types and four lithofacies were identified. The two most commonly observed lithofacies are labelled lithofacies C and D. Lithofacies C is composed of fine‐ to medium‐grained litharenites (Sandstone I); lithofacies D includes coarse‐grained sublitharenites (Sandstone II) and coarse‐grained/gravelly litharenites (Sandstone III). Compared with Lithofacies C, Lithofacies D was deposited as a series of laminated sand sheets in a higher energy fluvial system. The tightness of Sandstone I is a result of an episode of intense compaction of the rock framework causing early‐diagenetic dissolution of grains and deformation of ductile rock fragments. The processes that led to the low permeability of Sandstone II and Sandstone III are more complex. In addition to intense compaction, the growth and emplacement of quartz and clay cements are a critical factor. Diagenesis and porosity evolution analysis show that the petrophysical properties of these sandstones were better at the gas charging time. The porosity and permeability values of Sandstones II and III are similar at surface, but significantly different at formation pressure. This leads to differences in gas production rates. Sandstone II has higher gas production rates and cumulative gas production than Sandstone III. The presence or absence of Sandstone II controls the distribution of sweet spots within less productive tight gas reservoirs.

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Sandstones and Sandstone Reservoirs

Cited by 22 publications

References 16 publications

Thermal history of a Triassic sedimentary sequence verified by a multi‐method approach: Edgeøya, Svalbard, Norway

Thermal history of a Triassic sedimentary sequence verified by a multi‐method approach: Edgeøya, Svalbard, Norway

Diagenetic controls on reservoir quality of tight sandstone: A case study of the Upper Triassic Yanchang formation Chang 7 sandstones, Ordos Basin, China

Sedimentary facies and reservoir characteristics of the Western Sulige field Permian He 8 tight sandstones, Ordos Basin, China

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