Facies controls on the distribution of diagenesis and compaction in fluvial-deltaic deposits

Hammer, Erik; Mørk, Mai Britt E.; Næss, Arve

doi:10.1016/j.marpetgeo.2009.11.002

Cited by 78 publications

(35 citation statements)

References 46 publications

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“…2+ 11a; 13b), which provided the necessary Fe . The formation of siderite requires suboxic to reducing environments with low sulphide concentrations (Hammer et al, 2010). The low amount of pyrite (1 vol%) in investigated samples supports ________________________ the low sulphide concentration.…”

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confidence: 51%

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Carbonate cementation in Upper Eocene clastic reservoir rocks from the North Alpine Foreland Basin (Austria)

Grundtner¹,

Groß²,

Gratzer³

et al. 2017

AJES

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A strong relationship between carbonate precipitation and microbial gas generation is evident for the Upper Eocene reservoir rocks of the North Alpine Foreland Basin. To achieve a better understanding of this relationship, 40 samples of limnic to shallow marine, gas-, oil-and water-bearing sandstones were studied to determine mineralogy and diagenetic history. The specific mineral parageneses were used to reconstruct changes in the hydrogeochemical conditions over time. Thus, authigenic mineral phases within reservoir rocks are an important archive for the reconstruction of pore fluid composition changes.The eogenetic pore space evolution of investigated Eocene sandstones is influenced by their primary mineralogy, which is strongly controlled by (i) depositional environment, (ii) detrital input and (iii) transport distances. Thus, a low compositional maturity is associated with high feldspar and high clay mineral content. Authigenic clay minerals, formed during several stages of diagenesis, play an important role for reservoir quality, due to pore space reduction.During eogenesis, authigenic micritic and sparitic carbonate phases are precipitated, which decreases the pore space. These eogenetic carbonate cements exhibit isotope values of about δ C: -5.9 to +2.2‰ and O: -8.3 to -4.3‰ [VPDB]. Some of these sam- 18ples indicate a trend towards lighter δ O values (-17.2‰), which is attributed to meteoric flush.Within the Eocene sandstones, two types of strongly cemented zones with low permeabilities can be differentiated: (i) extraordi- 13nary light δ C (-28.4‰) carbonates, which formed due to degradation of organic matter at the stage of advanced sulfate reduc- 13tion and (ii) heavy δ C (δ C: +8.7‰), which precipitated at the fermentation zone. Within the reservoir sandstones telogenesis is characterized by mineral destabilization (e.g. carbonate and feldspar corrosion) and kaolinite precipitation. The formation of authigenic kaolinite booklets resulted into a decrease in porosity.

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confidence: 51%

“…Further, the kaolinites developed in older secondary pores of authigenic cements. Lanson et al (2002) and Hammer et al (2010) emphasized that meteoric flush removes ions, amongst + others K , from the system and, hence, promotes kaolinite ra-…”

mentioning

confidence: 99%

Carbonate cementation in Upper Eocene clastic reservoir rocks from the North Alpine Foreland Basin (Austria)

Grundtner¹,

Groß²,

Gratzer³

et al. 2017

AJES

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“…The re la tion ship be tween po ros ity and car bon ate ce ment in the sam ples shows that when the po ros ity is less than 2% car bonate ce ment is more than 20%, whereas when the po ros ity is more than 15%, car bon ate ce ment does not ex ceed 5%. This sug gests that car bon ate ce ment sig nif i cantly af fects both sandstone rich in de tri tal lithic grains and sand stone rich in de tri tal quartz (e.g., Wolela and Gierlowski-Kordesch, 2007;Luo et al, 2009;Ham mer et al, 2010).…”

Section: Carbonate Cementationmentioning

confidence: 84%

“…5E). Pre cip i ta tion of kaolinite oc curs from low pH and low ionic strength wa ters (Bjorlykke et al, 1986(Bjorlykke et al, , 1989Worden and Burley, 2003;Ham mer et al, 2010). Re place ment of feld spar may also con trib ute to the for ma tion of illite (Umar et al, 2011) and, also high K + ions sup port the pre cip i ta tion of illite (Bai, 1991).…”

Section: Ta Blementioning

confidence: 99%

The influence of diagenetic alterations on porosity in the Triassic Narrabeen Group, Southern Sydney Basin, Australia

Gahtani¹

2013

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The in flu ence of diagenetic al ter ations on po ros ity in the Tri as sic Narra been Group, South ern Syd ney Ba sin, Aus tra lia Pe trog ra phy of the Tri as sic Narra been Group (South ern Syd ney Ba sin of Aus tra lia) was de scribed by thin sec tion, scan ning elec tron mi cro scope and X-ray dif frac tion tech niques. Sand stone com po si tion in cludes mostly lithic grains with mi nor quartz, feld spar, mica and heavy min er als; litharenites and sublitharenites are com mon and quartzarenites are rare. Quartz in cludes monocrystalline and polycrystalline grains while the feld spar in cludes both K-feld spar and plagioclase. Vol ca nic, sed i mentary and chert rock frag ments are pres ent. In thin sec tion po ros ity is vis i ble in all units, par tic u larly the coarse-grained de posits. Sec ond ary po ros ity is greater than the pri mary po ros ity. The diagenetic al ter ations in clude com pac tion, quartz overgrowths, authigenic clay min er als, car bon ate ce ment and authigenic feld spar. Com pac tion oc curred in all units dur ing diagenesis. Both early and late diagenetic car bon ate ce ment is im por tant in the Narra been Group. Pore-fill ing car bon ate cement re duced po ros ity whereas dis so lu tion of car bon ate re sulted in sec ond ary po ros ity. Authigenic clay min er als are widespread in all units fill ing pores and oc cur ring as grain-coat ings on de tri tal and authigenic grains. Where they coat quartz grains they pre serve po ros ity by pre vent ing growth of quartz overgrowths. Dis so lu tion of un sta ble feld spar and lithic grains pro vided sec ond ary po ros ity. In the Narra been Group, shale and siltstone are abun dant in the Wom barra Claystone, Stanwell Park Claystone, Bald Hill Claystone and New port For ma tion, form ing lithological seals and con fin ing lay ers. Mi nor sandstone beds oc cur in the Wom barra Claystone and con tain more po ros ity. Me dium-and coarse-grained sand stone is com mon in the Coal cliff Sand stone, Scarborough Sand stone and Bulgo Sand stone and shows low to mod er ate po ros ity. Thus, these sand stone units prob a bly con tain gas or wa ter.Key words: pe trog ra phy, diagenesis, pri mary po ros ity, sec ond ary po ros ity, quartz over growth, car bon ate ce ment. INTRODUCTIONIn the Syd ney Ba sin (Aus tra lia), the Narra been Group is the low er most of three Tri as sic rock units and is lo cated be tween the Up per Perm ian Illa warra Coal Mea sures and the Hawkesbury Sand stone (Ward, 1971a). Fine-grained sed i ment in the Narra been Group was pre vi ously stud ied by sev eral authors (e.g., Baker, 1956;Loughnan et al., 1964Loughnan et al., , 1974Goldbery and Hol land, 1973;Retallack, 1977). Ward (1972) noted quartzose, quartz-lithic and vol ca nic sand stones as the three sed i ment suites in the Narra been Group. Prov e nance mark ers of fore land ba sin-fill sed i ments were de ter mined by Cow an (1993). The com po si tion and tex ture of the Narra been Group were de scribed by McElroy (1954). De scrip tions of the pe trology in the N...

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“…For this study, we have interpreted lithofacies through cored and uncored sections of the available wells following Jadoon et al (2017), Zhong et al (2017), Wang et al (2014), Hammer et al (2010), Cohen et al (1996) and Seybold et al (1996). Twelve lithofacies were interpreted based on sedimentological characteristics and bioturbation markers (Table 1).…”

Section: Facies Interpretationmentioning

confidence: 99%

Integrated 3D facies modeling of the Mangahewa Formation, Maui Gas Field, Taranaki Basin, New Zealand

Haque

Islam

Shalaby

et al. 2018

J Petrol Explor Prod Technol

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Abstract3D seismic data, well logs, core-based lithofacies and photographs have been combined to interpret and model the depositional facies of the Mangahewa Formation of the Maui Gas Field, Taranaki Basin, New Zealand. The primary objective of the study is to generate a robust facies model for the Middle to Late Eocene (47-37 Ma) Mangahewa Formation of the field. The facies model has included eighteen depositional facies spatially distributed over the gas field. These facies are further subgrouped into three broad depositional facies associations, namely marginal marine, shallow marine and offshore environment. We have identified that marginal marine is the most dominant facies association (64%) within the model. The model visualizes estuarine and shoreface sand geobodies dominating over other facies within the model. Both geobodies comprise over 40% of all the facies interpreted in the field. The entire modeling process involves a novel stochastic approach using unique workflow that follows 3D gridding, coding of the facies classes and multiple iterations over the interpreted facies. The model therefore realistically visualizes potential facies responsible for "good"-quality reservoir sands in the Mangahewa Formation with possible retrogradation from older to younger succession.

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Facies controls on the distribution of diagenesis and compaction in fluvial-deltaic deposits

Cited by 78 publications

References 46 publications

Carbonate cementation in Upper Eocene clastic reservoir rocks from the North Alpine Foreland Basin (Austria)

Carbonate cementation in Upper Eocene clastic reservoir rocks from the North Alpine Foreland Basin (Austria)

The influence of diagenetic alterations on porosity in the Triassic Narrabeen Group, Southern Sydney Basin, Australia

Integrated 3D facies modeling of the Mangahewa Formation, Maui Gas Field, Taranaki Basin, New Zealand

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