A New Age Interpretation For The Meluhu Formation In Toronipa Peninsula, The Southeast Arm Of Sulawesi, Indonesia

The offshore area in the northeast of Kendari city, the southeast arm of Sulawesi, is an area with favourable hydrocarbon prospectivity shown by numerous oil and gas seeps in the surrounding coastal area. It is a frontier basin in eastern Indonesia, known as the Manui Basin. An exploration well named Abuki-1 was drilled in 1990 suggested a Miocene transgressive sequence as a potential reservoir and source rock at this basin. However, this unit has no analogous exposure in the onshore area resulting in the lack of study and knowledge of this potential Miocene unit. Therefore, we revisit the sedimentary rocks exposure nearby Abuki-1 well in the Toronipa peninsula to study about its sedimentary facies and palynological contents. These outcrops by previous researchers were included in Toronipa Member of Meluhu Formation, and a Triassic age was suggested for this unit. By contrast, our result shows that these exposures are Middle to Late Miocene in age as indicated by the occurrence of the Florschuetzia group pollens (Florschuetzia trilobata, F. levipoli, and F. meridionalis). The absence of Plio-Pleistocene pollen and spores index fossils (Stenochlaena milnei group, Dacrycarpus imbricatus, and Phyllocladus) supports the Middle to Late Miocene age interpretation. A wave-dominated estuary depositional model is proposed based on the presence of river-dominated, mixed-energy, and wave-dominated facies associations. We suggest that the studied sediments are the outcrop analogues for the Middle to Late Miocene transgressive sequence found in Abuki-1 well. Furthermore, we recommend that these Miocene estuary-fill complexes should have excellent hydrocarbon potential. The reservoir potential is the sand deposits of the fluvial, tidal, washover, and shoreface facies with moderately to well-sorted characteristics. The source rocks candidate is the mud of lagoon, tidal flat, floodplain, and marine offshore facies. Moreover, the Manui Basin, with its Miocene estuarine deposits, requires further study to reveal its hydrocarbon accumulation potential.

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Petroleum geological activities onshore West Greenland in 1996, and drilling of a deep exploration well

Geological Survey of Denmark and Greenland Bulletin ◽

10.34194/ggub.v176.5055 ◽

1997 ◽

pp. 17-23 ◽

Cited By ~ 2

Author(s):

Flemming G. Christiansen ◽

Anders Boesen ◽

Finn Dalhoff ◽

Asger K. Pedersen ◽

Gunver K. Pedersen ◽

...

Keyword(s):

Late Summer ◽

Summer Season ◽

Source Rocks ◽

Press Releases ◽

West Greenland ◽

Potential Reservoir ◽

Second Year ◽

Deep Exploration ◽

Exploration Well ◽

Shed Light

NOTE: This article was published in a former series of GEUS Bulletin. Please use the original series name when citing this article, for example: Christiansen, F. G., Boesen, A., Dalhoff, F., Pedersen, A. K., Pedersen, G. K., Riisager, P., & Zinck-Jørgensen, K. (1997). Petroleum geological activities onshore West Greenland in 1996, and drilling of a deep exploration well. Geology of Greenland Survey Bulletin, 176, 17-23. https://doi.org/10.34194/ggub.v176.5055 _______________ The 1996 summer season saw continued petroleum geological activities in the Disko–Nuussuaq area, onshore West Greenland. These took the form of a geological field project led by the Geological Survey of Denmark and Greenland (GEUS), and continued commercial exploration by grønArctic Energy Inc. (grønArctic). In the second year of their licence, grønArctic carried out an airborne geophysical programme early in 1996 and drilled a c. 3 km deep exploration well on Nuussuaq, GRO#3, in the late summer (Fig. 1). Although the detailed results from grønArctic’s exploration are confidential (apart from the information made available at conferences and in press releases), it is evident that knowledge of the Nuussuaq Basin has greatly increased in recent years and that the basin has considerable exploration potential of its own (see Christiansen et al., 1995b, 1996a). The activities by GEUS and the exploration by grønArctic will significantly improve the understanding of the petroleum system of the basin; available data from the 1996 activities have shed light on the types and distribution of oils, source rocks and potential reservoir units.

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THE HYDROCARBON POTENTIAL OF THE PENOLA TROUGH, OTWAY BASIN

The APPEA Journal ◽

10.1071/aj94023 ◽

1995 ◽

Vol 35 (1) ◽

pp. 358 ◽

Cited By ~ 5

Author(s):

R. Lovibond ◽

R.J. Suttill ◽

J.E. Skinner ◽

A.N. Aburas

Keyword(s):

Early Cretaceous ◽

Seismic Data ◽

Oil And Gas ◽

Direct Detection ◽

Source Rocks ◽

Well Control ◽

Potential Reservoir ◽

Half Graben ◽

History Of

The Penola Trough is an elongate, Late Jurassic to Early Cretaceous, NW-SE trending half graben filled mainly with synrift sediments of the Crayfish Group. Katnook-1 discovered gas in the basal Eumeralla Formation, but all commercial discoveries have been within the Crayfish Group, particularly the Pretty Hill Formation. Recent improvements in seismic data quality, in conjunction with additional well control, have greatly improved the understanding of the stratigraphy, structure and hydrocarbon prospectivity of the trough. Strati-graphic units within the Pretty Hill Formation are now mappable seismically. The maturity of potential source rocks within these deeper units has been modelled, and the distribution and quality of potential reservoir sands at several levels within the Crayfish Group have been studied using both well and seismic data. Evaluation of the structural history of the trough, the risk of a late carbon dioxide charge to traps, the direct detection of gas using seismic AVO analysis, and the petrophysical ambiguities recorded in wells has resulted in new insights. An important new play has been recognised on the northern flank of the Penola Trough: a gas and oil charge from mature source rocks directly overlying basement into a quartzose sand sequence referred to informally as the Sawpit Sandstone. This play was successfully tested in early 1994 by Wynn-1 which flowed both oil and gas during testing from the Sawpit Sandstone. In mid 1994, Haselgrove-1 discovered commercial quantities of gas in a tilted Pretty Hill Formation fault block adjacent to the Katnook Field. These recent discoveries enhance the prospectivity of the Penola Trough and of the Early Cretaceous sequence in the wider Otway Basin where these sediments are within reach of the drill.

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Oil and gas prospects in the Cretaceous-Tertiary basin of West Greenland

Rapport Grønlands Geologiske Undersøgelse ◽

10.34194/rapggu.v22.7214 ◽

1969 ◽

Vol 22 ◽

pp. 1-63

Author(s):

G Henderson

Keyword(s):

Marine Sediments ◽

Oil And Gas ◽

Source Rocks ◽

Considerable Part ◽

West Greenland ◽

Reservoir Rocks ◽

True Source ◽

Potential Reservoir ◽

Greenland Basin ◽

Good Potential

The West Greenland basin contains marine and non-marine sediments ranging in age from Lower Cretaceous (Barremian-Aptian) to Paleocene (Upper Danian). The marine sediments are at least 1500 m thick in parts of Nûgssuaq and may reach 2000 m; the non-marine sediments attain a thickness of 1500 m in Nûgssuaq and Disko. Sediments older than those exposed may be present at depth. In a considerable part of the area the sediments are overlain by Tertiary basalts, which locally attain a thickness of about 8 km. The basin is fault-bounded and its coastline was probably largely fault-determined from the onset of sedimentation. Sandstone and shale are the main sedimentary types, and bituminous shales are an important part of the succession. Recent chemical analyses have shown that the bituminous shales include true source rocks; additional evidence in support of the existence of source rocks in the basin is provided by the presence of migrated hydrocarbons in sandstone close to a fault and by the presence of bitumen amongst the fluids brought to the surface in a mud volcano. The sandstones are regarded as good potential reservoir rocks, and there are good possibilities for the presence of structural and stratigraphic traps at depth. The first indications are encouraging and invite further exploration for oil and gas.

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Mid-Permian Khuff Sequence KS6: Paleorelief-influenced facies and sequence patterns in the Lower Khuff time-equivalent strata, Oman Mountains, Sultanate of Oman

GeoArabia ◽

10.2113/geoarabia1803135 ◽

2013 ◽

Vol 18 (3) ◽

pp. 135-178 ◽

Cited By ~ 3

Author(s):

Daniel Bendias ◽

Bastian Koehrer ◽

Michael Obermaier ◽

Thomas Aigner

Keyword(s):

Tectonic Activity ◽

Gulf Region ◽

Layer Cake ◽

Oman Mountains ◽

Stratigraphic Architecture ◽

Facies Associations ◽

Potential Reservoir ◽

Stratigraphic Position ◽

Lateral Extent ◽

Reservoir Potential

ABSTRACT Khuff Sequence KS6 was studied in the Al Jabal al-Akhdar, Oman Mountains, in an area of 30 x 50 square kilometers by means of detailed sedimentological logging of five time-equivalent outcrop sections of the Saiq Formation. KS6 represents one transgressive-regressive, third-order sequence, and is composed of four facies associations each representing particular environments of deposition (backshoal, shoal, foreshoal and offshoal) with distinct sedimentological characteristics. Facies stack to form cycles and cycle sets that were used for correlation at a subregional scale and to reveal the KS6 stratigraphic architecture. During the initial phase of basin-fill, clastic sediments (“Basal Saiq Clastics”) were deposited in paleolows above the “Sub-Saiq Unconformity”. In contrast to younger Upper Khuff sequences KS4 to KS1, the underlying paleorelief strongly affects the thickness and facies composition of KS6. The correlation strategy to follow paleolandscape surfaces using all available sedimentological, biostratigraphic and lithostratigraphic data resulted in a stratigraphic architecture with subtle shingle geometries. Sequence KS6 shows a strong facies partitioning resulting in the necessity of two separate facies models for the transgressive (crinoidal ramp) versus regressive hemisequence (oolitic/peloidal carbonate ramp). This study revealed potential reservoir units in KS6, commonly regarded as non-reservoir in the subsurface of Oman and other parts of the Gulf region. The abundance, nature and lateral extent of reservoir facies strongly varies with stratigraphic position. In the transgressive part of KS6, crinoidal grainstones are concentrated around the margin of a gentle paleohigh. They might have the best reservoir potential, although early diagenetic cementation is common in most settings. Oolitic/peloidal grainstones in the upper regressive part have a much higher diagenetic reservoir potential and are laterally much more widespread. Thus, Khuff Sequence KS6 differs profoundly in its stratigraphic architecture from the more “layer-cake”-like KS4 to KS1 sequences. Facies and thickness patterns are controlled by a marked paleohigh to paleolow configuration, resulting from the antecedent uneven topography during the Neo-Tethyan syn-rift setting, in contrast to the post-rift setting with low tectonic activity during KS4 to KS1.

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THE GEOLOGY AND PETROLEUM POTENTIAL OF THE WESTERN ARAFURA SEA

The APPEA Journal ◽

10.1071/aj89005 ◽

1990 ◽

Vol 30 (1) ◽

pp. 91 ◽

Cited By ~ 2

Author(s):

Jeanette M. McLennan ◽

John S. Rasidi ◽

Richard L. Holmes ◽

Greg C. Smith

Keyword(s):

Oil And Gas ◽

Source Rocks ◽

Petroleum Potential ◽

Northern Margin ◽

The North ◽

Australian Plate ◽

North Eastern ◽

Arafura Sea ◽

Good Potential ◽

Reservoir Potential

The northern Bonaparte Basin and the Arafura-Money Shoal Basins lie along Australia's offshore northern margin and offer significantly different exploration prospects resulting from their differing tectonic and burial histories. The Arafura Basin is dominated by a deep, faulted and folded, NW-SE orientated Palaeozoic graben overlain by the relatively flat-lying Jurassic-Tertiary Money Shoal Basin. The north-eastern Bonaparte Basin is dominated by the deep NE-SW orientated Malita Graben with mainly Jurassic to Recent basin-fill.A variety of potential structural and stratigraphic traps occur in the region especially associated with the grabens. They include tilted or horst fault blocks and large compressional, drape and rollover anticlines. Some inversion and possibly interference anticlines result from late Cenozoic collision between the Australian plate and Timor and the Banda Arc.In the Arafura-Money Shoal Basins, good petroleum source rocks occur in the Cambrian, Carboniferous and Jurassic-Cretaceous sequences although maturation is biassed towards early graben development. Jurassic-Neocomian sandstones have the best reservoir potential, Carboniferous clastics offer moderate prospects, and Palaeozoic carbonates require porosity enhancement.The Malita Graben probably contains good potential Jurassic source rocks which commenced generation in the Late Cretaceous. Deep burial in the graben has decreased porosity of the Jurassic-Neocomian sandstones significantly but potential reservoirs may occur on the shallower flanks.The region is sparsely explored and no commercial discoveries exist. However, oil and gas indications are common in a variety of Palaeozoic and Mesozoic sequences and structural settings. These provide sufficient encouragement for a new round of exploration.

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A preliminary assessment of carbon storage suitability in deep underground geological formations of New Brunswick, Canada

Atlantic Geology ◽

10.4138/atlgeol.2015.011 ◽

2015 ◽

Vol 51 (1) ◽

pp. 269 ◽

Cited By ~ 1

Author(s):

Dave Keighley ◽

Crystal Maher

Keyword(s):

New Brunswick ◽

Carbon Storage ◽

Oil And Gas ◽

Reservoir Rock ◽

Limited Information ◽

Gas Field ◽

Offshore Area ◽

Potential Reservoir ◽

Porosity And Permeability ◽

Carbon Dioxide Co2

An assessment of the surface and subsurface geology in New Brunswick has identified several regions, close to Large Final Emitters (industrial sites releasing carbon dioxide, CO2, into the atmosphere), underlain by large volumes of various sedimentary rocks that could act as either the reservoir or seal in a carbon storage operation. There is a lack of subsurface data with which to make an assessment for the New Brunswick Platform, the Gulf of St. Lawrence, and Northumberland Strait. In the Moncton Basin, the McCully Gas Field is hosted in tight gas sands where it would be difficult to pump down CO2 at an economical rate. The Stoney Creek Oil and Gas Field south of Moncton is not at sufficient depth for CO2 to be in a supercritical state, necessary for compressed storage. Saline reservoirs could underlie suitably large areas around these fields, but again there is limited information on the quality of the potential reservoir rock. In the Bay of Fundy, south of Saint John, one borehole indicates a prospective location that includes a saline reservoir with suitable thickness and wireline-calculated porosity and permeability, a seal with suitable thickness, and limited faulting to potentially compartmentalize the reservoir or, conversely, compromise the continuity of the seal. The major uncertainty is trap volume, which is particularly difficult to assess based on the borehole being the only data point within a 50 km radius. This is also an environmentally sensitive offshore area. Until data deficiencies are addressed, no locations can be recommended for carbon storage.

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2-D Basin modeling study of petroleum systems in the Levantine Basin, Eastern Mediterranean

GeoArabia ◽

10.2113/geoarabia160217 ◽

2011 ◽

Vol 16 (2) ◽

pp. 17-42

Author(s):

Lisa Marlow ◽

Kristijan Kornpihl ◽

Christopher G. St. C. Kendall

Keyword(s):

Oil And Gas ◽

Nile Delta ◽

Eastern Mediterranean ◽

System Modeling ◽

Passive Margin ◽

Source Rocks ◽

Petroleum Systems ◽

Levantine Basin ◽

Potential Source Rock ◽

Potential Reservoir

ABSTRACT The Levantine Basin has proven hydrocarbons, yet it is still a frontier basin. There have been significant oil and gas discoveries offshore the Nile Delta, e.g. several Pliocene gas plays and the Mango Well with ca. 10,000 bbls/day in Lower Cretaceous rocks and recently, Noble Energy discovered two gas “giants” (> 5 TCF and one estimated at 16 TFC) one of which is in a pre-Messinian strata in ca. 1,700 m (5,577 ft) water depth. Regional two-dimensional (2-D) petroleum system modeling suggests that source rocks generated hydrocarbons throughout the basin. This paper provides insight into the petroleum systems of the Levantine Basin using well and 2-D seismic data interpretations and PetroMod2D. Tectonics followed the general progression of the opening and closing of the Neo-Tethys Ocean: rift-extension, passive margin, and compression. The stratal package is up to 15 km thick and consists of mixed siliciclastic-carbonate-evaporite facies. Five potential source rock intervals (Triassic – Paleocene) are suggested. Kerogen in the older source rocks is fully transformed, whereas the younger source rocks are less mature. There are several potential reservoir and seal rocks. The model suggests that oil and gas accumulations exist in both structural and stratigraphic traps throughout the basin.

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THE PROBLEMS OF DETERMINING THE CONTENT OF KEROGEN IN THE OIL AND GAS SOURCE ROCKS

Geology Geophysics and Development of Oil and Gas Fields ◽

10.30713/2413-5011-2019-11(335)-69-74 ◽

2019 ◽

pp. 69-74

Author(s):

N.I. Samokhvalov ◽

◽

K.V. Kovalenko ◽

N.A. Skibitskaya ◽

◽

...

Keyword(s):

Oil And Gas ◽

Source Rocks ◽

Gas Source

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A possible new hydrocarbon play, offshore central West Greenland

Geological Survey of Denmark and Greenland Bulletin ◽

10.34194/ggub.v180.5082 ◽

1998 ◽

pp. 28-30

Author(s):

Nina Skaarup ◽

James A. Chalmers

Keyword(s):

Seismic Data ◽

Mineral Resources ◽

Source Rocks ◽

Bright Spot ◽

Offshore Area ◽

West Greenland ◽

The Government ◽

Structural Closure ◽

Multichannel Seismic Data ◽

Seismic Lines

NOTE: This article was published in a former series of GEUS Bulletin. Please use the original series name when citing this article, for example: Skaarup, N., & Chalmers, J. A. (1998). A possible new hydrocarbon play, offshore central West Greenland. Geology of Greenland Survey Bulletin, 180, 28-30. https://doi.org/10.34194/ggub.v180.5082 _______________ The discovery of extensive seeps of crude oil onshore central West Greenland (Christiansen et al. 1992, 1994, 1995, 1996, 1997, 1998, this volume; Christiansen 1993) means that the central West Greenland area is now prospective for hydrocarbons in its own right. Analysis of the oils (Bojesen-Koefoed et al. in press) shows that their source rocks are probably nearby and, because the oils are found within the Lower Tertiary basalts, the source rocks must be below the basalts. It is therefore possible that in the offshore area oil could have migrated through the basalts and be trapped in overlying sediments. In the offshore area to the west of Disko and Nuussuaq (Fig. 1), Whittaker (1995, 1996) interpreted a few multichannel seismic lines acquired in 1990, together with some seismic data acquired by industry in the 1970s. He described a number of large rotated fault-blocks containing structural closures at top basalt level that could indicate leads capable of trapping hydrocarbons. In order to investigate Whittaker’s (1995, 1996) interpretation, in 1995 the Geological Survey of Greenland acquired 1960 km new multichannel seismic data (Fig. 1) using funds provided by the Government of Greenland, Minerals Office (now Bureau of Minerals and Petroleum) and the Danish State through the Mineral Resources Administration for Greenland. The data were acquired using the Danish Naval vessel Thetis which had been adapted to accommodate seismic equipment. The data acquired in 1995 have been integrated with the older data and an interpretation has been carried out of the structure of the top basalt reflection. This work shows a fault pattern in general agreement with that of Whittaker (1995, 1996), although there are differences in detail. In particular the largest structural closure reported by Whittaker (1995) has not been confirmed. Furthermore, one of Whittaker’s (1995) smaller leads seems to be larger than he had interpreted and may be associated with a DHI (direct hydrocarbon indicator) in the form of a ‘bright spot’.

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Deep fluids and their role in hydrocarbon migration and oil deposit formation exemplified by supercritical СO2

Earth and Environmental Science Transactions of the Royal Society of Edinburgh ◽

10.1017/s1755691021000013 ◽

2021 ◽

pp. 1-11

Author(s):

Sara LIFSHITS

Keyword(s):

Supercritical Fluid ◽

Oil And Gas ◽

Gas Permeability ◽

Sedimentary Rocks ◽

Source Rocks ◽

Reservoir Properties ◽

Hydrocarbon Migration ◽

Geological Processes ◽

Before And After ◽

Oil Source

ABSTRACT Hydrocarbon migration mechanism into a reservoir is one of the most controversial in oil and gas geology. The research aimed to study the effect of supercritical carbon dioxide (СО2) on the permeability of sedimentary rocks (carbonates, argillite, oil shale), which was assessed by the yield of chloroform extracts and gas permeability (carbonate, argillite) before and after the treatment of rocks with supercritical СО2. An increase in the permeability of dense potentially oil-source rocks has been noted, which is explained by the dissolution of carbonates to bicarbonates due to the high chemical activity of supercritical СО2 and water dissolved in it. Similarly, in geological processes, the introduction of deep supercritical fluid into sedimentary rocks can increase the permeability and, possibly, the porosity of rocks, which will facilitate the primary migration of hydrocarbons and improve the reservoir properties of the rocks. The considered mechanism of hydrocarbon migration in the flow of deep supercritical fluid makes it possible to revise the time and duration of the formation of gas–oil deposits decreasingly, as well as to explain features in the formation of various sources of hydrocarbons and observed inflow of oil into operating and exhausted wells.

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