Revisiting petroleum systems in the Gippsland Basin using new geochemical data

2010 ◽  
Vol 50 (2) ◽  
pp. 728 ◽  
Author(s):  
Herbert Volk ◽  
Manzur Ahmed ◽  
Chris Boreham ◽  
Peter Tingate ◽  
Neil Sherwood ◽  
...  
Keyword(s):  
Molecular Weight ◽  
Fluid Inclusions ◽  
Isotope Geochemistry ◽  
Isotopic Analysis ◽  
Oil Field ◽  
Geochemical Data ◽  
Molecular Weight Range ◽  
Petroleum Systems ◽  
History Of ◽  
Gippsland Basin

The Gippsland Basin is one of the most prolific petroleum provinces in Australia, yet the understanding of source, migration and secondary alteration of petroleum is often based on data and concepts that have been developed decades ago. For instance, the Gippsland Basin is commonly cited as an explicit example of a province dominated by oil from coal, yet there is no literature using molecular and isotope geochemistry explicitly demonstrating that generation and expulsion has been from the coal seams and not the intervening carbonaceous mudstones. In this study we will present insights from the evaluation of quantitative analyses of aromatic hydrocarbons, which will be evaluated together with low molecular weight hydrocarbon distributions from whole oil gas chromatography and aliphatic biomarker distributions of the oils. Oils are commonly incrementors of different charge events, and hence extending molecular and isotopic information from a wide molecular weight range offers a more detailed insight into the charge history of an oil field. Oil-bearing fluid inclusions are additional archives that hold keys to the fill history of petroleum reservoirs, and this contribution will also present new data on the distribution and composition of palaeo-oils trapped in fluid inclusions. Lastly, examples will be presented of how modern tools for analysis such as compound specific isotopic analysis (CSIA) of n-alkanes and isoprenoids as well as how understanding relationships between organic facies and source rock kinetics can contribute to refining our understanding of petroleum systems in the Gippsland Basin.

COMPARISON OF PALAEO OIL CHARGES WITH CURRENTLY RESERVOIRED HYDROCARBONS USING MOLECULAR AND ISOTOPIC ANALYSES OF OIL-BEARING FLUID INCLUSIONS: JABIRU OIL FIELD, TIMOR SEA

1997 ◽  
Vol 37 (1) ◽  
pp. 490 ◽  
Author(s):  
S.C. George ◽  
P.F. Greenwood ◽  
G.A. Logan ◽  
R.A. Quezada ◽  
L.S.K. Pang ◽  
...  
Keyword(s):  
Fluid Inclusion ◽  
Fluid Inclusions ◽  
Hydrocarbon Composition ◽  
Polar Compounds ◽  
Oil Field ◽  
Geochemical Data ◽  
Peak Oil ◽  
Adsorption Effect ◽  
Isotopic Analyses ◽  
Oil Source

Geochemical techniques have been used to compare the composition of oil trapped in fluid inclusions from the Jabiru oil field with currently reservoired oil. The inclusion oil is preferentially enriched in polar compounds, probably due to an adsorption effect during trapping, but this has not affected the hydrocarbon composition of the trapped oil. Source characterisation using biomarker and gasoline range hydrocarbon parameters shows that the fluid inclusion oils have the same source affinity as the current production oil. This is corroborated by the carbon isotopic compositions of high molecuJar weight n-alkanes trapped in oil-bearing fluid inclusions, which are similar to those of the production oil. Both oils have maturities in the peak oil generative window, but aromatic hydrocarbon ratios demonstrate that the fluid inclusion oil is less mature (calculated reflectance [RJ = 0.84 per cent) than the currently reservoired charge (0.92 per cent Rc). Fluid inclusion abundance data and residual oil saturations indicate the Jabiru oil column was previously significantly larger, with subsequent leakage reducing the column to its present size. The geochemical data collected for the fluid inclusion oil suggests that it is representative of early charge to the Jabiru structure. The difference between the fluid inclusion oil and the production oil is thought to reflect continued charging of the trap with progressively more mature oil from the same or similar source rock facies. The change in the molecular composition of the oil in the Jabiru structure probably occurred by dilution of earlier, lower maturity charge with larger volumes of more mature oil.

Understanding the plumbing of the Gippsland Basin: new results on fluid migration and reservoir quality

2011 ◽  
Vol 51 (2) ◽  
pp. 693
Author(s):  
Peter Tingate ◽  
Monica Campi ◽  
Geoffrey O'Brien ◽  
John Miranda ◽  
Louise Goldie Divko ◽  
...  
Keyword(s):  
Co2 Storage ◽  
Fluid Migration ◽  
Gas Field ◽  
Reservoir Characteristics ◽  
Petroleum Systems ◽  
Migration History ◽  
History Of ◽  
Hydrocarbon Charge ◽  
Gippsland Basin ◽  
Migration Pathways

Understanding the CO2 storage potential and petroleum prospectivity of the Gippsland Basin are critical to managing the resources of this region. Key controls on determining the prospectivity for CO2 storage and petroleum include understanding the fluid migration history and reservoir characteristics in the basin. Gippsland Basin hydrology, reservoir characteristics and petroleum systems are being studied to better understand how CO2 can be safely stored in the subsurface. Hydrocarbon migration pathways have been delineated using petroleum systems modelling. The latest hydrocarbon charge history data has been acquired to test the containment potential of individual structures along these migration pathways. The charge history results indicate the Golden Beach gas field has had a complex hydrocarbon fill history, and that early charge has migrated through the regional seal. The results also indicate that early oil charge was very common in the basin, including large structures that are now filled with gas (e.g. Barracouta). The results allow the regions with good CO2 containment potential to be delineated for further storage investigations. A new evaluation of the reservoir characteristics of the Latrobe Group—through porosity/permeability analysis and automated mineral analysis (AMA)—has provided insights into CO2 injectivity and capacity. The AMA results constrain the mineralogy and diagenetic history of the reservoirs and seals. In addition, the data highlights the presence of carbonates, glauconite and K-feldspar that are potentially reactive with injected CO2.

NEOGENE TECTONICS IN SE AUSTRALIA: IMPLICATIONS FOR PETROLEUM SYSTEMS

2001 ◽  
Vol 41 (1) ◽  
pp. 37 ◽  
Author(s):  
J.A. Dickinson ◽  
M.W. Wallace ◽  
G.R. Holdgate ◽  
J. Daniels ◽  
S.J. Gallagher ◽  
...  
Keyword(s):  
Late Miocene ◽  
Oil And Gas ◽  
Petroleum Exploration ◽  
Petroleum Systems ◽  
Australian Plate ◽  
Late Tertiary ◽  
Petroleum Generation ◽  
History Of ◽  
Petroleum Accumulation ◽  
Gippsland Basin

The influence of Neogene tectonics in the SE Australian basins has generally been underestimated in the petroleum exploration literature. However, onshore stratigraphic and offshore seismic data indicates that significant deformation and exhumation (up to one km or more) has occurred during the late Tertiary-Quaternary. This tectonism coincides with a change in the dynamics of the Australian plate, beginning at around 12 Ma, resulting in a WNW–ESE compressional regime which has continued to the present day.Significant late Miocene tectonism is indicated by a regional angular unconformity at around the Mio-Pliocene boundary in the onshore and nearshore successions of the SE Australian basins.Evidence of on going Pliocene- Quaternary tectonism is widespread in all of the SE Australian basins. Late Tertiary tectonism has produced structures in the offshore SE Australian basins which have been favourable targets for petroleum accumulation (e.g. Nerita structure, Torquay Sub-basin; Cormorant structure, Bass Basin). In the offshore Gippsland Basin, most of the oil- and gas-bearing structures have grown during Oligocene-Recent time. Some Gippsland Basin structures were largely produced prior to the mid- Miocene, while others have a younger structural history. In areas of intense late Tertiary exhumation and uplift (e.g. proximal to the Otway and Strzelecki Ranges), burial/maturation models of petroleum generation may be significantly affected by Neogene uplift.Many structures produced by late Miocene-Pliocene deformation are dry. These relatively young structures may post-date the major maturation episodes, with the post-structure history of the basins dominated by exhumation and cooling.

INITIAL REVIEW OF THE BIOSTRATIGRAPHY AND PETROLEUM SYSTEMS AROUND THE TASMAN SEA HYDROCARBON-PRODUCING BASINS

2006 ◽  
Vol 46 (1) ◽  
pp. 201
Author(s):  
R.A. Cook ◽  
E.M. Crouch ◽  
J.I. Raine ◽  
C.P. Strong ◽  
C.I. Uruski ◽  
...  
Keyword(s):  
New Zealand ◽  
Sequence Stratigraphy ◽  
Sedimentary Basin ◽  
Geological History ◽  
Petroleum Systems ◽  
Tasman Sea ◽  
Internal Structures ◽  
History Of ◽  
Gippsland Basin ◽  
Recent Refinement

Understanding the genesis and habitat of hydrocarbons in a sedimentary basin takes knowledge of that basin at many levels, from basic infill geology to petroleum systems, plays, prospects and detailed sequence stratigraphy. While geophysics can define the basins and their internal structures, biostratigraphy and paleogeography provide greater understanding of basin geology. Micropaleontology and palynology are the chief tools that we need to define both the environment and dimension of time.As an example, the reconstruction of the Tasman Sea region to the mid-Cretaceous (ca 120 Ma) shows that the hydrocarbon-producing Gippsland and Taranaki petroleum basins developed at similar latitudes and in similar geological contexts. Other basins within the region have been lightly explored and need evaluation as to the value of further exploration.As paleontology has developed separately in Australia and New Zealand, comparison of biostratigraphic zones and their chronostratigraphy is critical to understand the similarity or otherwise of the sedimentary record of the two regions. Recent refinement of the NZ timescale and comparative studies on Gippsland Basin wells by NZ paleontologists have provided some key insights that enable us to compare the geological history of both regions more closely, and to recognise similarities in petroleum systems that may enhance petroleum prospects on both sides of the Tasman Sea.

Geochemical underpinnings of Australia's offshore hydrocarbon prospectivity

2014 ◽  
Vol 54 (1) ◽  
pp. 415
Author(s):  
Marita Bradshaw ◽  
Dianne Edwards ◽  
Chris Boreham ◽  
Emmanuelle Grosjean ◽  
Jennifer Totterdell ◽  
...  
Keyword(s):  
Source Rock ◽  
Lower Triassic ◽  
Source Rocks ◽  
Petroleum Systems ◽  
Isotopic Analyses ◽  
Marine Source ◽  
History Of ◽  
Hydrocarbon Sources ◽  
Geochemical Analyses ◽  
Gippsland Basin

Molecular and isotopic analyses of oils and gases can provide information on the depositional environment, maturation and age of their source rocks, and the post expulsion history of the hydrocarbons generated. Source rock analyses can determine their potential to generate hydrocarbons of varying type over specific thermal ranges, as well as demonstrating the strength of oil- or gas-to-source correlations. Together, this geochemical interpretation can provide insights about the extent of petroleum systems and can help delineate the relationships between hydrocarbon occurrences in a basin and across the continent. Oils that do not fit the well-established framework of oil families and Australian petroleum systems point to new source rock fairways. Examples include vagrant oils with lacustrine affinities found at various locations on the western Australian margin. Other examples are oil occurrences in the Gippsland Basin whose geochemical signatures contrast with the dominant non-marine oils, supporting the existence of a viable marine source rock facies. In under-explored and frontier basins, geochemical analyses of potential source rocks can provide key evidence to underpin new exploration efforts. For example, the recent acreage uptake in the Bight Basin was supported by Geoscience Australia’s recovery and analysis of oil-prone marine source rocks, and in the northern Perth Basin by new geochemical analysis extending the distribution of Lower Triassic Hovea marine source rocks offshore. Geoscience Australia has now embarked on a regional petroleum geological program that includes a national source rock study aimed at identifying and characterising Australia’s hydrocarbon sources, families and systems.

scholarly journals History of petroleum systems in the southern part of the Broad Fourteens Basin

2003 ◽  
Vol 82 (1) ◽  
pp. 71-90 ◽  
Author(s):  
J.M. Verweij ◽  
H.J. Simmelink ◽  
R.T. Van Balen ◽  
P. David
Keyword(s):  
Oil Field ◽  
Source Rocks ◽  
Burial History ◽  
Petroleum Systems ◽  
Basin Modelling ◽  
Petroleum Generation ◽  
History Of ◽  
Shale Formation ◽  
Sandstone Formation ◽  
Posidonia Shale

Abstract2D Basin modelling was used to evaluate the response of source rock maturation, and of petroleum expulsion, migration, accumulation and preservation to the evolution of the southern part of the inverted Broad Fourteens Basin. Modelling results show that the temperature, maturation and petroleum generation history as well as migration characteristics of both the Jurassic oil systems and the Carboniferous gas systems vary over short distances relative to the differences in burial history of the basin. Model results indicate that no major gas accumulations are preserved in the Slochteren Formation along the cross-section at present-day. Gas accumulations are predicted in sandstone-dominated Triassic units in the southern part of the section. Present-day oil accumulations predicted in the Vlieland Sandstone Formation sealed by the Vlieland Claystone Formation (in P9 and Q1 crestal structures) are in accordance with known oil accumulations. Additional oil accumulations are predicted in the sandstone-dominated Middle Werkendam Member, and in sandstones of the Delfland Subgroup.The modelling offers an explanation for the different geochemical compositions of the accumulated oils in the P9 and Q1 areas. Modelling implies, that the oils in the Q1 oil field were sourced by remigrated oils expelled over time, from early mature to mature source rocks of the Posidonia Shale Formation. The biodegraded and water-washed nature of the Q1 oil is explained by the concentrated topography-induced groundwater flow through the Vlieland Sandstone Formation during the Late Cretaceous inversion of the basin. The oils accumulated in the P9 area were sourced from an early mature part of the Posidonia Shale Formation and were probably not affected by water washing and biodegradation because of post-inversion charging of the reservoir.

Suppressive Effect of Dextran on Platelet Adhesiveness

1966 ◽  
Vol 16 (03/04) ◽  
pp. 384-394 ◽  
Author(s):  
S Cronberg ◽  
B Robertson ◽  
Inga Marie Nilsson ◽  
J.-E Niléhn
Keyword(s):  
Molecular Weight ◽  
Bleeding Time ◽  
Slight Modification ◽  
Molecular Size ◽  
Suppressive Effect ◽  
Factor Ix ◽  
Factor V ◽  
Platelet Adhesiveness ◽  
History Of ◽  
Mean Molecular Weight

Summary43 normal volunteers, 3 patients with thrombophlebitis, and 1 patient with a high platelet adhesiveness and a history of thrombophlebitis have received dextran and its action on the mechanism of haemostasis has been studied. Platelet adhesiveness has been investigated by a slight modification of Hellem’s methods for whole blood and plasma. Dextran with a mean molecular weight of 70,000 produced a markedly lowered platelet adhesiveness together with a moderate prolongation of the Ivy bleeding time. Factor VIII was decreased by about 50% and factor V, factor IX and fibrinogen were decreased slightly more than could be expected from haemodilution alone. No fibrinolysis occurred. Dextran of lower molecular size was less potent. The possible use of dextrans as a thrombosis prophylactic agent is discussed.

scholarly journals Burial-deformation History of Folded Rocks Unraveled by Fracture Analysis, Stylolite Paleopiezometry and Vein Cement Geochemistry: A Case Study in the Cingoli Anticline (Umbria-Marche, Northern Apennines)

Geosciences ◽  
2021 ◽  
Vol 11 (3) ◽  
pp. 135
Author(s):  
Aurélie Labeur ◽  
Nicolas E. Beaudoin ◽  
Olivier Lacombe ◽  
Laurent Emmanuel ◽  
Lorenzo Petracchini ◽  
...  
Keyword(s):  
Isotope Geochemistry ◽  
Central Italy ◽  
Microstructural Analysis ◽  
Northern Apennines ◽  
Foreland Basins ◽  
Deformation History ◽  
The North ◽  
Regional Tectonic ◽  
History Of ◽  
Clumped Isotope

Unravelling the burial-deformation history of sedimentary rocks is prerequisite information to understand the regional tectonic, sedimentary, thermal, and fluid-flow evolution of foreland basins. We use a combination of microstructural analysis, stylolites paleopiezometry, and paleofluid geochemistry to reconstruct the burial-deformation history of the Meso-Cenozoic carbonate sequence of the Cingoli Anticline (Northern Apennines, central Italy). Four major sets of mesostructures were linked to the regional deformation sequence: (i) pre-folding foreland flexure/forebulge; (ii) fold-scale layer-parallel shortening under a N045 σ1; (iii) syn-folding curvature of which the variable trend between the north and the south of the anticline is consistent with the arcuate shape of the anticline; (iv) the late stage of fold tightening. The maximum depth experienced by the strata prior to contraction, up to 1850 m, was quantified by sedimentary stylolite paleopiezometry and projected on the reconstructed burial curve to assess the timing of the contraction. As isotope geochemistry points towards fluid precipitation at thermal equilibrium, the carbonate clumped isotope thermometry (Δ47) considered for each fracture set yields the absolute timing of the development and exhumation of the Cingoli Anticline: layer-parallel shortening occurred from ~6.3 to 5.8 Ma, followed by fold growth that lasted from ~5.8 to 3.9 Ma.

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