Top seal bypass risk due to fracture systems, nearshore/onshore Gippsland Basin

2012 ◽  
Vol 52 (1) ◽  
pp. 397 ◽  
Author(s):  
Bozkurt Ciftci ◽  
Laurent Langhi ◽  
Silvio Giger ◽  
Julian Strand ◽  
Louise Goldie-Divko ◽  
...  
Keyword(s):  
Co2 Storage ◽  
Fault Zones ◽  
Hydrocarbon Exploration ◽  
Fracture Systems ◽  
Deformation Phase ◽  
Slip Tendency ◽  
Local Inversion ◽  
Seismic Deformation ◽  
Gippsland Basin ◽  
Assessment Factor

The extensional architecture of the Gippsland Basin was modified by a phase of contractional deformation during the Oligocene—Pleistocene postdating the main subsidence phase of the basin. This deformation caused local inversion and folding, which modified the depocentre geometry and controlled deformation of the syn-kinematic regional top-seal—the Lakes Entrance Formation. Accordingly, there is spatial variation of deformation intensity and lithofacies distribution, the latter of which possibly affected the strain accommodation behaviour of the Lakes Entrance Formation. These factors are critical and locally detrimental to seal capacity. In this study, the volume of shale distribution of the Lakes Entrance Formation was modelled and various parameters of the seismic-scale faults were computed, including shale gouge ratio, slip tendency and dilation tendency. Sub-seismic deformation was captured by strain and curvature attributes at the Latrobe unconformity, which carries the most intense imprint of the deformation phase. These parameters were correlated to known hydrocarbon seepage and leakage indicators in the basin, which could be related either to: (i) localised deformation along fault zones; or, (ii) to distributed deformation separated from the fault zones. There is generally a good match between the anomalous values of the computed parameters and the location of leakage indicators. For fault-related localised deformation zones, the match of the parameters ranks in the following order: shale gouge ratio (95%), strain (84%), curvature (84%) and slip tendency (74%). By combining these four parameters, a fault-related leakage assessment factor (FLAF) was defined and mapped across the study area. Match ratio of the parameters used to capture distributed deformation separated from the fault zones are ranked in the following order: curvature (100%), strain (100%) and volume of shale (83%). These parameters were also combined to define an ‘other’ leakages assessment factor (OLAF) and mapped across the study area. FLAF and OLAF maps are consistent with known leakage/seepage indicators in the basin and are indicative of additional areas with potential risk for top seal bypass. These risk maps provide useful input to CO2 storage and hydrocarbon exploration efforts in the basin.

The Latrobe Group and the 90-million-year beach

2013 ◽  
Vol 53 (2) ◽  
pp. 460
Author(s):  
Nick Hoffman ◽  
Natt Arian
Keyword(s):  
Sea Level ◽  
Co2 Storage ◽  
Hydrocarbon Exploration ◽  
Petroleum Exploration ◽  
3D Seismic ◽  
Fluvial Systems ◽  
Detailed Understanding ◽  
Marine Embayment ◽  
Gippsland Basin ◽  
Lake Systems

Carbon dioxide geosequestration requires a detailed understanding of the whole sedimentary section, with particular emphasis on topseals and intraformational seals. Hydrocarbon exploration is more focused on reservoirs but requires a similar basin understanding. This extended abstract reviews the knowledge gained from petroleum exploration in the Gippsland Basin to The CarbonNet Project’s exploration program for CO2 storage. The Ninety Mile Beach on the Gippsland coast is a prominent modern-day sand fairway where longshore drift transports sediments north-eastwards along a barrier-bar system, trapping lake systems behind the coastal strip. This beach is only 10,000 years old (dating to the last glacial rise of sea level) but is built on a platform of earlier beaches that can be traced back almost 90 million years to the initiation of Latrobe Group deposition in the Gippsland Basin. Using a recently compiled and open-file volume of merged 3D seismic surveys, the authors show the evolution of the Latrobe shoreline can be mapped continuously from the Upper Cretaceous to the present day. Sand fairways accumulate as a barrier-bar system at the edge of a steadily subsiding marine embayment, with distinct retrogradational geometries. Behind the barrier system, a series of trapped lakes and lagoons are mapped. In these, coal swamps, extensive shales, and tidal sediments were deposited at different stages of the sea-level curve, while fluvial systems prograded through these lowlands. Detailed 3D seismic extractions show the geometry, orientation and extent of coals, sealing shales, fluvial channels, and bayhead deltas. Detailed understanding of these reservoir and seal systems outlines multi-storey play fairways for hydrocarbon exploration and geosequestration. Use of modern basin resource needs careful coordination of activity and benefits greatly from established data-sharing practices.

CRUSTAL DEFORMATION STUDIES IN JAVA (INDONESIA) USING GPS

2009 ◽  
Vol 03 (02) ◽  
pp. 77-88 ◽  
Author(s):  
HASANUDDIN Z. ABIDIN ◽  
HERI ANDREAS ◽  
TERUYUKI KATO ◽  
TAKEO ITO ◽  
IRWAN MEILANO ◽  
...  
Keyword(s):  
Active Faults ◽  
Fault Zones ◽  
First Year ◽  
Horizontal Deformation ◽  
West Java ◽  
Plate Movement ◽  
Tsunami Earthquake ◽  
Second Year ◽  
Seismic Deformation ◽  
Large Earthquakes

Along the Java trench the Australian–Oceanic plate is moving and pushing onto and subducting beneath the Java continental crust at a relative motion of about 70 mm/yr in NNE direction. This subduction-zone process imposed tectonic stresses on the fore-arc region offshore and on the land of Java, thus causing the formation of earthquake fault zones to accommodate the plate movement. Historically, several large earthquakes happened in Java, including West Java. This research use GPS surveys method to study the inter-seismic deformation of three active faults in West Java region (i.e. Cimandiri, Lembang and Baribis faults), and the co-seismic and post-seismic deformation related to the May 2006 Yogyakarta and the July 2006 South Java earthquakes. Based on GPS surveys results it was found that the area around Cimandiri, Lembang and Baribis fault zones have the horizontal displacements of about 1 to 2 cm/yr or less. Further research is however still needed to extract the real inter-seismic deformation of the faults from those GPS-derived displacements. GPS surveys have also estimated that the May 2006 Yogyakarta earthquake was caused by the sinistral movement of the (Opak) fault with horizontal co-seismic deformation that generally was less than 10 cm. The post-seismic horizontal deformation of the July 2006 South Java tsunami earthquake has also been estimated using GPS surveys data. In the first year after the earthquake (2006 to 2007), the post-seismic deformation is generally less than 5 cm; and it becomes generally less than 3 cm in the second year (2007 to 2008).

Understanding the Flow Dynamics of CO2 Plumes in the Subsurface

2021 ◽  
Author(s):  
Florence Letitia Bebb ◽  
Kate Clare Serena Evans ◽  
Jagannath Mukherjee ◽  
Bilal Saeed ◽  
Geovani Christopher
Keyword(s):  
Carbon Capture ◽  
Oil And Gas ◽  
Co2 Storage ◽  
Flow Dynamics ◽  
Hydrocarbon Exploration ◽  
Hydrocarbon Reservoir ◽  
Exploration And Production ◽  
And Migration ◽  
Carbon Dioxide Co2 ◽  
Hydrocarbon Exploration And Production

Abstract There are several significant differences between the behavior of injected CO2 and reservoired hydrocarbons in the subsurface. These fundamental differences greatly influence the modeling of CO2 plumes. Carbon capture, utilization, and storage (CCUS) is growing in importance in the exploration and production (E&P) regulatory environment with the Oil and Gas Climate Initiative (OGCI) making CCUS a priority. Companies need to prospect for storage sites and evaluate both the short-term risks and long-term fate of stored carbon dioxide (CO2). Understanding the physics governing fluid flow is important to both CO2 storage and hydrocarbon exploration and production. In the last decade, there has been much research into the movement and migration of CO2 in the subsurface. A better understanding of the flow dynamics of CO2 plumes in the subsurface has highlighted a number of significant differences in modeling CO2 storage sites compared with hydrocarbon reservoir simulations. These differences can greatly influence reliability when modeling CO2 storage sites.

scholarly journals Assessing Natural Gas Versus CO2 Potential Underground Storage Sites in Greece: A Pragmatic Approach †

2022 ◽  
Vol 5 (1) ◽  
pp. 98
Author(s):  
Vagia Ioanna Makri ◽  
Spyridon Bellas ◽  
Vasilis Gaganis
Keyword(s):  
Natural Gas ◽  
Co2 Storage ◽  
Sedimentary Basins ◽  
Hydrocarbon Exploration ◽  
Greenhouse Gas Mitigation ◽  
Underground Storage ◽  
Pragmatic Approach ◽  
Increasing Demand ◽  
Salt Caverns

Although subsurface traps have been regularly explored for hydrocarbon exploration, natural gas and CO2 storage has drawn industrial attention over the past few decades, thanks to the increasing demand for energy resources and the need for greenhouse gas mitigation. With only one depleted hydrocarbon field in Greece, saline aquifers, salt caverns and sedimentary basins ought to be evaluated in furtherance of the latter. Within this study the potential of the Greek subsurface for underground storage is discussed. An overview and re-evaluation of the so-far studied areas is implemented based on the available data. Lastly, a pragmatic approach for the storage potential in Greece was created, delineating gaps and risks in the already proposed sites. Based on the above details, a case study for CO2 storage is presented, which is relevant to the West Katakolo field saline aquifer.

CarbonNet progress towards a declaration of identified storage formation at the Pelican site with a new high-resolution 3D seismic dataset

2020 ◽  
Vol 60 (2) ◽  
pp. 718
Author(s):  
Nick Hoffman
Keyword(s):  
High Resolution ◽  
Greenhouse Gas ◽  
Oil And Gas ◽  
Co2 Storage ◽  
Gas Storage ◽  
Frequency Resolution ◽  
Seismic Survey ◽  
3D Seismic ◽  
Long Term Storage ◽  
Gippsland Basin

The CarbonNet project is making the first ever application for a ‘declaration of an identified greenhouse gas storage formation’ (similar to a petroleum location) under the Offshore Petroleum and Greenhouse Gas Storage Act. Unlike a petroleum location, however, there is no ‘discovery’ involved in the application. Instead, a detailed technical assessment is required of the geological suitability for successful long-term storage of CO2. The key challenges to achieving a successful application relate to addressing ‘fundamental suitability determinants’ under the act and regulations. At Pelican (Gippsland Basin), a new high-resolution 3D seismic survey and over 10 nearby petroleum wells (and over 1500 basinal wells) supplement a crestal well drilled in 1967 that proved the seal and reservoir stratigraphy. The GCN18A 3D marine seismic survey has the highest spatial and frequency resolution to date in the Gippsland Basin. The survey was acquired in water depths from 15 to 35 m with a conventional eight-streamer seismic vessel, aided by LiDAR bathymetry. The 12.5 m bin size and pre-stack depth migration with multiple tomographic velocity iterations have produced an unprecedented high-quality image of the Latrobe Group reservoirs and sealing units. The 3D seismic data provides excellent structural definition of the Pelican Anticline, and the overlying Golden Beach-1A gas pool is excellent. Depositional detail of reservoir-seal pairs within the Latrobe Group has been resolved, allowing a confident assessment of petroleum gas in place and CO2 storage opportunities. The CarbonNet project is progressing with a low-risk storage concept at intra-formational level, as proven by trapped pools at nearby oil and gas fields. Laterally extensive intra-formational shales provide seals across the entire structure, providing pressure and fluid separation between the overlying shallow hydrocarbon gas pool and the deeper CO2 storage opportunity. CarbonNet is assessing this storage opportunity and progressing towards a ‘declaration of an identified greenhouse gas storage formation’.

APPROACHES TO PALAEOGEOGRAPHIC RECONSTRUCTIONS OF THE LATROBE GROUP, GIPPSLAND BASIN, SOUTHEASTERN AUSTRALIA

2005 ◽  
Vol 45 (1) ◽  
pp. 581 ◽  
Author(s):  
T. Bernecker ◽  
A.D. Partridge
Keyword(s):  
Co2 Storage ◽  
Depositional Environments ◽  
Petroleum Systems ◽  
Fine Grained ◽  
Southeastern Australia ◽  
Depositional System ◽  
Facies Associations ◽  
Marine Fossils ◽  
Coal Accumulation ◽  
Gippsland Basin

In the Gippsland Basin, the seaward extent of paralic coal occurrences can be mapped in successive time slices through the Paleocene and Eocene to provide a series of straight to gently arcuate surrogate palaeoshorelines within the petroliferous Latrobe Group. Palaeogeographic reconstructions that incorporate this information provide a unique perspective on the changes affecting a siliciclastic depositional system on a passive continental margin where basin development has been primarily controlled by thermal sag. In contrast, the absence of calcareous marine fossils and lack of extensive, widespread and thick fine-grained sediments on the marine shelf and continental slope, beyond the seaward limits of coal accumulation, have contributed to the false impression that the Latrobe Group accumulated in a largely non-marine basin. Based on the proposed model for palaeoshoreline delineation, seismic data, sequence analysis, petrography and palynology can be integrated to subdivide the main depositional environments into distinct facies associations that can be used to predict the distribution of petroleum systems elements in the basin. The application of such palaeogeographic models to the older section of the Latrobe Group can improve the identification of these petroleum systems elements in as yet unexplored parts of the Gippsland Basin. Given the recent attention paid to the basin as a CO2 storage province, palaeogeographic interpretations may be able to assist with the selection of appropriate injection sites.

scholarly journals The Use of Dynamic Models to Evaluate Potential Large-scale CO2 Storage in the Gippsland Basin, Victoria, Australia

2013 ◽  
Vol 37 ◽  
pp. 3594-3601
Author(s):  
S. Hurter ◽  
P. Probst ◽  
D. Labregere ◽  
A. Garnett ◽  
H. Holl
Keyword(s):  
Large Scale ◽  
Dynamic Models ◽  
Co2 Storage ◽  
Gippsland Basin

scholarly journals Rewards and Challenges of Seismic Monitoring for CO2 Storage: A Fluid Substitution Study in the Gippsland Basin, Victoria, Australia

2013 ◽  
Vol 37 ◽  
pp. 4145-4154 ◽  
Author(s):  
Aline Gendrin ◽  
Norzita Mat Fiah ◽  
Francois Poupeau ◽  
Lawrence J. Pekot ◽  
Andrew Garnett
Keyword(s):  
Co2 Storage ◽  
Seismic Monitoring ◽  
Fluid Substitution ◽  
Gippsland Basin
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