FLANK PLAYS AND FAULTED BASEMENT: NEW DIRECTIONS FOR THE COOPER BASIN

1991 ◽  
Vol 31 (1) ◽  
pp. 56
Author(s):  
S. Taylor ◽  
G. Solomon ◽  
N. Tupper ◽  
J. Evanochko ◽  
G. Horton ◽  
...  
Keyword(s):  
Gas Flow ◽  
Field Studies ◽  
Source Rocks ◽  
Gas Flows ◽  
The South ◽  
Gas Field ◽  
South West ◽  
Basement Reservoirs ◽  
Reservoir Potential ◽  
Cooper Basin

The Moomba and Big Lake Gas Field area has been actively explored for 25 years. However, recent drilling and field studies have identified new reservoir objectives for appraisal of established fields and for exploration in wildcat areas. Cooper Basin reserves have been increased and further additions are likely. Integration of drilling, production and pressure data for the Moomba and Big Lake Fields has resulted in the discovery of a structural-stratigraphic trap on the south-west flank of the Moomba Dome. Moomba-65 flowed gas at 9.8 MMCFD (0.27 Mm3/d) from deltaic sandstone of the Epsilon Formation (Early Permian). Similar plays are likely to be found on the flanks of other Cooper Basin fields and will become increasingly important as opportunities for conventional crestal tests of anticlines diminish.Exploration to the south-west of the Moomba Field has established the first significant gas flows from rocks beneath the conventional reservoirs of the Cooper Basin. Lycosa-1 drilled a faulted anticline and achieved a maximum gas flow of 5.0 MMCFD (0.14 Mm3/d) from fractured metasiltstone of the Dullingari Group (Ordovician). Moo- lalla-1 drilled a low-side fault terrace and flowed gas at 9.6 MMCFD (0.27 Mm3/d) from 'protoquartzite' tentatively assigned to the Dullingari Group. Consequently, structures where 'basement' reservoirs are faulted against mature Patchawarra Formation source rocks are attractive exploration targets.Petrological studies have identified 'glauconitic illite' in the Cooper Basin sequence suggesting hitherto unrecognised marine conditions. A reassessment of the source and reservoir potential of the region will be necessary if the presence of marine environments is substantiated by further studies.

THE KALLADEINA FORMATION – A WARBURTON BASIN CAMBRIAN CARBONATE PLAY

1990 ◽  
Vol 30 (1) ◽  
pp. 166 ◽  
Author(s):  
D.C. Roberts ◽  
P.G. Carroll ◽  
J. Sayers
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Source Rocks ◽  
Gas Oil ◽  
Gas Field ◽  
Oil And Gas Field ◽  
Shelf Sediments ◽  
Wrench Fault ◽  
Very High ◽  
Cooper Basin

The Warburton Basin is currently considered economic basement to the gas-oil productive Cooper Basin and the oil productive Eromanga Basin. Only 10 wells have penetrated more than 100 m of the Kalladeina Formation which is identified as the most prospective section within the Warburton Basin. The Kalladeina Formation consists of more than 1600 m of carbonate shelf sediments deposited during the early Cambrian to early Ordovician in a basin consisting of half grabens on the continental side of an active margin.Several intra-Kalladeina Formation seismic events in a 500 km2 region to the west of the Gidgealpa oil and gas field have been tied to wells with palaeontological control. Structure and isopach mapping illustrates large scale thrusts, wrench fault zones and subcrop edges for the Kalladeina Formation. Maps of unconformities and of formations above the Warburton Basin define source, seal and trap relationships.Good carbonate reservoirs have been identified in the Kalladeina Formation but the source potential of this succession appears to be restricted. The overlying Cooper Basin source rocks may have charged the underlying carbonates and this represents one of three play types identified in the area.All Warburton Basin plays are very high risk but potential reserves are also large.

SURFACE FACILITIES FOR THE SOUTH WEST QUEENSLAND GAS PROJECT

1994 ◽  
Vol 34 (1) ◽  
pp. 55
Author(s):  
Richard G. Robinson
Keyword(s):  
Full Range ◽  
Operating Experience ◽  
The South ◽  
South West ◽  
Wet Gas ◽  
High Level ◽  
The Cost ◽  
Gas Fields ◽  
Cooper Basin ◽  
Hydrocarbon Development

The South West Queensland Gas Project is the first greenfield gas development in the Cooper Basin for around 10 years. This has allowed a decade of operating experience from wet gas fields in the region to be applied in the design of the new facility. The design also took into consideration potential future expansion of the facility for increased throughput and the production of sales gas to service markets to the east and north.A greenfield hydrocarbon development in such a remote location is much more than just a gathering system and processing facility. A full range of infrastructure was also developed including telecommunications, roads, airstrip, accommodation and utilities.The project offered opportunities for a wide variety of Australian vendors and construction contractors. Many demonstrated a high level of capability to meet the cost, schedule and quality demands of a hydrocarbon development in the 1990s. Unfortunately, a number failed to demonstrate that capability.

The Nappamerri Trough, Cooper Basin unconventional plays: proving a hypothesis

2012 ◽  
Vol 52 (2) ◽  
pp. 662 ◽  
Author(s):  
Carrie Trembath ◽  
Lindsay Elliott ◽  
Mark Pitkin
Keyword(s):  
Shale Gas ◽  
Gas Flow ◽  
Primary Source ◽  
Gas Flows ◽  
Gas System ◽  
Central Trough ◽  
The Usa ◽  
Early Exploration ◽  
Structural Closure ◽  
Cooper Basin

Beach Energy has started exploring unconventional gas in the Nappamerri Trough, the central trough within the Cooper Basin, where the Permian section has long been regarded as the primary source for most of the conventional hydrocarbons found within the basin. This extended abstract discusses the data used to identify the unconventional play and the exploration program carried out to date. Mud weights, drill stem test (DST) pressures and log data from early exploration wells identified the Permian formations as overpressured. This with geochemical and mineralogy analyses indicated that the Roseneath and Murteree Shales had potential similar to successful shale gas plays being developed in the USA. The quartz and siderite content within both shale sections indicated sufficient brittleness for successful fracture stimulation. In addition, the Nappamerri Trough Permian section showed low permeabilities, which, when combined with overpressure, suggested a basin-centred style play within the Epsilon and Patchawarra sandstones and possibly the Toolachee Formation sandstones. During 2010–11, Beach drilled two exploration wells sited outside structural closure to test both the shale gas and basin centred gas system. Both wells have now been fracture stimulated, with very encouraging gas flows from the Roseneath to Patchawarra section. The latest geological data confirms the pre-drill potential for both gas flow from the shales and the presence and production of gas from sandstones outside structural closure, resulting in a significant shale and tight gas resource booking. Ongoing exploration and development will target a potential 300 Tcf gas in place in PEL 218.

scholarly journals South Kavala Gas Field - Taphrogenetic Prinos Basin

2001 ◽  
Vol 34 (3) ◽  
pp. 1221
Author(s):  
Π. ΠΡΟΕΔΡΟΥ
Keyword(s):  
Source Rocks ◽  
The South ◽  
Gas Field ◽  
Southern Limit ◽  
Coal Beds ◽  
Facies Classification ◽  
Recoverable Reserves ◽  
Sediment Deposits ◽  
Continental Deposits ◽  
Basin Formation

The South Kavala gas field located at the southwest edge of the Prinos basin was discovered at the turn of 1972 -73. The basin formation started in the middle Miocene with continental deposits. Later on the sea transgressed all over the basin until the south Kavala ridge at the southern limit lifted up and transformed it to a lagoon, leading to the formation of Evaporites in upper Miocene time. At Pliocene the sea dominated again covering even the previous mentioned ridge. An unconformity exists between Miocene and Pliocene visible mainly on the basin flanks. The trapping mechanism is a combination of a roll-over anticline in front of a northeast - southwest syngenetic fault and a pinch - out of the sediment deposits to the southwest towards the South Kavala ridge. The basement itself forms an erosional high. The gas reservoir is found between two evaporitic horizons and consists mainly of sandstone, microconglomeratic alternating with shale and marl. It is of turbiditic origin forming sedimentological cycles. Individual facies A4/B2, C and E representative of the turbidite facies classification of Walker and Mutti (1973) have been recognised. The net pay thickness is small and amounts up to eleven meters. The gas consists 83% of methan, 7.5% of ethan, 1.5% of propan and around 1.5% of butan. It is free of H2S and contains condensate. As source rocks are considered the under continental and marine conditions deposited preevaporitic shales. The coal beds are also considered to be potential source rocks. The gas is of low maturity and its generation started during latest Miocene and continued through the Pliocene. The main migrations paths apparently were along the faults that cross the basin. The in place reserves are close to 1.109m3 αερίου. The field is on production from 1981 and 80% of the recoverable reserves have been already produced.

Middle and Late Iron Age Occupation at Cadnam Farm, Alton, Hampshire

2018 ◽  
Vol 73 (1) ◽  
pp. 110-136
Author(s):  
Oliver Good ◽  
Richard Massey
Keyword(s):  
Iron Age ◽  
The South ◽  
Late Iron Age ◽  
South West ◽  
Middle Iron Age

Three individual areas, totalling 0.55ha, were excavated at the Cadnam Farm site, following evaluation. Area 1 contained a D-shaped enclosure of Middle Iron Age date, associated with the remains of a roundhouse, and a ditched drove-way. Other features included refuse pits, a four-post structure and a small post-built structure of circular plan. Area 2 contained the superimposed foundation gullies of two Middle Iron Age roundhouses, adjacent to a probable third example. Area 3 contained a small number of Middle Iron Age pits, together with undated, post-built structures of probable Middle Iron Age date, including a roundhouse and four and six-post structures. Two large boundary ditches extended from the south-west corner of Area 3, and were interpreted as the funnelled entrance of a drove-way. These contained both domestic and industrial refuse of the late Iron Age date in their fills.

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