bluuebunny/crossref_metadata_2025 huggingface dataset:
THE MINERALOGY AND PETROLOGY OF THE PERMIAN SANDSTONES AT GIDGEALPA, SOUTH AUSTRALIA
Authors: Smale D. , Trueman N. A.
Published: August 2017

Detailed mineralogical and petrographic examinations were carried out on the gas-bearing Permian sandstones at Gidgealpa, South Australia, on behalf of Delhi Australian Petroleum Ltd. The investigation was carried out to obtain data on the possible formation damage during drilling. The rocks consist dominantly of clay-cemented protoquartzites and contain sedimentary and rare (?)granitic rock fragments in the upper members, and acid volcanics fragments in the lower members. The matrix consists of kaolin, illite and quartz. Some of the kaolin is authigenic and consists of vermicular kaolinite. Silicification of the rocks is a common feature, and its effect on the recovery of petroliferous constituents is considered significant. Treatment of the clays with artesian water, saline solution and drilling mud filtrate revealed no modification to the crystal structures, but flocculation of the clays with salt solution was evident. The significance of the laboratory characteristics of these samples to their behaviour in situ is discussed.
MICROBIOLOGICAL OIL PROSPECTING IN AUSTRALIA
Authors: Brisbane P. G. , Ladd J. N.
Published: August 2017

Russian, American and Czechoslovakian scientists have shown that soils associated with oilfields contain bacteria which actively utilise hydrocarbons. The technique of microbiological oil exploration seeks to measure those soil bacteria which grow on gaseous hydrocarbons migrating from oil and gas pools, and to distinguish them from other bacteria also capable of utilising hydrocarbons, hut whose presence in the soil is due to soil organic matter.Using radioactive tracers and gas chromatography, we have developed methods for measuring these bacteria. The measurements are most accurate when the bacteria are growing in the logarithmic phase, the time required to reach this phase increasing as the number of bacteria decrease.Bacteria grow at ethane concentrations as low as five parts per million in air, higher concentrations of ethane supporting greater bacterial activities in the soil. The growth of indigenous or inoculated bacteria on hydrocarbon gas is markedly affected by the soil environment.Small-scale surveys have been made at Moonie, Cabawin, Grange, Mt. Salt, Glen Davis, Geltwood Beach and Lakes Entrance. High rates of hydrocarbon utilisation have been found in a few samples from two of these surveys, but no large area of high activity has been discovered.
RECENT GEOLOGICAL MAPPING IN THE NORTHERN EROMANGA BASIN, QUEENSLAND
Authors: Vine R. R.
Published: August 2017

The attached map represents the generalised results of five years of systematic regional geological mapping of the northern Eromanga Basin. A new nomenclature based on lithological characteristics now replaces the classic faunal divisions which have been widely used and misused as lithological units.Gamma-ray logs of many water-bores in the northern Eromanga Basin enable good correlations to be made of the sub-surface Jurassic and Cretaceous sequence over a wide area. lithological and thickness variations indicated by these correlations are inferred to be related to deeper structure.High radioactivity, associated with three argillaceous units within the Jurassic sequence, possibly indicates marine incursions. Also, the presence of glauconite and acritarchs suggests marine conditions during deposition of the three units.Correlation of the sub-surface Jurassic units with the exposed sequence is questionable. However, it is evident that only an attenuated sequence is preserved at the present basin margin, and that at the margin periods of non-deposition or erosion were common.
SOME RECENT ADVANCES IN OFFSHORE REGIONAL RECONNAISSANCE GEOPHYSICAL SURVEY METHODS
Authors: Vale K. R.
Published: August 2017

Traditional geophysical methods in use offshore include the airborne magnetometer, underwater gravity meter, and seismic reflection with 24-channel recording and large explosive energy source. Navigation is by range-range and hyperbolic phase-comparison radio systems set up as local networks. Other methods now being used include towed magnetometer, surface gravity meter, and automatic continuous seismic profilers, and all three methods can be used for simultaneous recording from a single recording boat. Navigation systems not requiring local networks include satellite radio doppler, very low frequency phase measurement and sonar doppler devices. These may be used word-wide and 24 hours per day. A single recording boat may thus be virtually self-sufficient. The Bureau of Mineral Resources plans a survey for 1967 that will use a number of these geophysical methods and navigation aids.
RECENT ADVANCES IN GEOPHYSICAL TECHNIQUES
Authors: Watson S. J.
Published: August 2017

This paper deals briefly with some recent developments in the techniques available for investigating the magnetic, gravitational and seismic properties, of anomalies connected with sedimentary basins.There is also some conjecture as to what may be expected in the near future.
CASE HISTORY — MEREENIE FIELD
Authors: Benbow D. D.
Published: August 2017

The Mereenie field was discovered by Exoil N.L. and its partners in February, 1964, when the wildcat well Mereenie No. 1 encountered large flows of natural gas.The field is located in the central western portion of the Amadeus Basin. Exploration work prior to the drilling of this well consisted of surface geological surveys with limited gravity and seismic surveys.Mereenie No. 1 was the third wildcat well drilled in the basin by Exoil and its partners. Difficult drilling, combined with unusual subsurface conditions led to the use of air and later gas drilling techniques. An oil leg was penetrated during subsequent appraisal drilling on the field.Seven wells have been drilled to date. The in-place reserves of oil in the more porous zones are approximately 300 million barrels whilst the in-place gas reserves in the same zones exceed 500 billion cubic feet.
PALYNOLOGIC CONTRIBUTIONS TO PETROLEUM EXPLORATION IN THE PERMIAN FORMATIONS OF THE COOPER BASIN, AUSTRALIA
Authors: Paten R. J.
Published: August 2017

From 1959, when Permian spores and pollen were first identified from Delhi-Santos wells in the Cooper basin until 1967, appreciation of the palynologic succession was impeded by problems associated with the severe carbonization of the microfossils. By 1966, sufficient data had been accumulated for the elucidation of the broad palynologic framework. The Merrimelia Formation was identified as early Permian (palynologic unit Plb of Evans), the Lower and Middle Members of the Gidgealpa Formation as Lower Permian (units Plc-P3a) and the Upper Member of the Formation as Upper Permian (units P3b-P4). Breaks in the microfloral succession were noted above the Merrimelia Formation and between the Middle and Upper Members of the Gidgealpa Formation corresponding with observed litho-stratigraphic hiatuses.Well-preserved microfloras were recovered from four wells in late 1967 and early 1968, and produced a dramatic advance in knowledge of the Permian biostratigraphy. It became possible to relate the microfloral succession to the Permian palynologic stages proposed by Evans (1967), for eastern Australia. The Merrimelia Formation was referred to stage 2, while stages 3, 4 and 5 were recognised within the Gidgealpa Formation. In addition, two units of apparently short duration were recognised in each of stages 4 and 5. A six-fold biostratigraphic subdivision of the entire Permian sequence was thus possible.Palynology is finding wide application to problems encountered in current drilling and stratigraphic investigations. It has shown particular value when applied to those problems associated with the mid-Gidgealpa Formation disconformity, which is an important feature relative to hydrocarbon accumulation in the Gidgealpa Field.
REVIEW OF GEOLOGY AND CASE HISTORY OF PETROLEUM EXPLORATION IN CENTRAL EROMANGA SUB-BASIN
Authors: Laing A. C. M.
Published: August 2017

This paper summarises the exploration conducted by Alliance Oil Development Australia N.L., in its Authority to Prospect 98P Queensland, in the central Eromanga sub-basin. The development of the present subsurface picture is described. The influence of exploration in AP 98P and from adjoining tenements is outlined. Finally, the present interpretation of the subsurface geology is discussed and the writers present views regarding the petroleum potential of the central Eromanga sub-basin are given.
SEDIMENTATION AND PETROLEUM POTENTIAL OF THE JURASSIC SEQUENCE IN THE SOUTHWESTERN GREAT ARTESIAN BASIN
Authors: Nugent O. W.
Published: August 2017

Along the western margins of the southwestern Great Artesian basin the Jurassic sequence is an almost continuous sandstone section. In the eastern part of the same area, this sandstone sequence is broken by two shale-siltstone intervals, the Birkhead and Westbourne Formations. Towards the western margins of the basin these facies change into sandstone. The Murta Member of the Mooga Formation develops in the area north of Lake Frome through a facies change in the upper part of this formation from sandstone to siltstone and shale. It is postulated that the depositional conditions in the southwestern Great Artesian basin were dominantly fluviatile during most of the Jurassic and that the fine grained sediments of the Birkhead and Westbourne Formations and the Murta Member of the Mooga Formation were deposited under low energy lacustrine conditions. Abundant good quality potential petroleum reservoir rock exists throughout the entire Jurassic sequence. The lack of hydrocarbon filled traps found to date and the change of the main siltstone-shale intervals into sandstone facies in the west and southwest, imply that the Jurassic in the southwestern Great Artesian basin has been effectively flushed. However, the complex facies relationship of the sandstone and shale beds indicates that stratigraphically controlled traps may exist. The most prospective part of the Jurassic for commercial hydrocarbons appears to be in the lower part of the Hutton Sandstone.
PETROLEUM AND THE ENVIRONMENT
Authors: Langston J. D.
Published: August 2017

Energy is the base for industrialization. Petroleum is not only the major source of energy but also has the greatest growth rate amongst the more important energy sources.With industrialization has come urbanization, and with urbanization has come a recognition of conservation. The Torrey Canyon and the Santa Barbara incidents have focussed this public recognition on the oil industry.When we speak of environment, we must include such things as the automobiles we drive and the plastics we use. We must consider our total environment and control its development for the good of all mankind - that is what conservation is about.Conservation is the watchword of most of the Petroleum Industry. Esso spends in excess of five million dollars per year on direct environmental control research. The American Petroleum Institute spent three million dollars on Air and Water Conservation research in 1969, and 1970 will see an expanded budget.At present 13 per cent of U.S.A.'s production of oil and gas comes from the seabed of the Gulf and Californian coasts where some 13 thousand million dollars have been invested. Of the 8,000 wells that have been drilled in Federal waters, only 16 have blown out — 12 gas and 4 oil — and only one of the latter has resulted in significant pollution — Santa Barbara. Contrary to emotional statements, informed sources have so far concluded that little detrimental effect has been sustained on marine life, whales, seals and commercial fish. Long-term effects are now being studied.Australia this year should see the first substantial reduction in oil imports due in the main to oil from offshore sources — what effect will this have on our environment?Techniques used in oil exploration today from seismic surveys to the drilling and production phases of the industry are preplanned, using all the data that can be gathered. Safety factors are built in to every phase of the plan including casing programmes, mud systems, and blow-out preventors and crude oil loading equipment. As an additional conservation measure, procedures for handling emergencies are also planned.It is evident that the Oil Industry stands ready to do its share: are we as individuals doing ours?
THE USE OF COALS AS INDICATORS OF THE OCCURRENCE OF OIL AND GAS
Authors: Brooks J. D.
Published: August 2017

Petroleum hydrocarbons are not normal constituents of recent sediments but only appear when a certain stage of diagenesis is reached, through deeper burial. An investigation of the mechanism of formation of oil and gas has shown that an indication of the generation of oil in a sedimentary basin can be obtained by an examination of coals or coaly material encountered during drilling.Coals form a continuous diagenetic and metamorphic series beginning with peat and ending with graphite. Peat and brown coal contain the same type of hydrocarbons as are present in land plants but the composition of coal hydrocarbons changes abruptly in the sub-bituminous to high-volatile bituminous coal range. This is because petroleum-type hydrocarbons are formed at this stage from precursors which are components of waxy leaf cuticles, pollen and spore coatings, by chemical reactions in which oxygen groups are removed from long-chain acids, alcohols and ester waxes. Most Australian oil occurrences are associated with coal-bearing sediments and it appears likely that they are formed at the same stage of alteration, from such land plant residues, finely disseminated in shales and siltstones.The diagenetic changes in coal composition are caused by the increasing temperature accompanying deeper burial, and the composition of a coal, whatever its present depth, is an indication of the maximum temperature to which it has been subjected. The determination of carbon content, reflectivity and other properties of coal samples provided by a number of oil companies, together with laboratory experiments in which petroleum-type hydrocarbons were generated by artificial diagenesis of coal components, indicated that hydrocarbon generation takes place only when the carbon content of the coals approaches 80 percent. In sedimentary basins in Australia the petroleum generation zone occurs at depths varying from 5,500 to greater than 11,000ft., depending upon present or past geothermal gradient.In addition to this lower limit of diagenesis, it has long been maintained that a relation exists (the Carbon Ratio theory) between the likely occurrence of oil and gas reservoirs in a sedimentary basin and the degree of metamorphism of coal if present. The theory sets an upper limit of alteration of organic matter, and states that oil reservoirs are unlikely to occur in areas or at depths in a basin where the 'fixed-carbon' of the coals is greater than about 65 percent (equivalent to a coal of about 85 percent total carbon — dry, mineral-matter free). The Gid-gealpa-Moomba area appears to be a part of the Cooper Basin in which the organic matter is close to this upper limit of metamorphism. The carbon content of the coal at Gidgealpa, associated with gas and light hydrocarbons, is 85-86 percent whereas that at Moomba, associated with dry gas, is higher at approximately 89 percent.Ihus the properties of coal samples encountered during drilling can provide valuable clues for the petroleum geologist in the search for further oil and gas reserves.
WHY EXPLORE FOR OIL AND WHERE?
Authors: Warman H. R.
Published: August 2017

The title of this paper is the question that every oil explorer, individual or corporate must perpetually ponder but which is seldom set out systematically and formally. The variables are too great for any simple, unequivocal answer, and this presentation does not attempt to give many answers.A review is given of how and where oil has been found historically, giving the general geographical and geological distribution. It covers briefly the history of production and some speculations on projected future demands in order to provide the basis for the needs for future discovery. An attempt is made to review the main possibilities of future discovery by geological type and by geographical regions.The main conclusion is that large reserves of oil still need to be discovered and that we have no simple criteria for deciding where it will come from, and that even the selection of prime areas for exploration is still prone to gross uncertainty.
RECENT INFORMATION AND PROSPECTS IN THE KIDSON SUB-BASIN
Authors: Creevey K. J.
Published: August 2017

A deep sedimentary depression, the Kidson Sub-basin, has been indicated within the southern Canning Basin by gravity and aeromagnetism. The wells, Sahara 1, Kidson 1 and Wilson Cliffs 1, showed that at least 15,000 feet of Phanaerozoic sediments were present. This paper aims to summarise information given by these wells and to indicate prospects and techniques for further exploration in the sub-basin.Previous surface geology had indicated Mesozoic and Permian sediments in the area bordered by Proterozoic outcrop. Geomorphological mapping techniques have been successfully used by Aquitaine to indicate possible structures for seismic work.Seismic results from Wapet and Aquitaine indicate gentle diastrophism within the sub-basin with the existence of a palaeogeographic limit to pre-Permian sediments in the east.The western Canning Basin had previously shown a Mesozoic and Permian sequence overlaying Ordovician shales, limestones and sandstones on igneous and metamorphic basement.Sahara 1, and later Kidson 1 and Wilson Cliffs 1, proved the presence of a Middle and pre-Middle Devonian limestone — red bed — evaporite sequence in the sub-basin: the MellinjerieLimestone, Tandalgoo Red Beds and Carribuddy Formation. The underlying Ordovician shales and tight sandstones in Wilson Cliffs 1 can be correlated with the Horn Valley to Pacoota Formations in the Amadeus Basin. In Wilson Cliffs 1 these sandstones overlie Proterozoic shales.The only show noted was minor wet gas associated with Ordovician dolomites in Wilson Cliffs 1. A major petroleum prospect of the sub-basin could be sought in improvement in the reservoir capabilities of the Ordovician sandstones along the palaegeographic eastern margin of the basin.Favourable pinchout forms of these Ordovician sandstones have been found by recent refraction seismic. Refraction, combined with gravity, geomorphology and detailed seismic techniques, can outline drillable prospects along the Kidson Sub-basin.
CONTINENTAL MARGIN TECTONICS AND THE EVOLUTION OF SOUTH EAST AUSTRALIA
Authors: Griffiths J. R.
Published: August 2017

Following recent advances in geotectonics, a new approach can be applied to the study of the development of continental margins.A continental margin begins to form as an older continental craton breaks up. The initial crack develops into a rift valley, which becomes filled with thick clastic and volcanic deposits. As separation continues a new mid-ocean ridge is formed, and the two plates begin to drift apart more rapidly. At this stage the structural evolution of the margins is virtually complete, and marine sediments are deposited unconformably across the fault troughs.The continental fragments in the south west Pacific can be reassembled as a part of the ancient continent of Gondwanaland. Gondwanaland began to break up in the mid-Jurassic. A rift valley developed along the line of the present southern coast of Australia, through the Otway Basin. Two subsidiary tensional splays gave rise to the Elliston and Robe-Penola Troughs. Clastic sediments stripped from the cratonic highlands, and alkali basalts, occur in the rift grabens. Faulting and deposition continued throughout the Lower Cretaceous. About mid-Cretaceous a marine transgression from the west entered the subdividing rift valley. In the Eocene a new mid-ocean ridge formed and the Australian and Antarctic plates began to separate more rapidly. After this, quiet marine sedimentation occurred on the continental shelf and slope.The Bass and Gippsland Basins began to develop in the Cretaceous as differential movement occurred between the main Australian plate and a partially detached Tasmanian sub-plate. In the Upper Cretaceous the Gippsland Basin became open towards the evolving Tasman Sea, as New Zealand detached. The Tasmanian sub-plate ceased fo exist after the Eocene, becoming firmly fixed to the Australian plate. Later readjustments have occurred giving rise to further limited movements, mainly in the Gippsland Basin.The integration of detailed geological work and a regional tectonic analysis has been successfully applied to south east Australia and it is probable that a similar approach would yield fruitful results applied elsewhere.
PALAEOZOIC HISTORY OF THE ST. VINCENT GULF REGION, SOUTH AUSTRALIA
Authors: Stuart William J. , Sanden A.T. von
Published: August 2017

The St. Vincent Gulf Region comprises portions of the Gawler Craton and Adelaide Geosyncline. It extends from Yorke Peninsula and a portion of Investigator Strait (within the craton) to the Mt. Lofty — Kangaroo Island fold belt (inclusive). An area of potential hydrocarbon accumulation exists in a marginal area of the geosyncline adjacent to the craton.After latest Precambrian deformation of Proterozoic strata, Lower Cambrian deposition commenced with transgressive arkoses, overlain by carbonates. The upper portion of the carbonates near or on the craton grade eastwards into mudstones in the geosyncline proper. A major retreat of the sea from marginal areas of the craton and geosyncline occurred during late Lower Cambrian time. The exposed land mass constituted a source for clastics deposited in the remainder of the geosyncline, which was undergoing strong downwarping movements. Intercalated carbonates and clastics of latest Lower Cambrian and Middle Cambrian age document return of the sea to the craton.Deposition in the geosyncline probably terminated during Middle Cambrian time, with pronounced earth movements and regional metamorphism culminating during Ordovician time. The Palaeozoic and Proterozoic rocks are unconformably overlain by Lower Permian and Cainozoic sediments.Three major fault patterns can be recognized in the region. Within most of the western portion, the fault pattern is similar to that of the Gawler Craton. Two later patterns of faulting in the remainder of the region evolved during Upper Proterozoic-Cambrian and Cambro-Ordovician times respectively, as the consequence of pronounced folding. Episodic movements of blocks bounded by faults in the western and northwestern portions of the region were the result of strong compressional forces directed towards the craton. Weaker earth movements also occurred during Lower Permian-Eocene time rejuvenating some of the old structures.
PETROPHYSICS OF THE COOPER BASIN, SOUTH AUSTRALIA
Authors: Porter Chris R. , Crocker Hugh
Published: August 2017

In the Cooper Basin lithologic types can be recognised and related to logging tool response. Empirical relationships between log readings and porosity and permeability can be developed locally by comparing log readings with core data. Water saturation/porosity relationships are found to be convergently hyperbolic. The effects of clay minerals upon water saturation determination show that only in the low porosity range is correction for clay necessary.A plot of Sw versus Sxo allows prediction of probable test results and has been confirmed by actual Cooper Basin well tests.An attempt to relate clay content to permeability has been successful in estimating tentative upper limits of permeability. Computer applications to log interpretation are utilized in achieving petrophysical parameters.
THE GEOSEIS SYSTEM
Authors: Magub Tim A.
Published: August 2017

In the past decade the exploration industry developed and used many types of land seismic sources, some of which have been surface sources designed to overcome the problems associated with conventional drilling techniques.Since its inception during 1966, the Geoseis* system has been used extensively as an exploration tool in many countries and has distinguished itself as a successful surface energy source system.The Australian exploration industry has seen only a limited utilization of the Geoseis system due to the reduced level of activity and consequently has not had the opportunity of becoming familiar with its characteristics.To obtain an evaluation of the system, it is necessary to compare its characteristics with those of other successful energy source systems in use today.In designing a suitable field system, the geophysicist must consider a combination of variable factors which contribute to obtaining optimum seismogram quality. To achieve this quality, it is necessary to have an understanding of the basic theory associated with the system.Variations of charge length, charge weight and charge separation are important factors in obtaining optimum frequency content, frequency response and acceptable signal -to -noise ratios, while calculation of recording offsets will enhance reflections from particular target horizons.The Geoseis system is one of the most flexible energy source systems in use today and has the added advantage of incorporating explosives in a surface source system thereby retaining many of the advantages of the conventional dynamite technique.
EXPLORATION IN THE EAST COAST BASIN, NEW ZEALAND
Authors: Leslie W.C. , Hollingsworth R.J.S.
Published: August 2017

Numerous oil and gas seeps have been known in the East Coast Basin of New Zealand since the last century; however, no commercial discovery has been made in the region. Although a number of wells was drilled earlier, the present phase of systematic geological and geophysical exploration was begun by BP Shell Todd Petroleum Development Limited in 1957 and by 1970 had resulted in the drilling of five wells. These wells indicated the presence of thick marine mudstones and siltstones of Cretaceous through Tertiary age, but failed to find any suitable reservoir beds. This, plus complex geological structure and rugged topography are major problems of the region, particularly in the northern portion.Beaver Exploration subsequently became interested in the area because of the presence of a porous Pliocene coquina limestone (known as the Te Aute Beds) cropping out in the Southern Hawke's Bay region. This unit was considered to be a good drilling target if it occurred adequately sealed in the deeper parts of the basin. In an effort to determine this, Beaver conducted a Seismic Survey with the object of tracing the limestone from outcrop into the subsurface, where hopefully it would be found structurally closed.The survey was successful and three drill sites were chosen. In two of these the drill penetrated the Te Aute Beds which had excellent porosity and permeability but were water filled; in the third well the reservoir was missing. Correlations between the seismic and the drilling results indicated that the Te Aute Beds are probably mappable at least over some parts of the Southern Hawke's Bay region. The problem now is to find these beds in areas where they are less likely to be water flushed.
TROUGH EVIDENCE ALONG THE SOUTHERN FOOTHILLS OF THE PRINCE ALEXANDER MOUNTAINS (SEPIK DISTRICT — NEW GUINEA)
Authors: Oyen Fred H. Van
Published: August 2017

The presence of a thick sedimentary sequence of Mio-Pliocene and Pleistocene age has been established in the Screw-Amogu Rivers area of the southern foothills of the Prince Alexander Mountains. Field geology and aeromagnetic, gravity and seismic surveys show evidence of up to 10,000 ft. of sediments that thin to the south towards the Sepik Plain and remain thin over the Plain with no indication of major faulting.During late Tertiary and possible Pleistocene, ancestral Prince Alexander Mountains are thought to have formed an island ridge separating depositional areas north and south of this barrier. Diverse sediment types derived from the complex island ridge, coupled with an apparent difference in tectonic activity, probably account for the lack of litho-stratigraphic correlation between sediments on either side of the basement core of the Prince Alexander Mountains.Immature sediments observed in outcrop in the foothills of the Northern Ranges support the local "Island Ridge" hypothesis for the source of the thick Screw-Amogu River section in preference to the alternative possible source area some 40 mi. to the south where basement is exposed in a series of hills along the Sepik River. The Screw-Amogr River sediments are thought to have been deposited in restricted, narrow trough that subsided contemporaneously with deposition. This concept of local troughs of thick Upper Tertiary sediments but otherwise relatively thin epicontinental deposits in the Sepik District necessitates moving the southern limit of the Northern New Guinea Basin north of the Sepik District.
AUSTRALIA'S PETROLEUM RESOURCES, PRODUCTION AND DEMAND IN THE 1970'S
Authors: Konecki M.C. , Gartland C.F. , Skeggs A.G.
Published: August 2017

At the end of the third quarter of 1971, Australia's estimated remaining proven reserves of crude oil were 1,685 × 106 barrels, and of natural gas were 13.97 × 1012 cu. ft., with 273 × 106 barrels of condensate recoverable from natural gas.Additional quantities have been discovered, but not proved as yet. Australia's found petroleum resources at the beginning of the last quarter of 1971 would have approximated 3.000 × 106 barrels of hydrocarbon liquids, and 45 × 1012 cu.tf of natural gas, together representing a thermal value of 64 × 1015 BTU, or about 20% of the thermal value of Australia's recoverable black coal resources.Depletion of petroleum resources by production amounted to 10.14% of the initial proven reserves of crude oil, and 1.21% of natural gas proven reserves.About 73% of our found petroleum resources are in the Mesozoic and Tertiary sediments beneath the Gippsland and the Northwest continental shelves. Factors quoted by Weeks in favour of the offshore vis-a-vis the onshore seem to have been confirmed by Australian experience to date The production of crude oil from proven deposits in the period 1.10.71 to 31.12.79, estimated as 1,070 × 106, will fall short of the estimated demand of 2.170 × 106 barrels. Possible additional production from deposits discovered but not yet proven is not likely to make up this shortfall. No estimate of the likely cost, or time required, to discover additional crude oil deposits can be given.An additional problem concerns the supply of the products at the heavy end of the barrel, unless heavier type crudes are discovered.The greater portion of our found petroleum resources consists of natural gas and its liquids. Unlike crude oil, the potential production from these deposits could exceed local demands, which for the period 1971 to 1979 are estimated as 1.8 × 1012 cu. ft.
THE EFFECTS OF CONTINENTAL DRIFT ON THE PETROLEUM GEOLOGY OF WESTERN INDONESIA
Authors: Ranneft T.S.M.
Published: August 2017

The traditional concept of western Indonesia as a sinuous island are is probably incorrect. Instead, western Indonesia seems to consist of a series of largely straight segments that are sometimes offset and that may change direction abruptly in specific hinge line areas. The segments, especially in these hinge line areas, are cut by a system of north-northeast trending transverse faults. This fault system (Bantam trend) is noted forremarkable consistency in the direction of strike,wide distribution,variety of amount and direction of movement,occasional volcanism, andvaried activity at different times during the Cenozoic period or before, probably diminishing in a northeasterly direction.The segmentation and associated transverse fault system of western Indonesia may be caused by the Australian plate and its fracture zones (extensions of "transform" faults?) and north-northeast trending Indian Ocean morphological features, being thrust beneath the Indonesian continental area. The Bantam (transverse) fault trend may have affected the petroleum geology of western Indonesia in at least two ways:it may have been responsible for the division of the backdeep and perhaps the interdeep into a series of highs and lows, resulting in silled conditions during deposition and therefore, source rock generation;it probably provided the usual north-northeast trending oil and gas producing anticlines in northern Java and in the Java Sea. As the less explored interdeep basins are closer to the edge of the subduction zone, the Bantam trend faults are likely to be particularly prominent there, a factor that should affect exploration programmes in this region.
STRUCTURE OF ISLAND ARCS BOUNDING THE AUSTRALIAN CONTINENTAL PLATE
Authors: Temple P.G.
Published: August 2017

The New Global Tectonic theory is proving exceedingly valuable to understanding the geological history of large parts of the world's surface. However, in island arc areas, such as those bounding the Australian Continental Plate, the theory is meeting with certain difficulties. These might be due to (a) the theory itself not being valid here, or (b) it needs modification.Certain spectacular aspects of the geology of Timor, New Guinea, New Caledonia and Northland New Zealand suggest that a good case could be made for modification. Large areas of each of these islands are covered by thick chaotic masses of layered ultrabasic igneous rock, radiolarian chert, shale and other sediments of a pelagic nature normally associated with oceanic regimes. Moreover, this sequence of rocks appears to have been tectonically emplaced from an oceanward direction on to sediments of a continental shelf environment. Emplacement seems to have occurred at approximately the same time and to have involved rocks of approximately the same age in all areas.A logical way to account for the observations above in terms of the New Global Tectonic theory is as follows:In Late Cretaceous to Early Tertiary time the northern and eastern edge of the Australian continental plate was dragged down and began to underthrust the oceanic mantle along a north to north-east dipping subduction zone (the Tethian subduction zone, which is still active along the western edge of the Indonesian Arc).From Early to Middle Tertiary time, light continental crust could no longer be subducted under heavier mantle and subduction ceased. Isostatic re-adjustment occurred, raising the northern edge of the Australian plate which still carried large remnants of oceanic crust that had been emplaced above it.At about the same time, and continuing to the present, a new pattern of south to east dipping subduction formed. Edges of the Australian plate were torn away and migrated eastward, leaving areas of new oceanic crust behind.If the sequence of events above is essentially a true picture, it leads not only to some interesting modifications of the New Global Tectonic theory, but also to certain implications as to mineral and petroleum prospects within island arc areas.
THE DELIA FIELD, COOPER BASIN, SOUTH AUSTRALIA
Authors: Pyecroft Martin
Published: August 2017

The Della gas field of the Cooper Basin, South Australia, was discovered by Pursuit Oil No Liability and joint venture associates in July 1970. The field covers an area of approximately 17,000 acres in a discrete culmination on the Nappacoongee-Murteree anticlinal trend.Production is from several fluviatile sandstone units within the Toolachee Formation of the Upper Permian Gidgealpa Group. The trap is essentially structural with a maximum closure of some 450 ft on the top of the Toolachee Formation above a probable gas-water contact at 6,460 ft subsea.Five of the seven wells drilled to date in the field have been completed as potential gas producers. Production occurs between 6,270 and 6,670 ft and the average total depth is 7,180 ft. Net pay thicknesses vary from 37 to 98 ft and good reservoir characteristics are typical of the producing sands in the field. Twenty-two days are normally required to drill and complete a productive well.
A METHOD OF CONTINUOUS VELOCITY ANALYSIS
Authors: Wardell John
Published: August 2017

This continuous velocity analysis technique is a development of previous automated computer methods for extracting velocity information from seismic reflection data. Every trace of the multi-fold coverage data is used to measure the time, amplitude, moveout and dip of each coherent reflection event on the seismic records, by means of moveout scan and dip scan techniques. Using these four parameters, reflection events are tracked along the line, finally producing a computer file on each reflection event, listing its time, amplitude and moveout at each depth point along its extent. The signal to noise ratio increase given by the moveout and dip scan processes is greater than that achieved on the final section, allowing the computer to pick events close to the limit of visibility on the final section. The velocity information obtained can be displayed in various ways, for use in estimating velocity functions for data processes such as moveout correction, time migration, and depth conversion, and for use by the interpreter in such things as the measurement of interval velocities and the estimation of sand-shale ratios.
CONTINGENCY PLANNING FOR OFFSHORE OIL SPILLS
Authors: Keith G. N.
Published: August 2017

The incidence of oil spillage from offshore exploration and production activities is comparatively low but the Santa Barbara and Chevron blowouts remind us of what can happen.There are two things each operator can do to help ensure he is prepared in the event of an emergency. First, a comprehensive inhouse contingency plan should be prepared before commencing operations in an area. The plan will ensure that adequate first-aid measures are on hand at all times and will go on to list the location and availability of additional assistance both in equipment and manpower.Second, the operator should be prepared to participate in the oil industry's National Oil Spills Action Plan. This plan is designed to ensure that the entire resources of the industry can be made available and effectively co-ordinated to combat an oil spill anywhere on the coast of Australia.
OIL SPILL CONTAINMENT AND RECOVERY SYSTEMS
Authors: Watts D. H. , March F.  A.
Published: August 2017

Systems for containment and recovery of oil spills in the offshore environment have been recently developed and tested.Containment SystemA containment barrier system has been designed to maintain structural integrity in 20 ft seas, 3 knot currents and 60 mph winds, and to contain oil in 4 to 5 ft seas and 40 mph winds. The system uses the properties of foam materials to make it lightweight, easily deployable, flexible, and highly wave-conforming. One unique property of the barrier is a special "dynamic keel" which permits the barrier to have static and dynamic stability without a significant weight penalty. The barrier uses foam "memory" to store energy, eliminating the need for auxiliary deployment equipment such as compressors. The barrier is designed so that it can be rapidly deployed to increase containment effectiveness.Recovery SystemA system for recovery of petroleum products from accidental offshore spills has been developed and tested. The testing has included both model testing and prototype testing of a 60 ft long system capable of recovering oil at a rate of 2000 gallons per minute. A 500 gpm system has also been designed.The tests have shown the system capable of recovering spilled oil at high efficiencies (less than 10% water in the recovered oil) at the 2000 gpm rate under environmental conditions ranging from calm to low State 5 seas (8 ft significant wave height) and in currents up to three knots.The oil recovery system is air, truck and ship transportable for rapid deployment to a remote spill location. It is completely self-contained having its own power unit, control system, and pumps. In its preferred deployment configuration it is used with oil containment booms such as the "dynamic keel" barrier, for funnelling the oil to the recovery system.A double weir system is employed to obtain high performance. The system is operated in such a way that oil thickens in front of the primary weir and then further thickens in front of the secondary weir, where it is withdrawn.
FUTURE FINANCING AND OWNERSHIP OF THE AUSTRALIAN PETROLEUM EXPLORATION INDUSTRY
Authors: Ranson A. E.
Published: August 2017

The cumulative deficit between Australia's petroleum requirements of the 30 years to the end of the century and projected domestic production has been estimated at 14.25 billion barrels.Oil exploration in Australia to 31 December 1971 cost $725 million and resulted in the discovery of 2.1 billion barrels of oil and 14.1 trillion cubic feet of natural gas. If this expenditure to discovery ratio is maintained we will need to spend a further $3,485 million on exploration to maintain only 70% self sufficiency in crude supplies.The alternatives to supplying a high proportion of demand from local production are frightening. The foreign exchange required to purchase the presently projected shortfall in 1984/85 at what we consider will be conservative prices is almost half Australia's record foreign exchange holdings at 30 June 1972. Further, by that time we will be competing with the other industrialised countries of the world for an increasingly scarce commodity.The major means of encouraging the expenditure of exploration moneys is to create a climate in which successful explorers are adequately rewarded. The unique position of indigenous crude prices must be corrected and gas sales encouraged. To maintain a meaningful Australian interest in the future finds local investors must be given suitable incentives to risk the necessary exploration funds.
HYDROCARBON SIGNIFICANCE OF UPPER PALAEOZOIC SEDIMENTS ASSOCIATED WITH THE KOBURRA TROUGH, GALILEE BASIN
Authors: Allen R. J.
Published: August 2017

The Koburra Trough is a major tectonic feature in the northeastern Galilee Basin of Queensland. The oldest rocks identified in exploratory drilling were Devonian sandstone, shale and siltstone, possibly representing a northern extension of the Adavale Basin. These rocks contain a fossil microflora and may be prospective for hydrocarbons. Overlying them are a maximum of 1979 m of Upper Palaeozoic sediments, and a maximum of 1180 m of Triassic sediments, together comprising the Galilee Basin succession. The lithofacies of the Late Palaeozoic is dominantly sandstone-shale; the lower beds show evidence of glacial derivation, and the upper beds contain coal measures. Shows of oil and gas have been recorded from the basal part of the sequence in the two deep wells (ENL Lake Galilee −1 and FPN Koburra −1) drilled in the trough. Structural and stratigraphic factors favour the existence of hydrocarbon traps on the south-western flank. "Large" inferred reserves of Upper Permian sub-bituminous coal have been discovered in Geological Survey exploration near outcrop at the southeastern end. Preference in the use of this coal is to be given to manufacture in Queensland of synthetic fuels and petrochemicals. The geological survey petroleum statigraphic drilling campaign is providing invaluable new data on the Galilee Basin.
THE DEVELOPMENT OF CONTINENTAL MARGINS IN PLATE TECTONIC THEORY
Authors: Falvey David A.
Published: August 2017

Atlantic-type continental margins are formed by rifting and subsequent breakup of continents by sea-floor spreading. Large scale horizontal displacements of continental blocks on lithospheric plates are well-described by current plate tectonic theory. However, the rifting process itself entails vertical tectonics which operate prior to breakup, and such processes are not well understood within the framework of plate tectonic theory.The qualitative models, at present described in the literature involve a sequence of events illustrated by type examples: the East African Rift; the ethiopian-Afar Rift; the Red Sea Rift; and the Gulf of Aden. The thinning and subsidence of the continental crust during rifting have been considered to be the result of crustal stretching. However the writer considers the evidence ambiguous and the theory inadequate. The model presented here involves the response of the crust and the lithosphere to thermal processes implicit in plate tectonic theory. Firstly, uplift is caused by thermal expansion and phase-boundary migration in the lithosphere. which leads to crustal thinning by erosion. Secondly, subsidence is caused by metamorphism in the deep crust. These events occur out of phase and result in two cycles of uplift/erosion/and subsidence during continental margin formation.From this generalised model, theoretical time-stratigraphic and structural cross sections may be constructed to suit the different continental margins. These cross sections are composed of different litho-tectonic elements, namely: pre-rift, rift valley, and post breakup, which are in general separated by two angular unconformities. These features may be readily identified on Atlantic continental margins with only a minimum of seismic and well control.
THE QUEENSLAND TROUGH: ITS PETROLEUM POTENTIAL BASED ON SOME RECENT GEOPHYSICAL RESULTS
Authors: Pinchin J. , Hudspeth J. W.
Published: August 2017

The Queensland Trough, about 130 km wide, lies between Queensland and the Coral Sea Plateau. It runs from a water depth of 1000 m off Townsville to 3000 m opposite Cape Melville.The most extensive and systematic geophysical survey of the area to date is that conducted by the BMR during 1971 as part of the survey of the Australian continental margin.The BMR sparker seismic sections show a rugged and eroded basement surface. It is concluded that this represents the top of mildly metamorphosed Palaeozoic sediments of the Tasman Geosyncline which were uplifted, folded, and faulted during the Permian and were subsequently severely eroded. In places coral reefs have grown from this basement surface. Some are now buried and some, especially those atop basement highs, are still growing.The Eocene/Oligocene unconformity encountered in the DSPD hole 209 on the outer edge of the Coral Sea Plateau can be traced as an unconformity over the entire trough and as a conformable Eocene seismic horizon over most of the trough. This horizon lies close to the basement over much of the plateau and at least 1.5 km above the basement in the centre of the trough. It is overlain by about 0.5 km of sediments over both the trough and the plateau.It appears that the trough was low relative to the plateau and the mainland since the beginning of the Mesozoic and received terrestrial and shallow marine sediments.Regional subsidence of the trough and plateau probably began in the Early Eocene. Small basins on the trough's eastern margin and on the plateau were formed by differential subsidence along rejuvenated basement faults. These small basins contain lower to middle Eocene shallow marine sediments.Petroleum prospects appear favourable in the south of the trough, especially in the trough's marginal reef development and in the region of pre-Eocene pinch-out against Palaeozoic basement.