bluuebunny/crossref_metadata_2025 huggingface dataset:
INDONESIA—GROWTH OF THE OIL INDUSTRY DURING 1970
Authors: Soediono Ir.
Published: August 2017

The growth of the oil industry in Indonesia during 1970 was the result of Pertamina's policy of encouraging foreign oil companies to invest in the country. By the end of the year production-sharing contracts had been signed with more than 35 groups of companies.The stabilisation of the political climate under the new government enabled exploration to start up again during 1967 and the next two years saw a rapid growth in geological activity. This has led to the drilling of over sixty exploration wells during the past year, and expenditure on exploration is now in excess of $U.S. 150 million per annum. A large part of the exploration effort is directed to offshore acreage and has been rewarded with discoveries by Sinclair in 1969, followed in 1970 by IIAPCO, Union Oil and Cities Service. These finds are expected to lead to production in 1971. Production in 1970 was in excess of 900,000 BOPD, compared with 600,000 BOPD in 1966. Existing refineries are being rehabilitated, a new plant at Dumai is planned to come on stream in July, 1971, and a further refinery is proposed for Java. A polypropylene plant is being built at Pladju, South Sumatra.As the campaign against pollution intensifies, other countries, particularly Japan, are hopeful of further significant finds of the good quality, low sulphur crude oil known to exist in Indonesia.
ECONOMIC PROSPECTS RELATING TO PETROLEUM EXPLORATION IN AUSTRALIA—WITH SPECIAL REFERENCE TO COOPER BASIN EXPERIENCE
Authors: Brown Albert W.
Published: August 2017

Petroleum exploration even in favourable environments is financially hazardous. By Australian standards large investments are required for exploration which, if successful, must be followed by further large investments for field development, production facilities and pipelines.The very nature of exploration demands that high risks be taken. But even after commercial discoveries are made, the financial risks can remain high. Quite often long periods elapse before revenue from a project begins to provide a return on investment. In the Moomba-Gidgealpa fields, a total of $32.8 million was spent on exploration, development and production facilities over a period of about eleven years.The long term perspective requires that the time value of money be considered when investment decisions are taken. Discounted cash flow is generally the technique employed for this purpose. When the investment in the Cooper basin is examined on this basis, the anticipated rate of return is 5% if only the revenue from firm sales of gas to the Adelaide market is considered. The rate of return on the investment in the Cooper basin will be improved by developing additional markets for gas and liquids.Present industry trends are disconcerting, as examination of the footage drilled, drilling rig activity and funds applied for exploration all suggest exploration activities are not increasing. For Australia to maintain a 70% self-sufficiency, annual exploration expenditure will have to be increased from the present level of about $76 million to approximately $180 million.The various government incentives are examined and it is argued that in the national interest, exploration incentives ought to be increased.
THE STRATIGRAPHY OF THE BASAL TRIASSIC SANDSTONE, NORTH PERTH BASIN, WESTERN AUSTRALIA
Authors: Hosemann P.
Published: August 2017

The Basal Triassic Sandstone is the basal member of the Lower Triassic Kockatea Shale. It is widely distributed adjacent to, and on the Precambrian Greenough Block in the northern Perth Basin, Western Australia. This member is lowermost Lower Triassic in age in the subsurface of the Don-gara gas field. In outcrop on the Greenough Block, the member is represented by a thin basal conglomerate, conformably overlain by upper Lower Triassic Kockatea Shale. In this stratigraphic study, detailed well-to-well correlations and lithologic studies were integrated to reconstruct the depositional history of the interval encompassing the Basal Triassic Sandstone. This sandstone is a composite of near-shore marine, and strand line accumulations deposited around the flanks and on the Greenough Block during a Lower Triassic marine transgression. The sandstone bodies were deposited on a drowned, topography of low relief, on progressively truncated Permian formations and Precambrian basement. The topography was formed following uplift and tilting of the Greenough Block and the overlying Lower Permian formations during mild Upper Permian tectonism.
THE DEPOSITIONAL HISTORY OF A PORTION OF THE NORTH PERTH BASIN—A SINGLE WELL DIPMETER ANALYSIS
Authors: Bird K. J. , Coleman W. F. , Crocker H.
Published: August 2017

Four-arm dipmeter interpretation has been integrated with other wireline logs, lithologic and palaeontologic data, and regional geology to arrive at a history of the deposition in a portion of the North Perth Basin.The Permian sediments were deposited in a moderate to low energy, paralic to marine environment. They were unconformably overlain by a thin transgressive Lower Triassic sand and deepwater marine shale. The Middle Triassic sediments were deposited as a regressive marine sequence under the influence of a strong southwesterly uplift, and culminated in piedmont talus deposits of Upper Triassic age.In the Lower Jurassic this area evolved through a flood-plain environment to a paralic environment with a northeast-southwest oriented coastline and a northern source area. During the Middle Jurassic gentle crustal movements, coupled with an increasingly active northern and eastern source area, resulted in several cycles of nearshore deposition, and finally a marine transgression.Subsequent violent tectonic uplift to the east in the Upper Jurassic produced massive first generation sands which were deposited in a mainly continental environment.
THE SIGNIFICANCE OF SURFACE INDICATIONS OF PETROLEUM
Authors: Meakin C. P.
Published: August 2017

Seeps are of interest to the petroleum geologist because:—they indicate a section capable of producing hydrocarbons, and very often are related to a petroleum accumulation, andmany of the Important oil-producing regions were discovered by surface indications of petroleum.There are five main types of seeps:- those emerging from homoclinal beds exposed at the surface; those associated with beds in which the oil was formed; those arising from definite large petroleum accumulations, either bared by erosion, or ruptured by faulting; those emerging at an unconformity; and those associated with intrusions. These types of seeps are associated with, and have led to the discovery of many major oil fields throughout the world.The reports of oil and gas seeps in Australia, however, are only meagre. This may be because:—of a lack of exploration and documentation,the basins are a type that do not have the conditions necessary to produce seeps,the seeps that do exist are unrecognized. For instance, even large gas seeps may pass unnoticed in dry areas,of a lack of petroleum.The detection of the gaseous hydrocarbons, methane, ethane, propane and the butanes, in soils by gas chromatography could aid petroleum exploration because:—it would enable the detection of gas seeps over a potential petroleum field that would otherwise remain undetected, andeven for small quantities of hydrocarbon gases, low ratios of methane to higher hydrocarbons indicate a petroliferous origin.This is the technique of geochemical prospecting. It is based on three assumptions:—It must be possible for the hydrocarbons to migrate to the surface.The concentration of migrating hydrocarbons should not be altered by chemical reaction, bacteria, or hydrocarbons derived from another source.An anomalous hydrocarbon concentration at the surface can be correlated with a petroleum deposit.A search of the literature shows that, on the whole, these assumptions are correct. It would therefore appear that geochemical prospecting, particularly when used in conjunction with geological and geophysical work, can be useful for locating petroleum deposits.
LOGISTICS OF DRILLING IN THE PAPUAN HIGHLANDS
Authors: McNair A.D.
Published: August 2017

The location of the first drilling site in the Highlands of Papua New Guinea presented some unusual logistics problems. The Mananda No. 1 well was drilled by Australasian Petroleum Company Pty. Ltd. in its Permit Area 27. The site is at an elevation of 6,000 ft. above sea level on the Mananda Ridge, about 100 miles west of Mount Hagen, in an area which is largely pinnacle limestone.After road access was discounted and several helicopter types found to be unsuitable, only one helicopter, the Boeing Vertol 107, was found to be an economic proposition for lifting rig components into the site.The helirig used was a Wilson 90E, owned by Santa Fe Drilling Operators Inc. and was taken over from Texaco after the completion of drilling of Cecilia No. 1 well in the Western District of Papua.Numerous supply routes were considered for the 4,000,000 lb. of materials and equipment required in addition to the rig. These route possibilities included Hercules and other large freighter aircraft from the coastal ports of Port Moresby, Lae and Madang, and combinations of coastal and river vessels, road transport and smaller fixed wing aircraft, with varying helicopter distances. Comparative costs of different routes are given. These showed that long helicopter distances with generally poor weather conditions could be quickly ruled out.The Hercules had distinct advantages and on initial considerations could possibly have been the most economic choice, but the obstacles of having to import the aircraft, of the general unsuitability of available airstrips and of the need to mobilize all or most materials at the one time, led to the abandonment of this route.The route finally selected for most materials was by road from Lae to Mount Hagen, Twin Otter and Skyvan aircraft to Komo airstrip and helicopters for the last eight miles to the rigsite. Each sector presented its own particular problems due to weight and length limitations, notably for casing, as well as problems due to weather.The route chosen for evacuation of the rig was by helicopter to a base established on the Turama River and thence by coastal vessel to Port Moresby. The choice of this route was justified by the time saved, since A.P.C. was liable under the contract to pay some $2,500 per day for rig hire until its arrival at a deep water port.Hindsight will undoubtedly show that improvements in the logistics patterns could have been made, but experience to date has tended to confirm that the basic patterns selected were the most economic.
CORROSION INHIBITORS IN OIL AND GAS PRODUCING EQUIPMENT
Authors: Stanphill Roy D. , Gibson R.W.
Published: August 2017

Most internal corrosive conditions found in oil and gas producing equipment can be controlled through the use of corrosion inhibitors. Organic corrosion inhibitor chemistry is now well known and inhibition mechanisms are understood. There are many good inhibitor formulations available today; so many, in fact, that the producer is faced with the problem of selecting the one best suited to his requirements. Many people depend solely on various types of comparative inhibitor efficiency tests in the laboratory to evaluate and select inhibitors for use under field conditions. These tests are important as relative screening tests, but the selection of a carefully planned application program for the specific formulation is equally important.
ENERGY — MAJOR SOURCES AND CONSUMPTION
Authors: Sherwin R.J.S.
Published: August 2017

We are wholly dependent upon energy of solar, terrestrial and celestial origin. Contributions from any basically new form of energy are unlikely. Fossil fuels are the basis of modern economies, crude oil being dominant.Overall energy demand and the considerable, special merits of crude oil and natural gas will lead to enormous demand for these two commodities in the coming decades. Oil and gas lend themselves to the economies of scale which are as important as technical factors. Vigorous and efficient world-wide exploration and research and development in improved recovery would appear urgent and important. A shortfall in these commodities could have serious economic repercussions world-wide. A massive shortfall could be disastrous.Research and development in coal, oil shale, tar sands, heavy oil, nuclear fracturing of reservoir rocks and fundamental issues to improve overall efficiency in using resources are worth early expenditure. Doubling total system efficiency or recovery percentage would each be equivalent to doubling proven reserves.Australia seems fairly well endowed with natural gas and brown coal but the locations with respect to large population centres are less than ideal. Reserves of uranium are also substantial. There could be serious shortages of black coal and oil resources. A good balance of components might not be easy to achieve if national security were given due weight. For example, to maintain its industrial economic growth Australia needs imported crude oil as a major contributor to primary energy consumption in spite of vulnerability to foreign control of supply and price.
NEW GLOBAL TECTONICS: ITS EXPLORATION APPLICATION TO THE EASTERN SECTOR OF THE AUSTRALIAN PLATE
Authors: Wonfor J.S.
Published: August 2017

The need of a session on Continental Drift and its relation to the search for hydrocarbons in the offshore areas of Australia and associated areas evolved from informal discussions with many geoscientists.The search for hydrocarbons on the continental margins requires a team approach between geologist and geophysicist, co-operation and exchange of data between industry, government, institutional and university personnel. To properly appraise the potential of the continental margins, synthesis of all data from land areas, continental margins and ocean deeps will be required.The history of the development of "Continental Drift" concepts is outlined from Wegener to the present. The principal concepts of the hypothesis of the New Global Tectonics are reveiwed. There are problems and objections to the hypothesis.The evolution of the continental margins can be related to the New Global Tectonics. A model is presented for the margins of the Australian continent. This relates hydrographic discoveries to the early stages of Wilson's life cycle of ocean basins and also relates concepts of Bott and others to the stages of continental margin developments.Exploratory offshore drilling in the eastern sector of the Australian Plate is reviewed. It is important that offshore exploration drilling be doubled if Australia is to attain a self-sufficient position in crude oil.An outline is given of the areas to be discussed in the following papers of the symposium.
EVOLUTION OF THE PERTH AND CARNARVON BASINS
Authors: Veevers J.J.
Published: August 2017

Along the present southwest Australian margin, in the Perth and Carnarvon Basins, the wholly nonmarine Permian, Triassic, and Jurassic sedimentary rocks of the southern Perth Basin pass northwards into paralic and marine equivalents of the Carnarvon Basin, which additionally contains marine Silurian, Devonian, and Carboniferous rocks. These contrasts are interpreted in terms of the re-assembly of Australia in Gondwanaland: the southern Perth Basin lay alongside India in the interior of Gondwanaland, and the northern Carnarvon Basin faced a gulf of Tethys.According to this model, southwest Australia was arched in the Late Carboniferous, and the arch collapsed by rifting in the Permian, Triassic, and Jurassic, with the accumulation of thick nonmarine (in the south) to paralic and marine sediments (in the north). Rupture from India was marked by the eruption of basalt in the earliest Cretaceous, and dispersal of India and Australia was marked by rapid marginal subsidence in the Late Cretaceous. This model, derived from stratigraphical and faciological data, is supported by the ridge-and-rift structure of southwest Australia.
EARTHQUAKE FOCAL MECHANISMS AND CONTINENTAL DRIFT
Authors: Denham David
Published: August 2017

By studying the first motions of earthquakes recorded at seismograph stations throughout the world it is possible to determine the type of faulting which takes place at the focus of an earthquake. Three main types of faulting are observed:thrust faulting, which is common in island arc provinces;normal faulting, which is common along mid-ocean ridges; andstrike-slip faulting, which occurs along fracture zones.In the New Guinea-Solomon Islands region all three types of faulting have been observed: thrust faulting along the mainland of New Guinea and in the island arc provinces at the northern margins of the Solomon Sea; normal faulting on the "seaward" side of the deep ocean trenches; and strike-slip faulting in the zone of seismicity under the Bismarck Sea.An analysis of the focal mechanism solutions indicates that the New Guinea region is divided into at least three small rigid plates, all moving separately.
LITHOFACIES STUDY ON THE TOOLACHEE FORMATION, GIDGEALPA-MOOMBA-BIG LAKE AREA, COOPER BASIN, SOUTH AUSTRALIA
Authors: Thornton Roger C. N.
Published: August 2017

A lithofacies study on the Upper Permian Toolachee Formation has been conducted in the Gidgealpa-Moomba-Big Lake area to determine the suitability of the technique in the reconstruction of depositional environments and palaeogeographic trends throughout the Cooper Basin. The Toolachee Formation is one of the main gas producing intervals in the basin, especially in the area of study, which is approximately 2,000 square kilometres. Thirty-one wells drilled in this region indicate that the formation ranges in thickness from 35 metres to over 115 metres.The Toolachee Formation, taken as a whole, is too thick to show any significant features on a lithofacies map over the limited area of investigation. However, lithofacies maps of three approximately chronostratigraphic subdivisions of the same formation show both vertical and lateral trends. Vertically, the percentage of sandstone decreases from the lowermost subdivision to the uppermost subdivision; coal percentages show the opposite trend; and core material shows fining upwards sequences. Laterally, isopachous thin areas (depositional highs) in most cases correlated with an increase in shale or coal lithologies. Histograms of coal cycles show that the lower and middle parts have similar composite sequences of, from the base upwards, sandstone mixture of sandstone and shale-shalecoal.The depositional model proposed is an aggradational flood-plain which, prior to the commencement of deposition, had been eroded to a peneplain. Sediments were deposited from rivers of gradually declining flow gradient until marsh and lacustrine conditions prevailed for long periods of time. Deposition ceased at the sediplain stage.
NATURE OF POROSITY IN SOME INDURATED PERMIAN SANDSTONES FROM THE COOPER BASIN
Authors: Steveson B. G. , Spry A. H.
Published: August 2017

The percentage porosity measured by physical means is commonly much larger than apparent porosity (measured as void space) seen in thin sections. This occurs even where the thin section is cut from the plug actually used for measurement and when extreme care is taken in preparing the section.This discrepancy has led to a consideration of the properties of pores and this paper reviews classifications based on size, fabric selectivity and genesis. A basic distinction between pores related to sedimentational features and those derived from diagenesis and/or tectonism is stressed.In Permian sandstones from the Cooper Basin porosity is present largely as pores less than 0.06 mm across. These generally cannot be seen in thin section nor can they be related to observable petrographic features of the rocks.Secondary micropores and submicropores in the Cooper Basin rocks may be due to either diagenetic or tectonic activity; the overall spatial variation of porosity and permeability may indicate which process has been more important.
SEISMIC INTERPRETATION AIDED BY THE COMPUTER
Authors: Irrgang H. R. , Burnet I. L.
Published: August 2017

The need to rapidly evaluate the immense quantity of seismic data being acquired by marine and land crews has focused attention on the development of an interactive seismic interpretation system using computer technology.Improvements in hardware and software and in the price/ performance ratio of computers make them more accessible for routine interpretation procedures.Advances in the development of interactive interpretation systems allow the geophysicist to exercise more control over the contouring, datuming, and other functions as the interpretations proceed. He can view graphically the results of major or minor changes in various parameters and their effects on the overall interpretation. Most important, the geophysicist has more time to apply his skills and experience to developing technically and geologically sound evaluations of areas or prospects.
CAFDRS INNOVATIONS AND FIELD RESULTS
Authors: Edwards Charles M.
Published: August 2017

The Computer Augmented Field Data Recording System-CAFDRS-is a unique combination of a standard seismic digital field recording system and a mini-computer system, specifically conceived to provide a major advance in monitoring and analysing data as it is being acquired in the field. On-line operations include capability to: composite, vertically stack, correlate VIBROSEIS data, control the recording operation and make power spectrum analysis. Off-line operations include the ability to play back data at a later time, and perform most of these same operations, plus, produce a normal-move-out corrected common-depth-point stacked section. Experience with CAFDRS in the field demonstrates both the versatility of the concept and the effectiveness of being able to analyse data "on the spot" particularly when using the VIBROSEIS technique. Noise, source array and geophone analyses are made "on- line" as the experimental program is conducted. By using the frequency analysis program to obtain power spectra, the optimum vibrator sweep can be established for the particular area.The 16 bit word base used in the mini-computer system preserves the 76db of dynamic range of the data acquired by the XDS-1010 or the DFS III, two of the standard field systems now used in CAFDRS. The dynamic range of the compositing and correlating operations accomplished with the SPC-16 mini-computers compares favorably with that obtained in a large scale data processing centre.The noise editing feature included in the double precision floating point compositing program reduces the deteriorating effect that large bursts of random noise have on most composited data. Composited data correlated in the field compares almost exactly with the same data correlated in the data centre. The NMO/CDP raw stacks produced in the field compare favorably with ones produced in the data centre.Note: VIBROSEIS is a trademark of the Continental Oil Company and DINOSEIS is a trademark of the Atlantic Richfield Oil Company.
THE ROLE OF GAS IN ENVIRONMENTAL CONTROL
Authors: Hartmann Hanns F.
Published: August 2017

The gases comprising the atmosphere are in dynamic balance both with the oceans and the dry land of the continents. The mechanisms which operate to keep the atmospheric content of oxygen, nitrogen, carbon and sulphur constant are now well defined. The capacity of the system to absorb excess gaseous impurities is adequate on a global basis with the exception of carbon dioxide.Air pollution is thus a local problem resulting from the overloading of a particular air space with contaminants. The greater part of air pollution is due to the combustion of fossil fuels. Ease of control and virtual freedom from sulphur give natural gas an advantage over liquid and solid fuels as far as air pollution control is concerned. Oxides of nitrogen are produced when natural gas is burned but in smaller quantities than in the combustion of other fuels. In high capacity industrial gas burners where oxides of nitrogen may be generated in large quantities control is easier and can achieve a lower level of oxides of nitrogen than is the case with other fuels.The large scale use of natural gas to solve the air pollution problems of Pittsburgh, Los Angeles and many other cities is proof of the usefulness of gas in this respect. Specialised applications include use in incinerators and industrial after burners. Advances in removal of impurities from fuels and of air pollutants from products of combustion combined with rising gas prices will in time displace gas from its preeminent position in air pollution control. It is, however, likely to retain its advantage in small installations and in dense urban areas. In public and private transport its use will probably remain limited.While technological developments in the distant future may eventually displace fossil fuels, gas will have a large share of the fuel market until that day comes and will contribute effectively to the control of air pollution.
UNDERWATER TIE-IN OF 24 INCH OFFSHORE PIPELINE
Authors: Bradley Frank
Published: August 2017

A 47 mile 24 inch underwater pipeline was required to link the Esso/BHP Halibut field to onshore production facilities. To hasten the completion of this line. Esso elected to use two pipe laying barges: one starting from the shore and one from the platform, and to make an underwater tie-in where the two lay barges met. To complete the tie-in, Esso engaged Ocean Systems Australasia Pty Ltd to make a sea floor welded connection in their underwater welding habitat, using the TIG (Tungsten Inert Gas) hyperbaric welding process and the saturation diving technique. The support vessel for this work was the semi-submersible derrick barge Choctaw. The tie-in was 38 miles offshore in the open waters of the Bass Strait in 218 feet of water. The pipe wall thickness at the tie-in was three-quarter inch.The Halibut 24 inch pipeline underwater tie-in was successfully completed in a total elapsed time of 383 hours (15 days 23 hours) compared with the estimated total time of 348 hours. Three major factors contributed to the success of the operation; these were:The ability of the semi-submersible derrick barge Choctaw to stay on location during the bad weather when swells of up to 20 feet were experienced.The efficient organisation and implementation of the work by Ocean Systems.The close alignment of the two sections of the pipeline on the seabed by the pipelaying contractor, Ingram Contractors Australia Pty Ltd.
OFFSHORE PETROLEUM POTENTIAL IN NEW ZEALAND
Authors: Katz H. R.
Published: August 2017

Extensive shelves and intermediate-depth terraces, rises, and plateaus characterize the New Zealand offshore region. Sedimentary basins with hydrocarbon potential on land, which all have formed after the Early Cretaceous Rangitata Orogeny, are mainly lined up along the west and east of both islands and obviously extend out to sea. Sediment thickness generally increases offshore, while the tectonic disturbances become markedly less severe. Prospects therefore look favourable, and on this basis offshore concessions to a total of nearly 400,000 sq. miles were taken up, covering the area all around New Zealand to a depth of 1,000 m. Ten offshore wells to an average depth of 10,000 ft have been drilled, the second, third and fourth of which establishing a large gas field with an estimated 5 trillion cu. ft of gas, and the seventh being a non-commercial oil discovery (tested flow rate 600 b/d). Marine seismic surveys have been done over about 80,000 line miles. However, the results indicate that in many areas maximum subsidence during the Tertiary occurred relatively close to the present landmass, whereas farther away on submarine rises and plateaus the basement is very shallow or even exposed; also nearer to land some areas have little or no prospects. Consequently, 70,000 sq. miles have been relinquished-with only one well here drilled-and more acreage will probably be relinquished in the near future. But the overall potential still is encouraging; interesting prospects remain particularly along the west coast within the 500 m depth contour and extending from about 35° to 44°, also along the east coast of the North Island, on the eastern half of Chatham Rise, in the south -east of the South Island south of Christchurch and towards the central depression of Campbell Plateau, and in the head of Solander Trough. These areas amount to about 100,000 sq. miles. Concessions totalling 50,000 sq. miles (which for the greater part lie within the above areas) are in their second 5-year term and will expire on 30 September 1975; until then, more drilling is expected to outline existing prospects in greater detail. There is reasonable hope for further discoveries of substantial petroleum accumulations.
A SUMMARY OF THE PETROLEUM GEOLOGY OF THE CARNARVON BASIN
Authors: Thomas B. M. , Smith D. N.
Published: August 2017

The Carnarvon Basin, an elongate crustal depression along the central West Australian coast line, contains a sedimentary record from the Silurian to the Recent. The southern part of the basin consists mainly of an area of downtaulted Palaeozoic sub-basins. The northern Carnarvon Basin is a major Mesozoic downwarp, containing a thich section of Triassic, Jurassic and Neocomian sediments. None of these is present in the south. All of the northern part of the basin and much of the southern Palaeozoic basins is covered by a blanket of Early Cretaceous shales and Late Cretaceous and Tertiary carbonates.The Palaeozoic was a time of tectonic stability when shallow marine shelf sedimentation predominated. The major structural trends now observed in the basin were developed during a Jurassic tensional regime. This was related to break-up of the continental margins when block faulting developed around the edges of the Precambrian Shield. Within the resulting Exmouth-Barrow-Dampier downvtarp there accumulated over 8000 m of Jurassic and Neocomian marine and fluvial sediment. During the Aptian, epeiric seas inundated the basin and by the Late Cretaceous, shelf carbonate sedimentation had become established.Progressive subsidence of the continental shelf has since allowed the accumulation of 3000 m of carbonate sediments along the present-day shelf edge.The present cycle of petroleum exploration in the basin began in 1952 when West Australian Petroleum Pty Limited (WAPET) was formed to operate on leases held by Ampol Petroleum Limited. A non-commercial oil discovery at Rough Range −1 followed in 1953, but it was not until 1964 that commercial quantities of oil were found at Barrow Island. In July 1971 the Burmah group of companies drilled North Rankin −1 the first of a series of giant gas-condensate discoveries on the Rankin Platform.
THE REGIONAL GEOLOGY OF THE BONAPARTE GULF TIMOR SEA AREA
Authors: Laws Robert A. , Kraus Gregory  P.
Published: August 2017

The present structural configuration of the Bonaparte Gulf-Timor Sea area is essentially the result of Mesozoic and Tertiary fragmentation of a once relatively simple Permo-Triassic Basin. A northwest-southeast Palaeozoic structural grain in the southeastern portion of the area resulted from early Palaeozoic faulting, possibly tied to aborted rift development. This faulting effectively controlled sedimentation throughout the Phanerozoic. Pronounced northeast-southwest Jurassic to Tertiary structural trends dominate the central and northern area, paralleling the present edge of the continental shelf and swinging south southwest into the northern extension of the Browse Basin. Post-Palaeozoic epeirogenies which had the greatest effect on the regional structural pattern occurred in the mid-Jurassic, Early Cretaceous, within the Eocene and in the Plio-Pleistocene.The Kimberley and Sturt Blocks flanking the basin to the south and east constituted the most important source areas for clastic sedimentation throughout the Phanerozoic. Periodic contributions during the Mesozoic were derived from a postulated source to the northwest in the vicinity of the present-day Timor Trough.The maximum thickness of Phanerozoic sediments present within the Bonaparte Gulf-Timor Sea area exceeds 50,000 ft (15,000 m). Early Palaeozoic to Carboniferous evaporites, carbonates and clastics are unconformably overlain by a thick sequence of Permian deltaic sediments in the southeastern Bonaparte Gulf Basin. This is succeeded by a Triassic to Middle Jurassic transgressive-regressive clastic sequence, grading northwestward to marginal marine and marine clastics and carbonates. The Permian to mid-Jurassic sediments are unconformably overlain by Upper Jurassic sands and shales, mainly fluvial in the southeast and north, becoming more marine westward. These clastics are everywhere succeeded by a monotonous sequence of Cretaceous shales and shaly limestones followed by a generally north to northwesterly thickening wedge of Tertiary carbonates and minor elastics.Hydrocarbon shows have been noted offshore in rocks of Carboniferous, Permian, Late Jurassic, Late Cretaceous and Eocene age. Porous clastics in conjunction with thick and laterally-extensive, organically-rich shales are present within the Palaeozoic and Mesozoic sequences. These sediments, in association with fault- and diapir-related anomalies and stratigraphic plays, combine to make certain provinces of the Bonaparte Gulf-Timor Sea area prospective in the search for viable oil and gas reserves.
ANALYSIS OF GRAVITY DATA NEAR CONTINENTAL MARGINS
Authors: Flavelle A. J. , Yoshimura Y.
Published: August 2017

In general large, thick sedimentary basins are delineated by negative gravity features. The gravity data are usually expressed in the form of Bouguer anomaly contours.Ordinary Bouguer anomaly data fail as a direct indicator of approximate sedimentary thickness in zones on and adjacent to the continental margin. Rapid variations in crustal and ocean thickness cause gravitational variations which are not removed during the computation of Bouguer anomaly values.If crustal thickness variations are known or can be calculated then gravitational corrections can be made which take this factor into account. Similar corrections for variations in sea water attraction can be made. The resultant Bouguer anomaly map, corrected for those variations, will indicate in more definite terms density variations in the material of the upper crust. In particular Bouguer anomaly patterns over continental areas adjacent to the continental slope can be more easily interpreted in terms of sedimentary thickness.
PIPELINES AND PIPEDREAMS
Authors: Ranson A. E.
Published: August 2017

There is little Australian experience to work on but the available evidence indicates that the capital cost of installing pipelines in Australia is well in excess of the cost of building similar size lines in the United States. The terrain in which the line is being laid is an important factor in total cost.The costs of operating a gas pipeline are essentially determined by the cost of installation of the line and the cost of the funds used. The first of these factors is largely outside the control of the operator although it does have some discretion in areas such as the source of the pipe to be used. The cost of the funds used in a project is dependent on the status of the owner and while private pipeline owners have tended to be low cost borrowers, government bodies should be able to obtain better rates of interest. However, the source of government funds is limited and the allocation of these funds should be determined by suitable tests of social and economic benefits.Given the capital and financial costs of a pipeline the unit cost of transporting gas is a direct function of throughput and the variation in that throughput.Even under generous usage assumptions, the pipe which is projected to join the North West Shelf to the East Coast will not be economic for many years. Provision of funds from consolidated revenue and other devices will not reduce the costs but merely divert them to taxpayers. Pipelines to some of the more remote areas will probably never be economic.
LIFE OFFICE INVESTMENTS IN AUSTRALIA
Authors: Macek C.
Published: August 2017

The Life Assurance industry has been frequently criticized about the investment policies it has pursued. Much of the criticism is ill-founded and based on ignorance of the industry. Hopefully, this paper will help your understanding of the Life Assurance industry and its investment policies-particularly the role it has and can continue to play in natural resource exploration and development.
LABORATORY STUDIES OF SANDSTONE RESERVOIRS GAS DISPLACEMENT FROM HAVING STRONG WATER DRIVE
Authors: McKay B. A.
Published: August 2017

Investigations by the Petroleum Technology Section of the Bureau of Mineral Resources have shown that a substantial residual gas saturation is trapped behind the flood front in gas-producing reservoirs having a strong water-drive; the volume of gas trapped may be as high as 44 per cent of pore space, and lies within the same range as residual oil saturation in a flooded-out oil reservoir.Core samples from gas-productive reservoirs in three Australian sedimentary basins have been subjected to laboratory tests to measure this effect. The tests comprised capillary pressure measurements, water-flooding by dynamic-displacement and imbibition at ambient and elevated temperatures, and repeat gas recovery measurements in core samples exhibiting variations in irreducible water saturation.The results show a loose correlation between porosity and residual gas behind the flood front in these samples. Temperature appears to have little effect on the residual gas saturation. Gas recovery, however, is strongly dependent on the irreducible water saturation established prior to flooding.
A REVIEW OF THE PETROLEUM SEARCH SUBSIDY ACTS
Authors: Williams L. W.
Published: August 2017

THE FIRST of the Petroleum Search Subsidy Acts was introduced in 1957, when the level of petroleum exploration in Australia was very low. The types of operation eligible for subsidy, and the subsidy rates, have been altered from time to time in recognition of changing circumstances. The present Act is not to be extended and only covers operations which will be completed by 30 June 1974.The activity in various areas in Australia and Papua New Guinea has fluctuated during the period that the Acts have been in force. The early, relatively high, level of activity in Queensland was not maintained, and other areas, such as Western Australia, received increased attention. The percentage of subsidy funds going to operations in offshore areas has changed markedly.
The Acts have provided assistance to petroleum exploration in Australia in several ways. In the early days of the Act, when little expertise on petroleum exploration was available in Australia, standards were set for the field operations and reporting, and the operations were closely supervised, ensuring a reasonable minimum standard of performance. Payments under the Act have assisted companies, particularly those with limited funds, to engage in exploration and have also encouraged all companies to explore in Australia by reducing the effective unit cost of exploration. The information which has become available through the operation of the Act has assisted exploration by enabling exploration decisions to be based on the results of most of the exploration which has been carried out in Australia.The Petroleum Search Subsidy Acts, which will cost a total of some 7150 million, have made a very useful and significant contribution to petroleum exploration in Australia and Papua New Guinea over a period of 17 years.
RECENT GEOLOGICAL AND GEOPHYSICAL RESULTS IN THE NORTHEASTERN CANNING BASIN
Authors: Drew M. F. , Evans G. R.
Published: August 2017

The exploration programme conducted in Exploration Permits 58 and 59 in the northeastern Canning Basin during the past three years has clarified regional structural and stratigraphic relationships. Interpretation of the combined results of field geological, high sensitivity aeromagnetic and reflection seismic surveys has delineated five major structural elements, some previously unrecognised. These are, from north to south, the Billiluna Shelf, the Betty Terrace, the Fitzroy Trough, the Crossland Platform and the Helena Platform. Sedimentary rocks from Proterozoic to Mesozoic age occur in the permits. The Phanerozoic rocks range in thickness from in excess of 15000 m in the Fitzroy Trough to a veneer of probably less than 1000 m over the Billiluna Shelf. On the Crossland Platform and the Helena Platform, up to 4000 m of Lower and Middle Palaeozoic rocks overlain by up to 1500 m of Upper Palaeozoic sediments are interpreted to be present.Whilst no wells have been drilled within the area, results of exploratory holes in adjoining permits have been used to refine the interpretations presented in this paper. The principal stratigraphic features of interest to petroleum exploration are a possible Devonian reef trend located on the junction of the Crossland and Helena Platforms and subdued structural features caused by halokinesis on the Helena Platform.Two major geological conclusions were drawn from the exploration programme to date. One is that the age of the formation of the Fitzroy Trough, at least in this part of the Canning Basin, is younger than previously postulated. The other is the presence in the northeastern part of the Canning Basin of a Proterozoic infrabasin with depths to magnetic basement comparable with measured outcrop thicknesses on the southern flank of the Kimberley Block.Future exploration plans for the region call for further seismic exploration and the drilling of medium depth wildcat tests to investigate the hydrocarbon potential of the region.
PETROLEUM RESOURCES OF QUEENSLAND
Authors: Allen R. J.
Published: August 2017

Queensland produces oil mainly from the small Moonie and Alton fields in the Surat Basin. Proven reserves of these two fields were 3262 m3 × 103 initial recoverable. Production began in 1964, after completion of a pipeline, 300 km long, from Moonie to Brisbane. The rate peaked at about 1600 m3 per day, but has since declined to about 200 m3 per day. With the exception of the fields presently supplying the pipeline, virtually no other appreciable reserves of oil or condensate are known in the State.Gas is produced from a group of small fields near Roma in the Surat Basin and underlying southern Bowen Basin. Proven reserves were 4573 m3 × 106 initial recoverable. Production for other than local use in town lighting (1906), condensation for motor fuel (1928–1931) and electricity generation (1961 –) did not begin until 1969, when a pipeline 450 km long was completed to Brisbane. The rate is currently about 0.83 m3 × 106 per day. In addition to those at Roma, reserves of gas are also known in small fields: in the Surat and southern Bowen Basin near Surat (about 80 km south of Roma); in the Bowen Basin near Injune and Springsure (respectively about 80 km and 280 km north-northwest of Roma); in the Adavale Basin; in the Queensland portion of the Cooper Basin. Exploration has been intensive only in parts of the Surat and southern Bowen Basins. Accordingly, persistent efforts in selected areas are likely to lead to success. The more prospective basins in Queensland are considered to be the Adavale, Bowen, Cooper, Galilee, Georgina, and Surat.
STRATIGRAPHIC AND STRUCTURAL DEVELOPMENT OF THE AURE TROUGH AND ADJACENT SHELF AND SLOPE AREAS
Authors: Brown C. M. , Pieters P. E. , Robinson G. P.
Published: August 2017

The Aure Trough is a partially submerged south-southeasterly trending eugeosyncline which comprises the main axial zone of sedimentation in the Cainozoic Papuan Geosyncline. It is bounded to the west by a broad stable miogeosynclinal shelf and slope, and to the east by a narrow unstable shelf.Onshore the trough consists of 10 000 m of deep-water sediments. These extend offshore where the axis of sedimentation coincides with the axis of a present day bathymetric feature, the Moresby Trough. Sediments are folded into north-trending linear anticlines and broad synclines; anticlines are ruptured by thrust faults and offshore by diapiric intrusion of mudstone. The western slope (5000 m of fine marine sediments) and shelf (2500 m of deltaic and shallow marine sediments) are relatively undeformed. Over the eastern shelf, 5000 m of folded fluviatile, deltaic and shallow marine sediments are transitional eastwards to 2000 m of relatively undeformed sub-aerial volcanics. Variations in sedimentary lithologies can be correlated with periods of volcanic activity associated with periods of uplift.The sediments of the Cainozoic Papuan Geosyncline unconformably overlie Mesozoic and Eocene sediments. West of the Aure Trough the Mesozoic and Eocene rocks are weakly deformed shelf sediments derived from the Australian continent; east of the trough they are strongly deformed, metamorphosed and partly volcanogenic. The nature, thickness and extent of these sediments beneath the Aure Trough is not known.The Mesozoic to Eocene sequence accumulated around the margins of the Australian continent in an arcuate geosynclinal basin. Early Cainozoic interaction of the Australian and Pacific plates resulted in deformation of the outer margins of this geosyncline and in the partial emergence of mainland Papua New Guinea. Erosion of this landmass and volcanic activity provided the main source of sediment for the Cainozoic Papuan Geosyncline. Development of the Aure Trough may be related to opening of the Coral Sea Basin in the Eocene; geophysical evidence suggests crustal thinning.Numerous oil and gas seepages have encouraged petroleum exploration throughout the area since 1911. No economic reserves have been located in the Tertiary section, but wells west of the Aure Trough have encountered gas and some oil of probable Mesozoic origin.
ONSHORE GIPPSLAND GEOCHEMICAL SURVEY: A TEST CASE FOR AUSTRALIA
Authors: Poll J. J. K.
Published: August 2017

Drilling for oil in Gippsland probably commenced about 1886 with a test bore to 175 feet near an alleged oil seep. It was however not until 1924 with the discovery of gas and minor heavy oil in a well near Lakes Entrance that petroleum exploration really commenced. Since then about 125 wells have been drilled onshore, half of which were in the Lakes Entrance area where two non-commercial oil pools were delineated. The wells in the remainder of the onshore basin were dry.Some potential remains in stratigraphie wedge-outs. Because of the low prospectivity of the area and the difficulty of locating these targets with conventional methods, a geochemical survey was carried out in early 1974.The Gippsland Geochemical Survey covers about 1,100 square kilometres and comprises 1,117 samples. The samples were analysed and the results computer processed. A regional background and anomalous threshold was defined for each homogeneous set of samples. The final map is a contour map of the product of the relative anomalous value by the probability of obtaining an anomalous sample in a small area.The gas map shows six main anomalies of which five are linear and parallel to the postulated wedge-outs. One anomaly probably relates to the residual oil pools near Lakes Entrance, another is weak and probably spurious. The remaining four anomalies warrant further investigation, preferably by detailed geochemical surveying, followed hopefully by the drill.Geochemical surveying is a valid and inexpensive tool in on-sh ore petroleum exploration, provided that:the possibilities and restrictions are understood;a large enough area is covered with a regular grid to establish proper contrast;care is taken with data processing, map preparation and interpretation;it is recognised that the method is additional and does not replace seismic, etc.Australia has over 1,000,000 square kilometres of moderately prospective onshore basins. The author believes that consideration should be given by the Australian petroleum explorers to employ the potential of this cheap exploration tool more fully.