bluuebunny/crossref_metadata_2025 huggingface dataset:
KEROGEN PRECURSORS: CHEMICAL AND BIOLOGICAL ALTERATION OF LIPIDS IN THE SEDIMENTARY SURFACE LAYER
Authors: Johns R. B. , Volkman J. K. , Gillan F. T
Published: August 2017

A study of the processes operating upon organic molecules in present day sediments can illuminate kerogen-petroleum inter-relationships. The starting point for kerogen formation is not the initial biological inputs to a sediment but rather those organic molecules which survive the active upper 1 to 2 cm of surface sediment where biological diagenesis is most marked. Depth profile studies on fatty acids, alcohols, sterols, and dicarboxylic acids emphasise the differing sensitivity of lipid classes to chemical and biological processes. Distribution patterns for these lipids in older sediments thus reflect the changed weightings which result from utilisation and preservation within the biologically active zone.Environmental effects are discussed in terms of stability of chlorophyll-a and bacteriochlorophyll-a molecules in sediments taken from temperate zones and contrasted with those in sediments from tropical zones. Whilst demetallation is an important degradative pathway for bacteriochlorophyll-a, this is not the case for chlorophyll-a. In this latter molecule the pigment ring system is chemically unstable, but the phytyl ester appears to remain substantially unhydrolysed. The data given in the tables bear on alkane genesis and on the origin of the isoprenoid alkane biological markers. The consequences of this type of study for side chain structures in the coal macromolecule and industrial conversion processes are noted.
THE APPLICATION OF CRITICAL PATH SCHEDULING TO ONSHORE DRILLING RIG MOVES
Authors: Crowe K. L.
Published: August 2017

One of a number of techniques to increase efficiency in the engineering industry which have appeared in the last few decades is Critical Path Scheduling. It is not much used in the petroleum industry, because its application is limited, but in many activities associated with drilling it can save time and money. Its use is illustrated by applying it to a typical rig move.There is a time-cost relationship on any job. An unplanned job will take a time and have a cost which can be reduced by Critical Path Scheduling to a point where cost is minimal, because further reductions in time will involve overtime, airfreight, and other abnormal charges. These factors can be analysed and better judgements can be made.The method used to apply Critical Path Scheduling is the Time Scale Arrow Diagram. It is a manual technique suitable for small to medium size jobs which has advantages in analysis and presentation over conventional methods employing computers. A rectangular, or parallel line diagram is used.A rig move is a complex operation whose costs can be a significant part of those for a whole drilling operation. It is usual to rely on experienced personnel to arrange for the rig preparation, loading, trucking, and rigging up at the new location to be done in the most efficient way. Jobs vary depending on the arrangements between the operator and the contractor, distances, local conditions, and other such factors. The Critical Path Schedule enables an analysis to be made beforehand which will assist in obtaining maxiumum efficiency in the operation.
SUBSEA PIPELINE CONNECTIONS AND REPAIRS USING DRY HABITATS
Authors: Donnet J. P.
Published: August 2017

Research on hyperbaric welding was carried out by Comex several years ago.The first hyperbaric weld on site in 1975 was the result of about twenty hyperbaric tests performed at the Comex hyperbaric centre in Marseilles. These tests took place at simulated depths from 75 m to 155 m and allowed the evaluation of different welding processes such as Tungsten Inert Gas (T.I.G.), Manual Metal Arc (M.M.A.), Metal Inert Gas (M.I.G.).Divers, welders and pipe fitters follow extensive training programmes before being involved in evaluation tests. Professional welders are first selected for diving courses and qualified for subsea work. They then perform qualification tests on specified welding procedures and are finally assigned to various tie -in operations.Comex has designed and built four subsea pipeline connection spreads which cope with the range of operational configurations required by the industry. A spread consists of alignment equipment, welding habitat and diving system with the appropriate surface support. The range of sizes vary from a 12-tonne repair habitat to a massive 250 -tonne alignment and welding frame. The field applications of these techniques to this day have been in the North Sea in water depths ranging from 90 to 155 m.
NATURAL GAS TRANSPORTATION AND UTILISATION IN AUSTRALIA
Authors: Baker T. R.
Published: August 2017

The Pipeline Authority commissioned the Snowy Mountains Engineering Corporation in association with Société Francaise d'Etudes et de Réalisations d'Equipements Gaziers (SOFREGAZ) to conduct an independent study of Australian natural gas utilization and transportation to the year 2000. A summary of the study was published in November 1976 and copies of the full report were made available for review and comment by State Government bodies, gas exploration and production companies, gas distribution utilities and other interested parties.The report concluded that there will be a shortfall in the supply of natural gas for the eastern states before 1990 even if natural gas is not used for those applications for which coal and electrical energy are not suitable alternatives. The report also concluded that a pipeline from Dampier to the Cooper Basin appears to offer an economic means of meeting the natural gas demands of all demand centres to the year 2000.It is obvious from the comment on the report that there are widely differing opinions within the gas industry on the probable demand for, and utilisation of natural gas in Australia. In addition there have been a number of important discussions and developments since the report was completed.The findings of the report have been reviewed in the light of the comment received and the subsequent decisions and developments and it has been concluded that the greatest uncertainty lies in the future availability of natural gas for Australian consumption. There is therefore a need to establish, with greater certainty, the natural gas reserves, particularly in central and eastern Australia so that future planning can be based on reliable data.
A CASE HISTORY OF ROUGH RANGE
Authors: Johnstone M. H.
Published: August 2017

Rough Range No. 1 was the first well to be drilled for oil in Western Australia in the post-war period. It was spudded on September 5th, 1953. At a depth of 1100m, the well encountered a flow of oil at a rate of 500 bbls per day from the Early Cretaceous Birdrong Sandstone. This first discovery of flowing oil in Australia set off a boom in exploration for oil that rivalled the gold mining booms of the last century. The discovery well was drilled for a total of 20 months, encountering a section of Tertiary, Cretaceous, Jurassic, Permian, and Carboniferous -? Devonian rocks. By May 1955, when Rough Range No. 1 was terminated, a further seven wells had been drilled on the Rough Range Anticline and all were dry. Late in 1955, Rough Range -9 was drilled but also proved dry. Rough Range-10 was drilled less than 200m from the discovery well but only found a thin, non-commercial pay zone.Studies of the Rough Range structure, incorporating data from all of the wells and the intense seismic mapping of the feature show that the area of closure is very small and the total accumulation could not be more than 282,000 bbls of oil in place in the reservoir.Assuming a 30% recovery factor, the accumulation is capable of producing approximately 84,600 bbls. Of this, 16,900 bbls has already been produced in a 48-day production test of Rough Range-1 A in 1955. WAPET believes that the small remaining reserves, even at world parity pricing, are not economically viable.Although the small accumulation at Rough Range No. 1 was a disappointment to WAPET, this first post-war oil well proved to be a "lucky break" and a big stimulus for oil exploration in Australia.
STRATIGRAPHIC CONCEPTS AND PETROLEUM POTENTIAL OF THE DENISON TROUGH, QUEENSLAND
Authors: Paten R. J. , Brown L. N. , Groves R. D.
Published: August 2017

The Denison Trough in east central Queensland contains up to 4600m of both marine and non-marine, Permian and Triassic rocks. The sequence comprises thick mature source rocks interlayered and interfingering with thick sandstone intervals. Good to excellent sandstone reservoirs occur, though their distribution and development is sporadic and controlled by both despositional and diagenetic processes. This is the main limitation to the potential of the area. Source rocks appear to be gas or gas/condensate prone, although liquids generation cannot be discounted.Exploration to date, comprising extensive seismic and the drilling of 39 exploration and 29 assessment wells, has led to the discovery of four small gas fields with combined reserves of approximately 850-1140m3 x 106. These reserves are insufficient to justify exploitation at this time. Apart from the fields, numerous gas shows and minor oil shows have been recorded throughout the Permian sequence, establishing beyond doubt that the trough is a hydrocarbon province.The trough is assessed as having a high potential for the discovery of additional gas reserves, with a possible 15-55m3 x 109 being present both in deep structural plays and in shallower, essentially stratigraphic, plays. Further successful exploration will require both good quality structural control, particularly at depth and a sound understanding of the depositional processes controlling the development of reservoir sands. Since active exploration effectively ceased in the area in 1970, a great deal of stratigraphic information has become available. This has led to a better understanding of the stratigraphy than was previously possible. In addition, advances in seismic technology over the last decade have made available much more reliable exploration tools, with respect to achieving good quality, deep structural control and to stratigraphic interpretation and reservoir trend prediction.The Denison Trough is considered to be one of the most prospective of Australia's onshore basins. It remains to be seen; however, if the application of present stratigraphic/depositional knowledge and new seismic technology will result in its potential being realised.
A NEW METHOD FOR MEASURING THE MATURITY OF PETROLEUM IN SOURCE ROCKS
Authors: Woodhouse R. Alexander R.I. Kagi G.W.
Published: August 2017

Values obtained from proton magnetic resonance measurements on the aromatic fraction of source rock extracts are proposed as a quantitative measure of the maturity of source rock hydrocarbons. The percentage of aromatic protons in the aromatic fraction is shown to correlate with the measured sediment temperatures for several different sedimentary sequences. Pyrolysis experiments have shown that these changes are due to thermal maturation of petroleum hydrocarbons. The application of the technique to routine source rock evaluation is discussed.
MATURATION PATTERNS IN THE PERTH BASIN
Authors: Kantsler A. J. , Cook A. C.
Published: August 2017

Vitrinite reflectance data from wells drilled in the Perth Basin show that major variations exist in the pattern of rank distribution within the basin. Generally, rank gradients are low and near linear, but some wells show curvature of the rank profile in the Early Jurassic and Triassic parts of their sections. Curvature of the rank profile is generally associated with a shallow depth to basement, but the presence of very high ranks in parts of the Permian section on the Beagle Ridge suggests that a Permian to Jurassic thermal event associated with local igneous activity or the initiation of rifting, or both, may also be a controlling factor. Low, linear rank gradients from parts of the basin such as the Bunbury Trough and the thick Upper Jurassic sections of some of the deeper sub-basins are taken to indicate that low geothermal gradients have operated since the Permian,in the former instance and certainly since the Jurassic in the latter. Such conditions imply slow generation of hydrocarbons.Higher geothermal gradients and rank gradients in parts of the basin as in the north Dandaragan Trough and Vlaming Sub-basin imply enhanced hydrocarbon generation, particularly as calculated palaeotemperatures indicate that the advent of higher geothermal gradients is likely to have been relatively recent. Potential source rocks occur throughout the basin and provided that suitable structural and reservoir conditions can be delineated, the prospects of discovering more commercial hydrocarbon deposits are high.
NEW DEVELOPEMENTS FOR DIVING SUPPORT OF SUBSEA OPERATIONS
Authors: Gray W. E.
Published: August 2017

The infusion of new technology into the offshore industry has resulted in the introduction of many types and variations of new diving systems. In addition to conventional hyperbaric manned diving and manned submarines, these include atmospheric diving suits, tethered remotely controlled submersibles, one atmosphere diving bells with manipulators and a variety of remotely controlled subsea tools.This paper reviews the current status of such systems, describes operating experiences with typical systems, and suggests criteria for selection of preferred systems. Areas of usage include exploratory drilling, field construction and development, survey, and inspection and maintenance.
FINANCE FOR DEVELOPMENT
Authors: Hamley B.L.
Published: August 2017

Australia's development capital requirements cannot be solely financed from domestic savings but need to be supplemented by overseas capital. Thus there should be no impediments to the inflow of overseas funds and variable deposit ratio controls (currently suspended) should be abolished.Overseas capital inflow is important for the balance of payments, as imports of capital goods are likely to rise during the developmental stage of large resource projects. Exports in subsequent years will provide the funds for amortization of borrowings.However the Australian capital markets can still provide for adequate local participation and funding. In particular, Australian banks have a capacity to finance our share of large projects, but it will be argued that a less controlled banking system will improve its long term ability in this regard.As a consequence the relationship between money supply management and interest rates will be discussed.Overall the capital needs of structural change will be reviewed with the conclusion that Australia is already turning its attention to capital investment in areas of comparative advantage - resource development, particularly beneficiation of raw materials.
REGIONAL GEOLOGY AND HYDROCARBON POTENTIAL OF THE MESOZOIC OF THE WESTERN PAPUAN BASIN, PAPUA NEW GUINEA
Authors: Burns B.J. , Bein J.
Published: August 2017

Jurassic and Cretaceous clastics of the Western Papuan Basin provide reservoir and source potential for hydrocarbon accumulation. Early Jurassic coarse clastics from sources in the south and west cover a wide stable platform area, while finer grained equivalents were deposited in a deepening trough along the east and northeast margins. A Middle Jurassic transgression deposited a thick shale unit over most of the basin, followed by a return to sand and silt deposition in the Late Jurassic-Early Cretaceous. Eocene/Miocene structuring in the north formed the Omati Trough which filled with deep water Miocene carbonates. This was followed by shallow water carbonates which cover the Western Papuan Basin. Mountain ranges to the north and northeast were the source for thousands of feet of poorly sorted Plio- Pleistocene sediments which were dumped in the rapidly subsiding Aure Trough and spread as a veneer over the remainder of the Papuan Basin.Geochemical studies indicate that adequate source rocks exist within the Mesozoic shales and these reach maturity at a depth of about 2700m. The Mesozoic shales correlate more closely with the various oil and condensate seeps than do the Miocene carbonates which are generally too immature over much of the basin to be considered as a significant oil source.The stable platform, except for the Omati Trough, has undergone very little tectonic movement since the Triassic and this has severely restricted the formation of structural traps suitable for hydrocarbon entrapment. Better structuring exists to the east of a Mesozoic hinge-line running approximately north- south just offshore from the present-day coastline, but lack of good Mesozoic reservoir sands in this area limits the hydrocarbon prospects. The most prospective area is the structured margin of the Omati Trough, where tilted fault blocks provide traps for hydrocarbons generated from the underlying shales of the Cretaceous and Jurassic, but difficult terrain and high exploration costs make for high risk exploration.
OIL GEOCHEMISTRY AND POTENTIAL SOURCE ROCKS OF THE OFFICER BASIN, SOUTH AUSTRALIA
Authors: McKirdy D.M. , Kantsler A.J.
Published: August 2017

Oil shows observed in Cambrian Observatory Hill Beds, intersected during recent stratigraphic drilling of SADME Byilkaoora-1 in the Officer Basin, indicate that oil has been generated within the basin. Shows vary in character from "light" oils exuding from fractures through to heavy viscous bitumen in vugs in carbonate rocks of a playa-lake sequence.The oils are immature and belong to two primary genetic families with some oils severely biodegraded. The less altered oils are rich in the C13 - C25 and C30 acyclic isoprenoid alkanes. Source beds within the evaporitic sequence contain 0.5 - 1.0% total organic carbon and yield up to 1900 ppm solvent-extractable organic matter. Oil-source rock correlations indicate that the oils originated within those facies drilled; this represents the first reported examples of non-marine Cambrian petroleum. The main precursor organisms were benthonic algae and various bacteria.Studies of organic matter in Cambrian strata from five other stratigraphic wells in the basin reveal regional variations in hydrocarbon source potential that relate to differences in precursor microbiota and/or depositional environment and regional maturation. Micritic carbonates of marine sabkha origin, located along the southeast margin of the basin, are rated as marginally mature to mature and good to prolific sources of oil. Further north and adjacent to the Musgrave Block, Cambrian siltstones and shales have low organic carbon values and hydrocarbon yields, and at best are only marginally mature. Varieties of organic matter recognised during petrographic studies of carbonates in the Officer Basin include lamellar alginite (alginite B) and "balls" of bitumen with reflectance in the range 0.2 to 1.4%.
THE PETROLEUM PROSPECTS OF THE GREAT BARRIER REEF REGION
Authors: Benbow D.D.
Published: August 2017

The Great Barrier Reef Region covers some 207 000 sq. km of Queensland continental shelf between 9° 30'S and 24°S. The Reef ranges from Late Tertiary to Recent age with reefal growth mainly over platform areas of shelf sediments or basement rocks.The Reef area is underlain in part by seven basins which are either wholly or in part offshore; these basins are from north to south, the Peninsula Trough (Jurassic to Recent), Laura Basin (Permian to Cretaceous), Halifax Basin (Cretaceous to Recent), Hillsborough Basin (Early to Middle Tertiary), Styx Basin (Cretaceous), Capricorn Basin (Cretaceous to Recent and the Maryborough Basin (Jurassic to Tertiary).The geophysical coverage of the area is regional and only small areas of several of the basins have been covered by detailed seismic. During 1973 the Bureau of Mineral Resources conducted a seismic survey over the Queensland Plateau and adjacent Barrier Reef region: the results of this survey provide the geophysical basis for the basin evaluation.Four petroleum exploratory wells have been drilled in Queensland waters; these include Anchor Cay at the northern extremity of the Reef, and three wells in the Capricorn Basin.The petroleum potential of the region will remain speculative until further drilling is carried out to assess the stratigraphic section.
LOW PERMEABILITY SANDSTONES IN AUSTRALIA CAN BE FRACTURE STIMULATED
Authors: Magus D.J. , Bratrud T.F. , Molnar E.L. , Wiltshire M.J.
Published: August 2017

Given adequate incentives, markets and pricing, a very substantial source of hydrocarbons may be recoverable from low-grade sand reservoirs which previously were considered non-commercial. With escalating energy costs and modern reservoir stimulation technology many of the sedimentary basins in Australia, containing large volumes of gas locked in low permeability reservoirs, could conceivably be developed into commercial projects.In recent years exploration of comparable reservoirs in Canada has proven highly successful to where these reserves now contribute a major portion of the country's total energy needs. A preliminary study has been conducted to identify similar low permeability sands in Australia and to attempt a comparison of reservoir and mineralogical properties. Examples of specific fracture treatments and associated response are presented. In view of similarities in matrix composition and pore distribution, evidence suggests that properly engineered fracturing treatments would be successful in Australia. From this, one can only speculate upon the vast potential of low quality reservoirs which were previously overlooked.
SOURCE, MATURITY AND GAS COMPOSITION RELATIONSHIPS IN THE SOUTHERN COOPER BASIN
Authors: Schwebel D.A. , Devine S.B. , Riley M.
Published: August 2017

In the Permian sedimentary sequence of the Cooper Basin, land plants contributed the bulk of the organic matter to the sediments. Inertinite, vitrinite and exinite are common kerogen types present in the organic-rich shales. Coal thickness varies areally.The geothermal gradient, though varying (from area to area), is everywhere higher than normal for sedimentary basins. The whole of the Permian sequence is mature for hydrocarbon generation. The highest temperature gradients of up to 3.19°F/100’ are measured in the Nappamerrie Trough and are associated with areas of granitic basement. Vitrinite reflectance profiles confirm that the sediments are thermally mature.Trends of gas composition indicate three distinct regions with gases trapped in:the Patchawarra Trough tend to be high in CO2 and wet gas;the Nappamerri Trough tend to be high in CO2 and low in wet gas; andthe Tennapera Trough tend to be low in CO2 and moderately high in wet gas.These differences in gas composition are accounted for by differences in thermal history within structural zones.
THE HIGH COST OF CARING
Authors: Butler W.H.
Published: August 2017

Protests and mandatory government requirements are manifestations of current public environmental awareness. The fulfilment of each requirement takes time, effort and money and the total cost of these must be added to the consumer price of the final product, thus increasing general trends to inflation.Conservation and environmental awareness are seen to be short term processes under the benign influence of affluent democratic governments. Emergent or developing nations rarely can afford the luxury of conservation, being more concerned with upgrading the standard and quality of life of their populace.The growth and development ethic which triggers our way of life is inherent in all living things, either individually, collectively, or racially, and so cannot be interpreted by current value judgements as being good or bad.Future needs and challenges are seen to be the central involvement of environmental awareness in community planning and life style. Such planning will, of necessity, accept the intrinsic right to life of all other life forms.
DEPOSITION OF THE PRECIPICE SANDSTONE AND THE EVOLUTION OF THE SURAT BASIN IN THE EARLY JURASSIC
Authors: Martin K. R.
Published: August 2017

The Precipice Sandstone, the basal formation of the Surat Basin sequence, is an Early Jurassic quartzose sandstone, which extends to the west and east beyond the limits of the Surat Basin.Throughout most of the basin, the formation consists of medium to coarse-grained, porous, quartzose sandstone with well-developed medium-scale planar cross-bedding. In the subsurface on the Roma Shelf, the formation is more variable in its grain size and porosity/permeability but is generally finer grained than elsewhere in the basin.Sedimentary structures and vertical profile characteristics for the Precipice Sandstone, throughout most of the basin, indicate that the sandstone was deposited as transverse bars in a braided stream system flowing on a gradient of approximately 1m/km. The sandstone on the Roma Shelf shows characteristics of a lower gradient meandering stream depositional system.The palaeogradient and palaeoslope directions predicted from sedimentary data, which indicate a consistent west to east current direction across the northern Surat Basin, are incompatible with previously published interpretations based on use of the datum plane/valley floor isopach method. It is suggested that the isopach method has yielded erroneous results, as a result of the effects of differential subsidence in the underlying Permo-Triassic Bowen Basin sequence.The Precipice Sandstone is a diachronous fluviatile facies, which transgressed in a westerly direction, and was replaced by the finer grained fluviolacustrine Evergreen Formation. The sandstone on the Roma Shelf probably represents the last stages of low-energy fluviatile deposition prior to the transition to the Evergreen Formation. The main sediment source for the Precipice Sandstone probably lay to the west and south of the Great Artesian Basin in Precambrian areas such as the Willyama Inlier.
WOODADA 1—A DISCOVERY IN THE PERTH BASIN
Authors: Norlin W. K.
Published: August 2017

The year 1980 saw the first significant gas discovery to be made in the Perth Basin in many years. The basin has been explored sporadically since about 1960. West Australian Petroleum Pty Ltd made discoveries in the Dongara area in 1966-68 and production is still underway from these fields. Subsequent discoveries in the Perth Basin have been disappointing on test. The basin has a history of sandstone reservoirs with either limited areal extent, poor porosity, poor permeability, or all three. However, ample source, seal and trapping structures have been proven in numerous wells.The Woodada discovery well was drilled in a previously untested part of the basin with the nearest deep exploration well some 20 km away. The discovery well flowed gas at a maximum rate of 33.4 MMcf/D through a 1 in choke. The well is significant, in that large quantities of gas with minor condensate were tested from a Permian carbonate reservoir not previously considered or tested as a potential reservoir. A step out well, offset 1.2 km, flowed at a similar rate. The discovery may thus herald the opening of a new and vigorous phase of exploration in the Perth Basin.
IMAGING BENEATH COMPLEX STRUCTURE: A CASE HISTORY
Authors: Lamer K. , Gibson B. , Chambers R.
Published: August 2017

Migration is recognised as the essential step in converting seismic, data into a representation of the earth's subsurface structure. Ironically, conventional migration often fails where migration is needed most—when the data are recorded over complex structures. Processing field data shot in Central America, and synthetic data derived for that section, demonstrates that time migration actually degrades the image of the deep structure that lies below a complicated overburden.In the Central American example, velocities increase nearly two-fold across an arched and thrust-faulted interface. Wavefront distortion introduced by this feature gives rise to distorted reflections from depth. Even with interval velocity known perfectly, no velocity is proper for time migrating the data here; time migration is the wrong process because it does not honour Snell's Law. Depth migration of the stacked data, on the other hand, produces a reasonable image of the deeper section. The depth migration, however, leaves artifacts that could be attributed to problems that are common in structurally complicated areas: (1) departures of the stacked section from the ideal, a zero-offset section; (2) incorrect specification of velocities; and (3) loss of energy transmitted through the complex zoneFor such an inhomogeneous velocity structure, shortcomings in CDP stacking are directly related to highly non- hyperbolic moveout. As with migration velocity, no proper stacking velocity can be developed for these data, even from the known interval-velocity model. Proper treatment of nonzero-offset reflection data could be accomplished by depth migration before stacking. Simple ray-theoretical correction of the complex moveouts, however, can produce a stack that is similar to the desired zero-offset section.Overall, the choice of velocity model most strongly influences the results of depth migration. Processing the data with a range of plausible velocity models, however, leads to an important conclusion: although the velocities can never be known exactly, depth migration is essential for clarifying structure beneath complex overburden.
RESERVOIR DATA ANALYSIS AT THE WELLSITE
Authors: Anderson Terry O. , Ott William K. , Ajam Sami , Kyle. Don
Published: August 2017

Current drill-stem test pressure-recording techniques rely on a pressure sensor, a chart recorder and a clock. Analysis and interpretation of this recorded data can only be done after the tool string is retrieved from the well.The subject of this paper is a computer-based system that monitors, records, analyzes and displays at the wellsite, supplying the reservoir data necessary for the well operator to make a production decision about the well.This system uses the capabilities of full-opening testing strings to provide instantaneous display of pressure and temperature information at the time intervals selected by the operator. Because the system provides a continuous stream of data (at selected intervals) the printer-plotter can display results of computer calculations and make graphs necessary for evaluation of the reservoir. The well operator can judge by the data received when the test can be terminated, and so could shorten significantly the rig time used for the test.A conventional 'pressure vs. time plot' is made throughout the test, and Horner, Log-Log and 'pressure vs. square root of time plots' are available on operator demand. The well operator can also obtain calculations of the well's theoretical potential at the conclusion of the test or during any flow period after closed-in pressure data accumulate.
AUSTRALIAN RESOURCE DEVELOPMENT - CAN FINANCIAL REQUIREMENTS BE SATISFIED?
Authors: Grehan D. R. P.
Published: August 2017

While it is of the utmost importance to maintain Australia's existing level of self-sufficiency in the production of oil and its related products, this industry receives very little tangible support for its endeavours in this regard. When the participants in the industry require finance, particularly for project development, they find that they have to compete on the open market for the necessary funds. In the coming decade there will be very heavy demands placed on the financial markets in this country, particularly from the minerals area where huge amounts of capital will be required. Additionally, we can expect certain sectors of the community to receive favoured treatment at the expense of the more efficient sectors.During the mineral boom of the early 70s the percentage of foreign ownership of Australian resources increased. During the 80s it appears that the reverse may be the case, as greater Australian participation in the development of this country's resources may be required. Accordingly it may be more difficult to have the Foreign Investment Review Board approve an application from a possible foreign partner who is willing to inject capital into a project.These possible restrictions on fund raisings may result in delays for many projects and could well cause the cancellation of others which are now marginally feasible.
GEOCHEMICAL INTERPRETATION OF SOME OILS AND CONDENSATES FROM THE DAMPIER SUB- BASIN OF WESTERN AUSTRALIA
Authors: Brikké I.
Published: August 2017

Twenty oils and condensates from the Dampier Sub-basin have been analysed for their gross composition and normal alkane distribution.The chemical composition (GLC traces) enables two groups to be distinguished:Oils and condensates low in C22 + n-alkanes. These are essentially found in the Rankin Platform. In this group, the sample from Eaglehawk 1 shows characteristics of a bacterially-altered product.Oils richer in C22 + n-alkanes. These are found in the Lewis Trough, but also in the Rankin Platform/Kendrew Terrace where subtle differences may suggest different origins.The geological interpretation puts strong emphasis on time of trapping. The oils and condensates of the first group (except at Angel) are trapped at the contact with the 'Main Unconformity'. Oils formed earlier than the Neocomian have been destroyed, altered (Eaglehawk 1) or trapped in deeper reservoirs, so that only mature to very mature hydrocarbons (low in C22 + n-alkanes) were available for trapping after sealing by Neocomian shales. Maturity considerations indicate that a deep source within the core of the Rankin Platform unit (Middle/Early Triassic Locker Shale and/or older) is the most likely generator of these hydrocarbons.The oils of the second group, on maturity grounds and to some extent on type correlation, may originate from Jurassic sources in the Lewis Trough. Some oils attributable to the second group are present on the Rankin Platform and/or Kendrew Terrace trapped by intraformational/fault seals and having the full composition of crudes; however, lower land-plant contribution inferred from the n-alkanes, suggests a 'Locker Shale' origin.The source of the Angel hydrocarbons is more enigmatic, but their strong affinity with the hydrocarbons from the Rankin Platform points to a similarity of origin.
HYDROCARBON POTENTIAL OF THE ARCKARINGA REGION, CENTRAL SOUTH AUSTRALIA
Authors: Moore P. S.
Published: August 2017

The Arckaringa region is a large area which lies between the Officer Basin and the Peake and Denison Ranges in central South Australia. It includes sedimentary rocks of Jurassic-Cretaceous, Permo-Carboniferous and ?Cambrian ages. The thickest sequence of sediments (about 2000m) occurs in the Boorthanna Trough, located immediately to the west of the Peake and Denison Ranges. Cretaceous sediments of the Eromanga Basin form a veneer over much of the area. Oil shows at very shallow depths in immature sediments at Oodnadatta 1 raise speculations about the possibility of shallow generation of hydrocarbons in the Eromanga Basin. However, most of the petroleum exploration in the region has been aimed at delineating the underlying Permo-Carboniferous Arckaringa Basin sequence. The Arckaringa Basin is not a simple sedimentary depression but rather a series of peripheral depressions surrounding a central platform region. Unlike the Cooper and Pedirka Basins, it contains some marine sediment, suggesting the possibility of an oil-prone rather than a predominantly gas-prone province. Due to the thin nature of the sequence and its shallow depth of burial, most of the Arckaringa Basin is predicted to be immature for hydrocarbon generation in traditional terms. However, source-rock and vitrinite studies in the Boorthanna Trough indicate that the basal units are marginally mature to mature in this area. Early Cambrian carbonates are interpreted to extend southeastwards in an arc from Byilkaoora 1 in the Officer Basin, through the Boorthanna Trough, and onto the Stuart Shelf. In the Boorthanna Trough these carbonates are named the Cootanoorina Formation. They are of varied lithology and are associated with terrigenous clastics and minor evaporites. Vugular porosity occurs sporadically in the sequence, which may be thicker than 1000m in some of the deeper parts of the trough. Source-rock studies suggest that the sequence is immature to marginally mature in Weedina 1 and Cootanoorina 1.It is emphasised that the Arckaringa region is largely unexplored for hydrocarbons, with only two wells drilled on structural targets in the entire area of about 60 000 sq km. This report presents source-rock and maturation data which suggest that the sequence is more mature than originally predicted, and that the deeper parts of the Boorthanna Trough may have a modest potential for oil, both in the basal Permo-Carboniferous and in the ?Cambrian Cootanoorina Formation. An active exploration programme has begun, with several hundred kilometres of seismic surveys planned for 1982.
THE UNDISCOVERED OIL AND GAS POTENTIAL OF AUSTRALIA
Authors: McKAY B.G.
Published: August 2017

In 1982 Esso Australia completed a fundamental re-assessment of the undiscovered oil and gas potential of Australia. In the seven years since Esso's previous major study there has been a marked upsurge in exploration for hydrocarbons, particularly oil. During this period several hundred wells have been drilled and hundreds of thousands of kilometres of seismic data have been recorded. New discoveries of both oil and gas have been made in several areas. Because of this influx of new data, a re-assessment was considered timely.The assessment utilised computer-based techniques and incorporated improvements in assessment and risk theory. The study involved the identification of more than one hundred individual plays followed by the volumetric and risk assessment of those plays. The risked assessments of the individual plays were then combined to produce an overall assessment for Australia in the form of cumulative probability distributions for oil and gas.The results show that the potential exists in Australia to find a significant volume of additional oil, possibly equivalent to the amount of oil discovered to date. The assessment also indicates a high probability of abundant undiscovered gas.Although the perceived resource base is quite encouraging, no consideration was given in the assessment to operational, economic or political constraints. Consequently there is no discovery time-frame implied within the assessment results. The rate of discovery will be determined by the amount and quality of exploration effort, which in turn will be dictated by the economic and political environment under which industry is allowed to operate.
NEW ZEALAND GAS TO GASOLINE PLANT
Authors: Maiden Colin J.
Published: August 2017

In 1979 the New Zealand Government adopted a recommendation by the Liquid Fuels Trust Board to allocate 50-60 petajoules per year of the country's natural gas resources to manufacture synthetic gasoline using a process developed by Mobil Oil Corporation. Following a joint study, Government and Mobil concluded that the establishment of a plant to produce synthetic gasoline was economically, commercially and technologically feasible. Construction of the plant commenced on March 12, 1982 and is scheduled for completion third quarter 1985, with full production expected by the beginning of 1986. The plant will be owned and operated on a tolling basis by New Zealand Synthetic Fuels Corporation Limited with a shareholding of Government 75 percent, Mobil 25 percent. The conversion of natural gas to gasoline occurs in two stages: first gas-to-methanol (GTM) and second methanol-to-gasoline (MTG). The GTM facility has two methanol trains, each with the capacity of 2200 tonnes a day (on a pure methanol basis) and employs the ICI Low-Pressure Methanol Process sub-licensed from Davy McKee. The 4400 tonnes of methanol are then converted to 1654 tonnes a day of synthetic gasoline in the MTG plant which incorporates Mobil's fixed bed catalytic process using its proprietary zeolite catalyst, ZSM-5. The design has been scaled up from a four barrel a day pilot plant, and the New Zealand plant will be the first commercial application of the Mobil process. Its annual capacity of 570,000 tonnes of gasoline represents some 35 percent of New Zealand's requirements. The capital cost of the plant has been estimated at $1475 million dollars of the day which includes fees and start-up costs, inflation and interest capitalised during construction. This will be financed by shareholder equity of $275 million and a loan facility of $1200 million with a standby provision of $500 million.
HYDROCARBON HABITAT OF THE COOPER/EROMANGA BASIN, AUSTRALIA
Authors: Kantsler A. J. , Prudence T. J. C. , Cook A. C. , Zwigulis M.
Published: August 2017

The Cooper Basin is a complex intracratonic basin containing a Permian-Triassic succession which is uncomformably overlain by Jurassic-Cretaceous sediments of the Eromanga Basin. Abundant inertinite-rich humic source rocks in the Permian coal measures sequence have sourced some 3TCF recoverable gas and 300 million barrels recoverable natural gas liquids and oil found to date in Permian sandstones. Locally developed vitrinitic and exinite-rich humic source rocks in the Jurassic to Lower Cretaceous section have, together with Permian source rocks, contributed to a further 60 million barrels of recoverable oil found in fluvial Jurassic-Cretaceous sandstones.Maturity trends vary across the basin in response to a complex thermal history, resulting in a present-day geothermal gradient which ranges from 3.0°C/100 m to 6.0°C/100 m. Permian source rocks are generally mature to postmature for oil generation, and oil/condensate-prone and dry gas-prone kitchens exist in separate depositional troughs. Jurassic source rocks generally range from immature to mature but are postmature in the central Nappamerri Trough. The Nappamerri Trough is considered to have been the most prolific Jurassic oil kitchen because of the mature character of the crudes found in Jurassic reservoirs around its flanks.Outside the central Nappamerri Trough, maturation modelling studies show that most hydrocarbon generation followed rapid subsidence during the Cenomanian. Most syndepositional Permian structures are favourably located in time and space to receive this hydrocarbon charge. Late formed structures (Mid-Late Tertiary) are less favourably situated and are rarely filled to spill point.The high CO2 contents of the Permian gas (up to 50 percent) may be related to maturation of the humic Permian source rocks and thermal degradation of Permian crudes. However, the high δ13C of the CO2 (av. −6.9 percent) suggests some mixing with CO2 derived from thermal breakdown of carbonates within both the prospective sequence and economic basement.
THE HUTTON SANDSTONE - TWO SEPARATE RESERVOIRS IN THE EROMANGA BASIN, SOUTH AUSTRALIA
Authors: Gravestock D. , Griffiths M. , Hill A.
Published: August 2017

The Hutton Sandstone in the South Australian portion of the Eromanga Basin consists of two units, one Early to Middle Jurassic, the other Middle to Late Jurassic in age. The younger unit may conformably overlie the older in areas of persistent subsidence but either may be thin or absent in areas of complex structure.Siliceous and calcareous authigenic cements at the top of the older unit and within the younger unit indicate surficial weathering in a warm arid to humid climate, supported independently by palaeofloral and faunal evidence. Duricrusts of Middle to Late Jurassic age have been recorded in outcrop from the southwest Eromanga Basin margin and the Surat Basin region.Both units have disconformity trap potential and the younger unit has additional poor to excellent stratigraphic trap potential. Exploration strategies will be enhanced by mapping each unit as a separate reservoir and by recognizing the downflank stratigraphic trap potential of the younger unit.
HIGH PRESSURE SNUBBING OPERATIONS WITH ANNULAR PREVENTERS
Authors: Vujasinovic A. , Moore W.
Published: August 2017

The use of snubbing techniques for through-tubing and complete workover operations offers several advantages over conventional methods. First, the work can be done under pressure, which means that the use of heavy kill fluids and subsequent potential formation damage is eliminated. Second, the well can be placed on production quickly because no cleanup time is required.To further increase the speed of the snubbing operation, a new technique has been successfully tested, which consists of using a special high pressure annular preventer in the snubbing package: with this arrangement, the tubing can be pulled almost continuously, avoiding the time consuming stripping through a ram preventer stack, where rams must be opened and closed in sequence every time a tubing joint is pulled.This paper describes and documents several factual high pressure (up to 10,000 psi) snubbing operations performed through the annular preventer, including stripping and rotating when drilling through bridge plugs, and compares the time and cost savings with equivalent snubbing operations performed in the conventional manner.
PETROLEUM EXPLORATION DEVELOPMENTS IN NEW SOUTH WALES DURING 1982
Authors: Battersby D. G.
Published: August 2017

Thirty-eight Petroleum Exploration Licences were in force in New South Wales at the end of 1982. During 1982, nine permits expired or were cancelled, one was granted and three applications were received.Three onshore exploration wells were drilled in New South Wales during 1981/82 (Table 1). All three wells were plugged and abandoned. No wells were drilled offshore. Eleven seismic surveys, totalling 1,611 kilometres, were carried out during 1981/ 82 (Table 2). In addition, one offshore survey of 1,742 kilometres was undertaken.
PETROLEUM EXPLORATION DEVELOPMENT IN TASMANIA DURING 1982
Authors: Davidson J. K.
Published: August 2017

1982 was a year of mixed fortune for petroleum exploration in Tasmania. Although the year opened on a high note with two wells to be drilled, the first in three years, the Pipipa I well in the Bass Basin was a dry hole and Cape Sorell I in the West Tasmanian Sub-Basin did not report a discovery. Further discouragement resulted from no applications being made for offshore acreage offered on the west, south and east coasts and minimal activity occurred onshore.
BOOBYALLA SUB-BASIN : A CRETACEOUS ONSHORE EXTENSION OF THE SOUTHERN EDGE OF THE BASS BASIN
Authors: Moore W. R. , Baillie P. W. , Forsyth S. M. , Hudspeth J. W. , Richardson R. G. , Turner N. J.
Published: August 2017

Geophysical methods, including gravity, magnetics, refraction and reflection seismic, together with drilling have revealed the presence of a steep, fault-bounded trough of Cretaceous age in the Boobyalla Plains area, northeastern Tasmania. The trough is at least 500 m deep and contains the first proven Cretaceous sedimentary sequence from onshore Tasmania in the Boobyalla Sub-basin. The Boobyalla Sub-basin is the southeastern extremity of the Bass Basin and is bounded by faults having NW-SE, N-S and NE-SW trends.These Late Cretaceous sediments consist of poorly sorted boulder conglomerate, often containing dolerite boulders several metres in diameter, pebble conglomerate and poorly sorted ferruginous sandstone. Clast lithologies are variable but reflect local derivation. Away from the trough margins the infilling sediments become finer grained with conglomerate becoming a less prominent part of the sequence. The coarse-grained sequences are interpreted to have been deposited rapidly in close proximity to a fault scarp.The sediments are biostratigraphic equivalents of and represent a proximal (near-source) facies of the Eastern View Coal Measures, which were encountered in Durroon 1, drilled in the Bass Basin and some 60 km northwest of Boobyalla Plains. A minor volcanic episode probably affected this section of the Bass Basin about 100 Ma B.P. This may be related to tectonic disturbances and could be responsible for an unconformity at the base of the Eastern View Coal Measures indicated by offshore seismic information.