bluuebunny/crossref_metadata_2025 huggingface dataset:
INFORMATION TECHNOLOGY- LEVERAGE TO ADD VALUE
Authors: Frost M.F.
Published: August 2017

Master the process of implementing innovative IT and make gains. Choose the wrong IT and suffer. These opposing outcomes are driving cooperation amongst E&P competitors. Pooling resources is an effective strategy to mitigate risk-be it the risk of the Year 2000 Bug or the risk of implementing frontier IT solutions. Narrowly focussed, joint-industry IT initiatives pose realistic hope for practical IT innovations amongst companies that believe IT frontiers fall outside their core competence. Defacto standards will plausibly result and lead to lower costs and reduced complexity. Just such standards pose the opportunity of savings in the range of US$1 to US$3 per barrel produced. Given the IT component of costs is now roughly US$0.25 for each barrel produced, the incentive is clear.Expect change for the better. Encouraging trends include de-facto standards in relational databases (ORACLE), the development of fast processor-indepen- dent program codes (JAVA), powerful search engines and fast internet-type communications.E&P IT will continue to change the way we work. Management will continue to be challenged-to chose fit-for-purpose IT; do so just-in-time; and to maintain access to motivated, well-trained professionals to effectively use those new tools. Shared (cross-functional) databases, easily accessible applications and interconnected workstations are the catalysts for multi-locational, multidisciplinary teams that will improve corporate performance. Implementation of capacity planning metrics can minimise the pain of slow connectivity and system upsets. Organisations that learn how to apply the right IT at the right time will be competitive.
THE PERSEUS FIELD, NORTH WEST SHELF, AUSTRALIA: A GIANT GAS ACCUMULATION IN A COMPLEX STRUCTURAL/STRATIGRAPHIC TRAP
Authors: Taylor M.L. , Thompson N.B. , Taylor N.C.
Published: August 2017

The Perseus Field contains reported expectation (proven plus probable) dry gas and condensate reserves of 6.48 TCF (183 × 109 m3) and 165.7 MMBBL (26.3 × 106 m3), respectively, in a complex structural/stratigraphic trap. Gas is predominantly reservoired in Bathonian shallow marine sandstones of the Legendre Formation which subcrop the Upper Jurassic-Lower Cretaceous 'Main Unconformity' in a graben separating the Goodwyn and North Rankin horsts. The Lower Cretaceous Muderong Shale forms the main regional top seal. The Lower-Middle Jurassic Athol Formation forms the seat seal for the Perseus trap and subcrops the Main Unconformity northwest of North Rankin. The maximum gross gas column for the field is approximately 360 m. The Athol Formation and underlying Murat Siltstone also form the topseal for the small Searipple Field, which underlies Perseus.The Perseus trap is dip-closed to the northwest. A steep fault scarp forms the southern margin of the trap. Trap integrity is dependent upon fault seal along the western flank of the field, where the reservoir section is juxtaposed against Athol Formation claystones in a long narrow fault block downthrown from the Goodwyn block. At the southwestern corner of the field this fault block is absent and the Perseus reservoir is juxtaposed against Triassic reservoir section in the Goodwyn block.The NRA22 well, drilled from the North Rankin A platform, has been producing gas from the Perseus Field since mid-1991. Reservoir pressure measurements and production history data have been of immense value in the exploration and appraisal of this field, both in driving further drilling and in understanding the results. Integration of geoscientific and engineering data and expertise within a multi-disciplinary team was essential for the efficient appraisal and evaluation of the field.
THE PETROLEUM POTENTIAL OF AUSTRALIAN PHANEROZOIC IMPACT STRUCTURES
Authors: Gorter J.D.
Published: August 2017

This paper examines proven, probable, possible and speculative impact structures in Australian Phanerozoic strata and their petroleum potential. There are two classes of crater: simple and complex. The former usually assumes a bowl shaped depression with a raised and overturned rim with a diameter rarely more than three kilometres, with complex structures generally occurring above diameters of two kilometres in sedimentary rocks and four kilometres in crystalline rocks. Complex craters are characterised by a central uplifted area and a classic 'sombrero' structure and can be very large and have diameters of over 800 km. Criteria for the identification of terrestrial impact structures include: (a) circular plan; (b) faulted rim structure; (c) flat floor with central uplift (may not always be present) or interior ring(s); (d) negative gravity anomaly; (e) magnetic low with subdued magnetic relief; (f) brecciated crater fill; (g) low seismic velocities in the crater fill; (h) shock metamorphism (coesite, multiple sets of planar shock lamellae in quartz grains, shatter cones); (i) meteoric material; (j) presence of melt rock; (k) distal ejecta; and occurrence of an annular trough between the central uplift and the outer faulted rim.Proven impact features, like Gosses Bluff and Mt Toondina, are well exposed, contain indisputable evidence of shock metamorphism, and have had extensive geophysical surveys conducted over them: these structures provide models to interpret completely buried structures. Subsurface impact structures have been detected in areas where there has been intensive seismic surveying in the search for hydrocarbons. The Tookoonooka, Talundilly and Mulkarra structures all occur in the Cooper-Eromanga Basin, an area of high intensity exploration. The best known wholly subsurface impact feature is the 66 km diameter Tookoonooka Structure in southwestern Queensland, which exhibits several of the accepted criteria for an impact origin, including shock metamorphism, and is classified as a probable complex type impact structure. The Talundilly Structure, a possible impact feature, lies 300 km to the northeast of the Tookoonooka Structure and is of the same general age. The two structures could reflect the impact of fragments of the same bolide. The Yallallie Structure lies in a moderately explored hydrocarbon province in the central Perth Basin. It has a classic 'sombrero' shape in section view with a central uplift and evidence of shock metamorphism. Yallallie is a probable complex impact structure. The Mulkarra Structure, located in northeastern South Australia, has been classified as a simple type of impact crater lacking a central uplift, but recent geophysical work indicates a probable complex impact origin. Other possible and speculative impact related features described here owe their recognition to good quality seismic surveying.'there are yet some geologists who, adhering to Lyellian dogma, devoutly refuse to accept that large objects fall out of the sky.' (Shoemaker, 1997).
SEQUENCE STRATIGRAPHIC INTERPRETATION OF CARBONATE WIRELINE LOG MOTIFS: AN EXAMPLE FROM THE NORTH WEST SHELF OF AUSTRALIA
Authors: Hull J.N.F. , Smith S.A. , Young H.C.
Published: August 2017

An integrated biostratigraphic, wireline and seismic sequence stratigraphic study has been conducted to constrain the timing and evolution of Late Cretaceous to Tertiary depocentres along the North West Shelf of Australia. During this study a model for the sequence stratigraphic interpretation of wireline logs in this carbonate-dominated regime has been developed.A series of readily identifiable, lowstand clastic deposits interspersed within the predominantly carbonate passive margin section of the North West Shelf provide well-defined correctable events with which to divide the section. Biostratigraphic data have indicated the presence of missing section at the base of these clastic deposits and their shelfal equivalents. These events have been correlated to define sequence boundaries that are represented on wireline log data by a sharp increase in the gamma signature. Lowstand systems tracts exhibit an irregular sonic and upwardly increasing gamma signature. Transgressive systems tracts show characteristically upward-decreasing gamma and sonic profiles. Maximum flooding surfaces have been identified as the point of cleanest carbonate sedimentation represented by gamma minima on wireline logs. Log motifs exhibiting little character have been interpreted as highstand systems tracts. On seismic these sequence stratigraphic events are represented by stratal geometries that would be expected for these systems tracts.The model has enabled the definition of a higher resolution chronostratigraphic framework for the Mid Cretaceous to Recent section of the North West Shelf than has previously been possible. Forty basin-wide events have been identified from the biostratigraphic and wireline log analysis, thirty of which can be tied throughout the Barrow, Dampier and Roebuck basins.
ANALYSIS OF THE DAMPIER SUB-BASIN PETROLEUM SYSTEMS USING INTEGRATED 2D MODELLING TECHNIQUES
Authors: Vear A.
Published: August 2017

Determining the controls on subsurface pressure, and describing fluid flow within the petroleum systems of the North West Shelf's Dampier Sub-basin, were the primary aims of this work.The study was conducted using Temispack, an integrated forward modelling software package developed by the Institut Français du Pétrole (IFP). Three southeast-northwest trending regional seismic lines were modelled, utilising numerous well penetrations for pressure and temperature calibration, lithological and stratigraphical control. Once a detailed understanding of the regional controls on fluid flow and abnormal pressure distribution had been determined, pre-drill predictions were then made to aid the planning and safe completion of a 1996 exploration well.The primary conclusions of the study are that: a) three intervals constitute significant regional aquifers and alleviate overpressures in even the most remote locations of the Dampier Sub-basin-The Tithonian Angel Sands, Bathonian Legendre Sands and Upper Triassic/Lower Jurassic Sands; b) two intervals are capable of producing severe overpressures-The Muderong Shale and any fine-grained Jurassic sections devoid of lateral carrier beds; and c) with a full and accurate knowledge of structure and stratigraphy, the pressures at a drilling location could be accurately predicted using the 2D basin modelling approach.
THE CURRENT STATUS OF THE FAMM THERMAL MATURITY TECHNIQUE FOR PETROLEUM EXPLORATION IN AUSTRALIA
Authors: Wilkins R.W.T. , Buckingham C.P. , Sherwood N. , Russell N.J. , Faiz M. , Kurusingal J.
Published: August 2017

The fluorescence alteration of multiple macerals (FAMM™) technique was developed in 1989-91 to overcome problems encountered by existing techniques applied to the thermal maturity determination of North West Shelf organic matter. Subsequently it has been widely used in Australia, SE Asia and elsewhere. This paper reviews the present status of the FAMM technique.Since its inception, the methodology of the FAMM technique has undergone some changes. The most important is a closer integration with vitrinite reflectance (VR) resulting in expansion of the capacity of the technique to solve complex maturity problems. The accumulated data indicate that shales and mudstones are most suitable for FAMM analysis for the reason that more porous lithologies are potentially more susceptible to organic matter oxidation. There is extensive evidence that organic matter in cores and well-protected cuttings samples of shales remain unaffected by oxidation during decades of storage because clay is extremely effective in limiting access of oxygen. Adhering to sampling guidelines can greatly reduce the risk of errors from this source. Of the two recently described thermal maturity techniques based on combining VR with fluorescence intensity measurements (Quick, 1994; Newman, 1997), FAMM is more closely related to Quick's method. As the fluorescence alteration ratio which acts as the thermal maturity indicator in the FAMM method is independent of VR, it is possible to cross check results for consistency using suppression iso-correction curves-a possiblity which does not exist with the other thermal maturity techniques based on fluorescence. A working set of suppression iso-correction curves has been determined specifically for Australian Jurassic vitrinite. Whether from coal or dispersed organic matter (DOM), Australian Jurassic vitrinites are commonly perhydrous and this should be borne in mind when modelling thermal histories of North West Shelf sequences.
MEASURING EXPLORATION PERFORMANCE AND IMPROVING EXPLORATION PREDICTIONS-WITH EXAMPLES FROM SANTOS' EXPLORATION PROGRAM 1993-96
Authors: Johns D.R. , Squire S.G. , Ryan M.J.
Published: August 2017

In 1993 Santos implemented new business processes and procedures with the intention of improving exploration performance. A uniform decision and risk analysis methodology was introduced to obtain a more consistent approach to prospect evaluation and a review and audit process was put in place to help ensure that exploration prospects were being realistically assessed. An integral part of the process has been to seek improvement in exploration predictions. Results have been tracked since 1993 and performance measures implemented which give detailed feedback to explorationists on their performance and highlight areas of bias or where improvement has occurred.Results from the period investigated indicate that gas prospects have been more realistically assessed than oil prospects. Oil prospects demonstrate an optimistic bias in the evaluation of potential resource size largely as a result of bias in the estimates of hydrocarbon pool area and net pay. However, some improvement in the predictions for oil prospects was noted over the period investigated.
ENVIRONMENTAL MANAGEMENT: INNOVATION THROUGH COOPERATION
Authors: Taylor P.I. , O'Neil B.
Published: August 2017

In 1996 the then Australian Nature Conservation Agency (ANC A) and APPEA formalised a commitment to greater cooperation with the hope of facilitating the achievement of objectives of sustainable development and the pursuit of greater understanding of each other's objectives. Up to this time neither APPEA or ANC A had contemplated such an innovative alliance.The outcomes of this commitment, and the re-signing of the agreement with the Biodiversity Group of Environment Australia, in 1997, has opened up new opportunities to explore innovative strategies which extend beyond the more traditional and adversarial approaches to environmental management and protection.This paper will discuss progress under the agreement and will analyse the lessons learned for Environment Australia in working with industry. An examination will also be made of how we translate the specifics of these lessons to institutional learning, particularly in the context of policy development and the implementation of research and management.The paper concludes with some challenges and a vision for the future.
NON-VOLATILE HYDROCARBON CHEMISTRY STUDIES AROUND A PRODUCTION PLATFORM ON AUSTRALIA'S NORTH WEST SHELF
Authors: Burns K.A. , Codi S.
Published: August 2017

In September 1994 and 1995, scientists from the Australian Institute of Marine Science (AIMS) and the Australian Geological Survey Organisation (AGSO) conducted surveys aboard the Research Vessel Lady Basten to determine the dispersion, fates and effects of Produced Formation Water (PFW) discharged from the Harriet A production platform near the Montebello Islands, on the North West Shelf of Australia. This report describes the non-volatile hydrocarbon chemistry studies.We measured the dispersion of the PFW into dissolved and particulate fractions of seawater using moored high volume water samplers, surface screen samplers and moored and drifting sediment traps. We studied bioaccumulation using transplanted oysters, and we measured dispersion into sediment with benthic grabs. Samples were analysed for total non-volatile hydrocarbons and individual hydrocarbon components using ultraviolet fluorescence spectroscopy (UVF), gas chromatography with flame ionisation detection (GC-FID), and GC with mass selective detection (GC/MS). The hydrocarbon concentrations were used to calculate vertical fluxes and the total concentrations of hydrocarbons in the various ecosystem compartments. A mass balance model was then used to calculate the rates of other important dispersion and degradation processes.We estimate the potential zone of biological impact in the water column extends to a distance of approximately 0.5 nmile (900 m). Concentrations of oil in sediments were too low to indicate potential toxicity. By the collaborative application of oceanographic and geochemical techniques to marine environmental problems, we endeavour to provide effective feedback to the oil industry to gauge the effectiveness of their operational strategies in minimising impact in these pristine regions.
PERMEABILITY AND POROSITY DISTRIBUTION PATTERNS IN A SHOREFACE RESERVOIR: LOWER CRETACEOUS FLACOURT FORMATION, BARROW SUB-BASIN, NORTH WEST SHELF, WESTERN AUSTRALIA
Authors: Kraishan G.M. , Liu K.
Published: August 2017

Porosity and permeability measurements on 926 core plugs were taken from 18 exploration, wildcat and producing wells from the Lower Cretaceous Flacourt Formation, Barrow Sub-basin and analysed for their spatial and temporal variability using both sedimentological and geostatistical methods.The porosity and permeability distribution shows a strong relationship to depositional facies and diagenetic modification. The samples are variably cemented with porosity ranging from 1.3 to 39.4 per cent and permeability from less than 0.01 to 24,400 md. Both porosity and permeability exhibit strong heterogeneity as a result of change of the depositional facies within the same well and the amount of detrital matrix within each facies.The degree of spatial and temporal variability observed in both porosity and permeability data is well reflected by the Levy-stable statistical analysis and variogram modelling. The heterogeneity is shown to be strongly controlled by texture, composition and sedimentary structures of the specific sedimentary facies. The heterogeneity of both permeability and porosity for each individual facies was characterised by the correlation length in the vertical direction from both the variogram and Levy C-gram analyses, and Levy index parameter.The sands of the Flacourt Formation, which form the principal reservoirs in the Barrow Sub-basin, were deposited in a paralic environment. Five major facies were recognised including a tidal channel, an upper shoreface, a middle shoreface, a lower shoreface and a background facies.Sedimentological and statistical analysis of the porosity and permeability of the Flacourt Formation shoreface sandstones enabled us to better understand the heterogenity of the petrophysical properties. The finding can be used to understand similar heterogeneous reservoirs elsewhere, and will provide a basis for reservoir simulations. We have shown that the approach of using genetically related sedimentary facies, can significantly improve the predicability of the porosity and permeability distribution.
MULTI-CLIENT COLLABORATIVE R&D CONTRIBUTING TO NATIONAL PROSPERITY: A TALE OF TWO INDUSTRIES
Authors: Cucuzza J.
Published: August 2017

The business landscape has undergone some significant changes over the last several years. Accompanying these changes has been an alignment of corporate R&D with business goals. This has resulted in significant downsizing of corporate research laboratories and the devolving responsibility for R&D matters to operating sites or business units. The downside of this is that the operations are now more than ever focussing on productivity, industrial relations and other essential short-term profitability-motivated issues. Consequently, the changing environment is creating cultures that value and reward short-term results. This short-termism has important implications to industry and the research community.One of the more successful and cost-effective mechanisms by which Australia can enhance its R&D base and consequent prosperity is through collaborative R&D. The Australian Minerals Industries Research Association (AMIRA), together with its oil and gas Division APIRA, has demonstrated over the years how effective this can be. AMIRA's raison d'etre is to assist the resource industries improve their technology position through collaborative R&D. It achieves this by working closely with researchers and industry to identify areas of common interest, develop research proposals, and seek financial support for these proposals from industry. Once a project commences, the Association administers the financial and reporting aspects, as well as monitoring progress, organising progress review meetings and assisting in technology transfer. AMIRA/APIRA has the track record, the systems and expertise to facilitate and manage collaborative R&D focussing on industry needs.The evolution of the Australian collaborative R&D environment in the oil and gas and minerals sectors has been significantly different. The oil and gas industry, particularly in exploration, does not have a history of strong collaborative R&D in Australia. The reasons for this are varied and can be found in the different corporate cultures between mineral and oil and gas companies.
PIPELINES, POLITICS AND PROSPERITY: THE ROLE OF NATURAL GAS IN THE QUEST FOR SUSTAINABLE ENERGY
Authors: Grollman N.G.
Published: August 2017

As the preferred 'growth fuel' at the turn of the millennium, natural gas carries a great weight of expectations. Globally, it offers a partial solution to the problem of greenhouse gas emissions as a substitute for other fossil fuels, while at the same time reducing the security risks attached to dependence on oil by providing greater diversity of energy supply. Regionally, it is envisaged as the 'clean' fuel that will render Asia's burgeoning cities more livable. In Australia, it lies at the heart of a process of energy market liberalisation aimed at improved economic efficiency and expansion of Australia's energy-intensive export industries. This process, however, has yet to internalise the true value of gas in regard to environment and security. Moreover, whether the prosperity promised to the East Asia/Pacific region as a whole by new pipelines and LNG plants will be environmentally and logistically sustainable is a political question linked to events outside the region. As gas infrastructure becomes more regional in concept, and energy markets converge and become more competitive, there is a risk that the security and environmental problems associated with the 'age of oil', far from being ameliorated, will be perpetuated.
GREENSAND RESERVOIRS IN SILICICLASTIC SHORELINE SYSTEMS: FACIES MODELS FOR HYDROCARBON EXPLORATION
Authors: Dyson I.A.
Published: August 2017

Greensand reservoirs are particularly significant in siliciclastic shoreline systems. Formation of autochthonous glauconite is restricted almost exclusively to the rising limb of the relative sea level (RSL) curve. Depositional environments that are typically developed in response to a rise in RSL are estuaries, barrier bars and shoreface sands. In this setting, the greensands are diachronous and exploration for hydrocarbon reservoirs should ideally be based on a sequence stratigraphic framework. These deposits are characterised by a number of significant surfaces that differ greatly in their origin, geographic extent and chronostratigraphic significance, and their thickness depends on the rate of RSL rise and sediment supply. The identification of significant surfaces bounding or contained within depositional sequences is critical, especially where drillhole samples are either unreliable or not available for geochemical and palynological analysis. Abrupt physical and chemical changes often occur on or across these surfaces, e.g. porosity, permeability and the presence of Fe-rich authigenic minerals such as glauconite and siderite. Greensands deposited in estuarine, barrier bar and shoreforce environments have excellent oil and gas potentail. Early Cretaceous greensand reservoirs from the North West Shelf are best developed where they overlie ravinement surfaces. Recognition of greensands within estuarine, barrier bar and shoreface environments is dependent on the correct identification of facies and the subsequent interpretation of the bounding discontinuities.
THE TOTAL MANAGEMENT OF NORM IN THE OFFSHORE PETROLEUM INDUSTRY
Authors: Kvasnicka J.
Published: August 2017

Naturally Occurring Radioactive Materials (NORMs) in the offshore petroleum industry are generally associated with the formation of scale in pipes and vessels. As scale and sludge contain radioactive isotopes of radium they are in the category of Low Specific Activity (LSA) NORMs. Handling of NORMs creates issues involving occupational health and safety, environmental protection and radioactive waste management and waste disposal. Barium(Radium)Sulfate scale is highly insoluble and can create serious production problems by clogging pipes and valves.The paper discusses the external gamma radiation monitoring at the external surfaces of well and oil production pipes which assists in establishing the scale thickness patterns in pipes and in identifying the optimum location of a scale inhibitor injection point.To minimise radiation doses received by workers special NORM handling Work Procedures and Instructions supported by radiation protection training need to be developed. If facility personnel are trained in radiation protection and Work Procedures and Instructions are adopted it is possible to effectively manage personal radiation exposures below the public limit of 1 millisievert per year. Under such conditions no personal radiation monitoring during routine operations is required and the assessment of routine annual external radiation doses may be carried out through yearly external gamma radiation surveys of of fshore petroleum production facilities.The NORM waste cannot be disposed of onshore within the same disposal sites used for general non-radioactive waste. In Australia only the NORM waste generated in Western Australia can be disposed of onshore in an official low level radioactive waste disposal facility. It is important that Governments of other States and Territories address the onshore NORM waste disposal option. Regulations should also address a screening method for scrap metal contaminated by NORMs to be released for smelting.
THE RENEWED SEARCH FOR OIL AND GAS IN THE BASS BASIN: RESULTS OF YOLLA-2 AND WHITE IBIS-I
Authors: Lennon R.G. , Suttill R.J. , Guthrie D.A. , Waldron A.R.
Published: August 2017

Boral Energy Resources Ltd and its Joint Venture partners drilled two weUs in the offshore Bass Basin during 1998. Both wells targetted reservoirs in the Upper Cretaceous to Eocene Eastern View Coal Measures (EVCM).Yolla–2, located in Petroleum Licence T/RL1, appraised sandstones within the EVCM, first established gas bearing in the Yolla structure by the 1985 exploration well Yolla–1, drilled by Amoco. The exploration well White Ibis–1, located in adjacent permit T/18P, was a crestal test on a large basement high updip of the 1967 well Bass-3, drilled by Esso.Both wells of the 1998 drilling program encountered gas columns in the objective Paleocene to Lower Eocene section of the EVCM (Intra-EVCM). Liquids-rich gas was recovered from these reservoirs in wireline tests. Formation pressure data suggest a thin oil rim is developed in White Ibis–1. Neither well was tested in cased hole though White Ibis–1 was suspended for potential re-entry. Yolla–1 also encountered a gas and oil accumulation at the top of the Eastern View Coal Measures, but this level was not an objective in Yolla–2.Based on well results and 3D seismic control, a gas resource of between 450–600 BCF OGIP is currently estimated in the Yolla Field. The gas accumulation encountered in White Ibis–1 is estimated at 85 BCF OGIP.The 1998 drilling campaign has provided encour-agement to the T/RL1 and T/18P Joint Ventures to continue the search for both oil and gas in the Bass Basin. Markets for gas are being pursued in both Tasmania and Victoria and engineering studies are being undertaken in parallel to refine parameters for a potential Yolla Field development. The White Ibis Field may provide a candidate as a satellite to such a development. Depending on the outcomes of these studies, further drilling may occur in 1999 to increase confidence in the reserves base in the Yolla Field, and to further evaluate the exploration potential of T/18P.
PETROLEUM POTENTIAL OF THE NEOPROTEROZOIC WESTERN OFFICER BASIN, WESTERN AUSTRALIA, BASED ON A SOURCE ROCK MODEL FROM EMPRESS-IA
Authors: Carlsen G.M. , Apak S.N. , Grey K.A.R. Ghori K. , Stevens M.K.
Published: August 2017

The sedimentology, palaeontology and geochemistry of Neoproterozoic, organic-rich, clastic and related carbonate deposits in Western Australia provide new insights into the first-order depositional controls on hydrocarbon source rocks in the Neoproterozoic. Organic facies are correlated with depositional facies, revealing the impact of organic productivity and transport of organic rich sediments on the accumulation of organic matter in different depositional environments. Sedimentation is largely limited to ramp, platform, shoal, lagoon and sabkha environments.Growth of benthic organisms in the photic zone was the primary process controlling the production of organic matter in the ramp-shoreline system of the Kanpa Formation. Storms and floods were the primary mechanism for moving organic rich sediments into dysoxic and anoxic depositional environments. Variations in organic facies are indicated by: 1) changes in the palynomorph assemblages, particularly the increase in acritarchs within shallow-water ramp facies and cyanobacterial filaments in quiet-water sediments; 2) organic-rich laminae, containing abundant cyanobacterial filaments and mat material; and 3) the oxidation state of preserved organic remains.Periods of high organic growth rates or periods of mass mortality may have led to the development of an anoxic zone at the water-sediment interface. In the shoal and lagoonal settings, higher rates of clastic sediment dilution combined with oxygenated conditions resulted in lower TOC and hydrogen depleted organic facies.Condensed sections overlying stromatolitic dolomites represent the most effective organic facies of all of the potential source laminae sampled in Empress–IA. Most of the Officer Basin succession is currently within the oil-generating window and hydrocarbon shows encourage further exploration.
DEVELOPMENTS IN PORE PRESSURE PREDICTION USING SEISMIC-WHILE-DRILLING TECHNOLOGY
Authors: Evans B.J.
Published: August 2017

Exploration and development drilling encounters many technical challenges. Knowing the depth to overpressured zones is essential for choosing a safe mud weight that will keep formation pore fluids in place and prevent a blowout. The danger of encountering overpressure and variations in rock strength with depth can require well plans to include many casing string changes, and without some idea of true depth to target, it becomes hard to plan a well efficiently.The seismic-while-drilling (SWD) approach has offered an alternative seismic method to image geology ahead of the bit while drilling, so that overpressured zones would be detected aboard the rig. The technology involves recording the drill-bit noise using surface or seabed receivers, cross-correlating this with data recorded by an accelerometer mounted on the swivel, and producing interval velocities as well as a seismic section beneath and to the side of the bit.Success at producing seismic sections while drilling has been limited. The industry now offers the technique as a check shot replacement for time-to-depth conversion, which in itself is a highly valued tool for casing setting. However, a walk-away section while drilling is still desirable. In April 1998, the Gas Research Institute of Chicago announced the funding of a scoping study to determine the status of the SWD technology, and the areas of technology which could be developed by industry. This paper presents the status of the technology, and indicates the direction in which research is going to develop a pore pressure prediction methodology while drilling ahead.
ADVANCES IN WIRELINE DATA ACQUISITION IN SYNTHETIC-BASED MUD SYSTEMS AND STRATEGIES FOR IMPROVED FORMATION EVALUATION
Authors: Walker M.J.
Published: August 2017

With the growth in popularity of synthetic-based mud (SBM) systems in Australia, and the emergence of more advanced wireline logging tools, there is an expectation that better hole conditions will give rise to better value- for-money evaluation programs. This is certainly true from the drilling cost perspective, where a logging job can be completed without need for 'wiper' trips to recondition the hole. However, in order to extract maximum value from the latest generation of logging tools, careful attention needs to be applied to the formation evaluation program.There have been some unexpected results from the wireline data quality viewpoint, with some positive results mixed with outcomes that fell below expectation, both linked to the complex nature of the synthetic-based mud recipes. Contrary to intuition, good quality electrical images may be obtained in synthetic-based muds, and some mud additives used to stop filtrate loss can seriously degrade the quality of acoustic images that are traditionally run in SBMs. Nuclear Magnetic Resonance works well in SBMs, especially where invasion is kept to a minimum. Holes drilled with SBMs do not normally display borehole ellipticity, which may be used to infer tectonic stress directions. However, oriented cross dipole shear-weave logging is able to detect azimuthal anisotropy, which may be related to tectonic stress, in holes with a circular profile.There are trade-offs using different SBM recipes, which will impact on formation evaluation programs. Close consultation with the logging contractor and mud company, as far ahead of the drilling of the well as possible is recommended to ensure a satisfactory outcome.
AVOIDING STRATIGRAPHIC CONFUSION IN EXPLORATION: THE NEED FOR STANDARDS IN SEQUENCE STRATIGRAPHY
Authors: Brake A.T.
Published: August 2017

As interpretations of sequence stratigraphy are published in increasing numbers in the petroleum exploration literature, the potential for confusion also increases because there are no rules for the classification or naming of the identified sequences. At present it is difficult to apply databases and geographic information systems to sequence stratigraphy, particularly when organisations with different outlooks and approaches attempt to collaborate and merge their databases.Despite sequence stratigraphic concepts having been in the literature for over two decades, no scheme for standardisation has achieved consensus in the geoscientific community, either within Australia or internationally. Three areas in particular need to be agreed on: (1) how sequence units should be defined; (2) the hierarchy of those units, and on what basis; and (3) a standard scheme for naming units.The two basic ways of subdividing a succession into sequence units, the Vail–Exxon and Galloway methods, both rely on the enclosing boundaries being defined first. Various hierarchies of units have been proposed, in which there is often a clear desire to link the scale of sequence units to phases of geological evolution or stratal boundaries of different orders. In addition, most workers use informal names, but formal names are becoming more common. Consequently, it is essential that workable national guidelines be developed to ensure that communication and computer compatibility are not impeded.
WANDOO: THE DEVELOPMENT OF A MARGINAL FIELD
Authors: Fabian M.R.
Published: August 2017

The combination of characteristics of the Wandoo Oil Field is unusual and presented significant challenges for commercial development of this field. These characteristics are a shallow reservoir, high oil viscosity, thin oil column, unconsolidated sands and very high permeability.A staged development of this field was adopted to enable evaluation of these characteristics, commencing with a 120-day extended production test (EPT). The EPT was further extended to address aquifer support and horizontal well length issues and for commercial reasons. The information gained from the EPT was used to calibrate the full field simulation model, which was used to quantify the benefits of various development scenarios. To date, the reservoir performance has been in accordance with pre-full field development expectations.
WESTERN AUSTRALIAN GOVERNMENT DECISION-MAKING CRITERIA INVOLVED IN THE REGULATION OF DRILLING FLUIDS OFFSHORE
Authors: Cobby G.L. , Craddock R.J.
Published: August 2017

Traditional regulatory regimes have focussed upon the regulation of classes of drilling fluids based on their chemical category. The Western Australian Department of Minerals and Energy (WADME) has developed an alternative approach to the regulation of drilling fluids offshore.This alternate approach is based on an objective case- by-case assessment of each drilling proposal. The WADME assesses the likelihood and consequence (environmental risk) of potential environmental events associated with the total drilling proposal in determining the acceptability of that proposal.This approach uses a framework of assessment criteria to assist in decision making. These criteria include the environmental sensitivity of the well location; the oceanographic conditions and the potential for cuttings accumulation; the type and quantity of the proposed drilling fluid and cuttings; the method of cuttings disposal; the environmental performance of the drilling fluid under standard test protocols and the technical justification for the proposed use of the drilling fluids.This framework offers a more holistic assessment of the potential environmental impacts of a drilling proposal. This paper considers each criterion in this assessment and introduces cuttings pile removal as a topic for discussion.
PRACTICAL APPLICATION OF ENVIRONMENTAL RISK MANAGEMENT-GORGON LNG PROJECT CASE STUDY
Authors: Stoklosa R.T.
Published: August 2017

Stoklosa Engineering has been working with the petroleum industry to develop an environmental risk management methodology that can be generally applied to petroleum industry activities. In particular, the methodology is for assessing and managing ecological risk in sensitive marine environments.This paper introduces a management and technical methodology for the risk assessment process that has been applied to planning scenarios for the Gorgon LNG Project. The methodology has evolved from earlier efforts by petroleum operators and government in Western Australia to quantify ecological risk. The principles of Standards Australia risk management publications, State risk management initiatives and international approaches have been preserved in the methodology.The basis for a quantitative analysis of the likelihood of an incident is described, with a qualitative or semiquantitative analysis of the severity of the potential consequences. The technical approach adopts the principles of AS/NZS 4360 for risk management, and characterises risk for decision makers in an unambiguous manner. The methodology leads to a clear understanding of the benefits of risk management, and allows proponents the opportunity to reduce risk to acceptable levels. The risks of development should be interpreted in the context of naturally occurring hazards to environmental systems (e.g. cyclones and coral spawning slicks), human activities (e.g. recreation, fisheries and aquaculture), and the natural variability of ecosystems.The Gorgon LNG Project case study characterises risk in terms of credible incident scenarios and baseline operational activities from project planning scenarios. The inputs to the risk assessment are release scenarios, fate and transport modelling, response mechanisms in sensitive species, and recovery mechanisms following exposure. The methodology can be broadly applied to offshore and onshore development projects and environmental management programs, as it is presented as a repeatable process that can incorporate various types of risk analysis methods.
ENVIRONMENT UPDATE: 1998 REVIEW, 1999 OUTLOOK
Authors: Pendoley K.L.
Published: August 2017

The steady growth and evolution of environmental legislation over the past 10 years has resulted in 'environment' earning its own line in project critical path analysis and scheduling. Regulatory changes throughout 1998 and projected for 1999 ensure that environment will remain firmly entrenched on the collective corporate planning agendas of oil and gas exploration and production companies nationally. By the end of 1999 every state and territory is expected to have environmental protection legislation in place, while proposed legislative changes at the Commonwealth level indicates a possible increased involvement of Federal environmental agencies in industry activities in both state and Commonwealth jurisdictions. Industry is watching carefully the direction that will be taken by regulators in drafting current and future legislation. Industry and some government agencies favour an objective-based, self-regulating system over prescriptive regulations.
COMMONWEALTH PERSPECTIVE ON PETROLEUM TAXATION
Authors: Layer B.
Published: August 2017

In 1997 the petroleum industry sought modifications to the petroleum resource rent tax (PRRT) regime which applies to all Commonwealth offshore areas except the North West Shelf Project area. Industry argued that the PRRT impeded deepwater exploration and development activity and the exploitation of large stranded gas deposits suitable for conversion to liquids such as LNG. Industry suggested that a more appropriate risk/reward balance in the tax structure could be achieved by providing a volume based PRRT exemption for projects located in water depth greater than 400 m and by increasing the uplift rates for unrealised losses. It was proposed that the risk premium for the general (development) expenditure carry forward rate be increased by five percentage points to the long term bond rate (LTRR) plus 10 percentage points. Another industry recommendation was that exploration expenditures incurred more than five years before the issue of a production license (PL), which currently attract the lower GDP factor rate (the five year rule), be uplifted at the long-term bond rate for the period prior to the five year mark and then rolled forward at LTBR plus 15 percentage points. In addition, industry asked that the reference date for the five year rule should be based on the application date for a PL and not the issue date. For integrated gas to liquid projects, industry requested clarification of the basis for valuing feedstock gas for determining gas liability.In response, the Commonwealth decided to adopt a gas transfer price (GTP) methodology based on a combination of established cost plus and net back formulas to be applied to the up and downstream stages of the project respectively. The difference in the price outcome of the two methods, the residual price, is split 50:50 to obtain the GTP. Details of how the residual price method will be applied are currently being finalised with a view to enacting legislation in 1999-2000. The Commonwealth also responded positively to the industry suggestion that the reference date of the five year rule be applied from the date of application for the PL on the proviso that the appropriate authority receives all information pertaining to a successful application. Recommended changes to the PRRT for deepwater areas and proposed increases to the carry forward rates of undeducted losses were rejected mainly on economic efficiency grounds.
PETROLEUM SYSTEMS IN TASMANIA'S FRONTIER ONSHORE BASINS
Authors: Burrett M.R. Bendall C.F. , Askin H.J.
Published: August 2017

Sedimentary successions belonging to three petroleum su persy stems can be recognised in and below the Late Carboniferous to Late Triassic onshore Tasmania Basin. These are the Centralian, Larapintine and Gondwanan. The oldest (Centralian) is poorly known and contains possible mature source rocks in Upper Proterozoic dolomites. The Larapintine 2 system is represented by rocks of the Devonian fold and thrust belt beneath the Tasmania Basin. Potential source rocks are micrites and shales within the 1.8 km-thick tropical Ordovician Gordon Group carbonates. Conodont CAI plots show that the Gordon Group lies in the oil and gas windows over most of central Tasmania and probably under much of the Tasmania Basin. Potential reservoirs are the upper reefal parts of the Gordon Group, paleokarsted surfaces within the Gordon Group and the overlying sandstones of the Siluro-Devonian Tiger Range and Eldon Groups. Seal rocks include shales within the Siluro-Devonian and Upper Carboniferous-Permian tillites and shales.The Gondwanan supersystem is the most promising supersystem for petroleum exploration within the onshore Tasmania Basin. It is divided into two petroleum systems— the Early Permian Gondwanan 1 system, and the Late Permian to Triassic Gondwanan 2 system. Excellent source rocks occur in the marine Tasmanite Oil Shale and other sections within the Lower Permian Woody Island and Quamby Formations of the Gondwanan 1 system and within coals and freshwater oil shales of the Gondwanan 2 system. These sources are within the oil and gas windows across most of the basin and probably reached peak oil generation at about 100 Ma. An oil seep, sourced from a Tasmanites-rich, anoxic shale, is found within Jurassic dolerite 40 km WSW of Hobart. Potential Gondwanan 1 reservoirs are the glaciofluvial Faulkner Group sandstones and sandstones and limestones within the overlying parts of the glaciomarine Permian sequence. The Upper Permian Ferntree Mudstone Formation provides an effective regional seal. Potential Gondwanan 2 reservoirs are the sandstones of the Upper Permian to Norian Upper Parmeener Supergroup. Traps consisting of domes, anticlines and faults were formed probably during the Early Cretaceous. Preliminary interpretation of a short AGSO seismic profile in the Tasmania Basin shows that, contrary to earlier belief, structures can be mapped beneath extensive and thick (300 m) sills of Jurassic dolerite. In addition, the total section of Gondwana to Upper Proterozoic to Triassic sediments appears to be in excess of 8,500 m. These recent studies, analysis of the oil seep and drilling results show that the Tasmanian source rocks have generated both oil and gas. The Tasmania Basin is considered prospective for both petroleum and helium and is comparable in size and stratigraphy to other glaciomarine-terrestrial Gondwanan basins such as the South Oman and Cooper Basins.