bluuebunny/crossref_metadata_2025 huggingface dataset:
A REVIEW OF THE U.S. TIGHT GAS INDUSTRY FROM THE PERSPECTIVE OF SELECTED AUSTRALIAN AND NEW ZEALAND BASINS
Authors: Crosby D.G. , Tamhane D. , Yang Z. , Khurana A.K. , Kuuskraa V.A.
Published: August 2017

The recovery of natural gas from low permeability sandstones in the US has been made commercially possible due, to a large degree, to advanced technologies. The US currently produces 2 TCF annually from tight gas sandstone reservoirs. Large efforts have been directed towards identifying and developing the more productive basinal areas, or 'sweet spots9 of tight gas reservoirs. The identification of natural fractures prior to drilling, through the use of remote imagery in combination with established methods such as magnetic and gravity mapping, is currently being pioneered. Reduction in well-bore stimulation costs through development and application of advanced hydraulic fracture technology has improved the economics of tight gas production. The use of 3D fracture models in combination with realistic insitu stress profiles, appropriate proppants and effective quality controls have greatly increased well productivities through smaller, more efficient fracture treatments. Treatments have been successfully designed to avoid damage to natural fractures.Large tight gas sandstone resources similarly exist in the Cooper and Perth Basins of Australia and in the Taranaki Basin of New Zealand, although these resources remain largely untapped. To date, less than 50 BCF has been produced from Australian and New Zealand tight sandstones, largely from the Tirrawarra Sandstone and Patchawarra Formation of the Cooper Basin and the Ngatoro/McKee Formations of the Taranaki Basin. These formations compare well however, in terms of depositional environments with prolific US tight gas producing formations. They appear to be well placed to take advantage of the experiences and technologies gained by their US counterparts as well as through site specific adaptation of such technologies and the development of new technologies.
GETTING VALUE OUT OF NON-OPERATOR AUDITS
Authors: Ikin A.
Published: August 2017

The conduct of non-operator audits is a fundamental safeguard built into most joint venture agreements. The conduct of such audits should be regarded as a normal part of managing the relationship between the operator and the other parties to the joint venture, and should, where possible, be undertaken by the joint venture participants' own finance staff rather than abdicated to third parties.The audits should be expedited in a professional manner and cause the operator the least disruption.The purpose of audits should be to confirm trust in the operator. Accordingly, they should focus on the operator's systems and procedures for ensuring compliance with the JOA.
COMPETITION LAWS IN THE COOPER BASIN
Authors: Bednall T.
Published: August 2017

Competition laws in Australia are in the process of substantial reform. The major competition issues facing participants in the Cooper Basin: market definition, and competition between joint venturers are reviewed. The manner in which the Trade Practices Act has been applied to Cooper Basin producers is reviewed, proposed reforms to implement new national competition policy are outlined, and the likely impact which those reforms will have on the production and marketing of gas from the Cooper Basin are discussed.The likelihood, under reformed laws, of development of natural gas pipelines, open access, the difficulties of separate marketing of gas by joint venture parties, the potential for inter-basin competition in Australia, and the real issue of whether substantial benefits will flow to consumers of gas as a result of the application of new competition policies are evaluated.
INTEGRATED APPROACH LEADS TO SUCCESSFUL 3D SEISMIC ACQUISITION ON BARROW ISLAND
Authors: White M.R.
Published: August 2017

Barrow Island is a Class 'A' Nature Reserve off the northwest coast of Western Australia. West Australian Petroleum Pty Limited (WAPET) has conducted oil exploration and production activities on the island for the past 30 years. The Company recently completed an extensive 3D seismic pro­gram over the northern two thirds of the island. Two years of government liaison were required to ob­tain the necessary environmental approvals for the project to proceed. WAPET and its seismic contrac­tor utilised some of the latest Computer Aided Design (CAD) Geographic Information System (GIS) and Global Positioning System (GPS) technology to assist in planning the project and combined this with extensive on-the-ground work to ensure the highest level of environmental protection in a very important ecosystem. The project illustrated the benefits of early planning, ongoing communica­tion, use of new technology, a multi-disciplinary approach and continuous improvement in environ­mental management.
EXPLORATION IN SENSITIVE AREAS: CONVINCING THE COMMUNITY
Authors: Stejskal I.V.
Published: August 2017

Hadson Carnarvon Pty Ltd (Hadson), on behalf of the Joint Venture Partners, operates permits EP342 and TP/9 located at the northern end of Exmouth gulf, to the east of Cape Range peninsula, Western Australia. The Exmouth region is known for the Ningaloo Reef, and for its diving and recreational fishing. The area also supports a large commercial prawn fishery. Many marine areas in the Exmouth region are regarded as being environmentally sensitive with several areas of conservation value.The partners were committed to drilling two wells in EP342 and TP/9 in 1993 as part of the obligations under the permits. Public mistrust of, and an unfamiliarity with, the oil and gas industry gave the Exmouth community the perception that the EP342 drilling program would have a detrimental impact on the sensitive marine resources of the region and, hence, to the growing tourism industry in the region.Hadson developed a management strategy which involved an extensive local community education and consultation program. Activities for this program included presentations to various community and special interest groups and a two-day public exhibition in Exmouth. The management strategy also included commitment to statutory and voluntary environmental guidelines, and an impact assessment study.Hadson's communication program was successful on a local level: by the time drilling commenced, active opposition to the drilling program had diminished significantly. This drilling program showed the importance of involving the public in the plans of the company, of putting a 'face' to the company and of communicating environmental risk in a trustworthy manner.The State Government announced in July 1994 that petroleum exploration within Ningaloo Marine Park would not be permitted. This decision was not based on scientific evidence, but political strategy and a perception that in the Exmouth and wider community there was an innate 'fear' regarding the impact of the petroleum industry.
LAM IN ARIA—A NEW TIMOR SEA DISCOVERY
Authors: Smith G.C , Tilbury L. A , Chatfield A. , Senycia P. , Thompson. N.
Published: August 2017

The Laminaria-1 discovery in the southeast of AC/P8 is a major new Timor Sea oil accumulation. The discovery well, drilled in October 1994, encountered a gross oil column of 102 m in deltaic to jiearshore marine sediments of the Callovian-Oxfordian Laminaria Formation. On production test, a maximum flow rate of 7,507 BOPD was recorded through a 5/8 in. choke. The oil is a light (59° API), undersaturated oil with a GOR of 175 SCF/STB. Laminaria-1 was the first well drilled by the AC/P8 Joint Venture since resumption of exploration following resolution of the international boundary between Australia and Indonesia.The Laminaria Prospect, originally identified prior to the boundary dispute, was detailed by seismic surveys in 1992 and 1993. The prospect was selected as the best of several structural targets, comprising a large complex horst block produced by major east-west faults, discernible on the 2D seismic lines at Aptian (KA) level. The prospect was expected to have Upper to Middle Jurassic Flamingo and Plover sandstone reservoirs, sealed by the Flamingo Group Shales,with hydrocarbons sourced from the same shales in adjacent synclines.Since the discovery, a comprehensive appraisal campaign has been undertaken to delineate the accumulation, including the acquisition of a large 3D seismic survey over almost the entire AC/P8 permit, and the drilling of a further two wells and a sidetrack. The Laminaria horst is now interpreted to comprise a series of tilted fault-blocks, orientated ENE to WSW and dipping to the southeast.
THE COOPERATIVE DEVELOPMENT OF THE GOBE OIL FIELDS
Authors: Magner T.N.
Published: August 2017

The proposed Gobe Petroleum Development Project includes the development of two separate oil fields, SE Gobe and Gobe Main. The fields are located, respectively, in the northwestern area of Petroleum Prospecting License (PPL) 56 and the southeastern area of PPL 161 in the Gulf and Southern Highlands provinces of Papua New Guinea, approximately 500 km northwest of Port Moresby, 80 km northwest of the town of Kikori and 85 km southeast of the Kutubu oil fields.The Gobe anticline, on which the discovery wells were drilled, is a large east-southeast trending ridge situated at the leading edge of the Papuan Fold Belt. The surface of the anticline was formed by folded limestone which has weathered to produce a rugged terrain characterised by intense pinnacle karst topography. Dense rainforest covers all of the project area. The crest of the anticline is in excess of 1,300 m above sea level, with the hydrocarbons occurring between approximately 900 m and 1,200 m below sea level.The Gobe Main Field is located entirely within PPL 161 which is operated by Chevron Niugini Pty. Ltd. The SE Gobe Field is located within both PPL 56 and PPL 161. The PPL 56 license is operated by Barracuda Pty Limited. Both of the fields are situated approximately 15 km from the existing Kutubu oil export pipeline. Development planning for the two fields is now at a mature phase and the two license groups are preparing to submit Petroleum Development License Applications (PDLA) to the PNG Government. Initial production is targeted for December of 1997 and the fields are forecast to produce at a combined peak rate of approximately 50,000 BOPD.The potential economic return to participants and the state will be optimised by developing these fields in a cooperative manner with shared production facilities. Similarly, utilisation of the nearby Kutubu oil export pipeline will yield benefits to both the field developers and pipeline owners. The Gobe development serves as an example of how the economics of two 'marginal' field developments can be enhanced by employing existing infrastructure and sharing of facilities. This paper will provide an overview of this cooperative approach to development.
MESOZOIC AND CAINOZOIC TECTONOSTRATIGRAPHY OF WESTERN ZOCA AND ADJACENT AREAS
Authors: Whittam D. B. , Norvick M. S. , Mclntyre C. L.
Published: August 2017

Increased exploration activity in Area A of the Timor Gap Zone of Cooperation between Australia and Indonesia (ZOCA) has created the need for revision of the existing stratigraphic framework of the region. A chronostratigraphic approach to the analysis of the Mesozoic and Cainozoic succession of Western ZOCA provides a framework for improved stratigraphic prediction. The framework is based on the identification of depositional sequences by the integration of seismic and well data. Genetically related depositional sequences have been grouped into seven 'megasequences' which reflect distinct stages in the tectonic development of the basin.The Mesozoic and Cainozoic succession in the Northern Bonaparte Basin was deposited in a marginal sag basin that was affected by Triassic to Lower Cretaceous extension related to continental separation along the northwest margin of Australia. Four stages are seen in the evolution of the basin since the end of the Permian. Relative tectonic quiescence during the Triassic preceded two cycles of extension related to continental separation during the Jurassic to Earliest Cretaceous. Continental separation was followed by the development of a Cretaceous/Tertiary passive margin and a subsequent phase of tectonism related to the Miocene/Pliocene collision of the Indo-Australian and Eurasian plates. A tentative correlation has been made between the megasequence framework of Western ZOCA and the geological succession exposed on Timor Island.The framework forms the basis for a system of common stratigraphic nomenclature for the Timor Gap. The model also assists in understanding the tectono-strati-graphic evolution of the basin and is a foundation for the development of new play concepts that will support continuing exploration activity in the area.
ECONOMIC ADVANTAGES OF USING EXPLORATION 3D SEISMIC ON THE NORTH WEST SHELF
Authors: Larsen O.A. , Winterhalder J. , Boardman J.S. , Smith J.N.G.
Published: August 2017

The development of high capacity seismic 3D vessels has been so rapid that the oil industry has yet to optimise its investment in seismic data. However, the oil companies are becoming increasingly aware of the financial benefits of multi-client surveys which maximise vessel efficiency and provide a comprehensive evaluation of large areas.Many oil companies continue to design exploration seismic programs based on 2D seismic and acquire 3D seismic surveys after drilling the exploration/discovery well and generally after at least one appraisal well. Such single client surveys are limited by expected field outlines, which results in high unit costs for the seismic and missed opportunities beyond these outlines.The immediate benefits identified from obtaining early 3D data include: a higher success rate, optimisation of well locations, more rapid and cost effective appraisal, earlier screening studies, and an advanced development program. The combination of these factors can accelerate production by up to 18 months.For the scenarios evaluated in this paper, the use of 3D seismic early in the exploration period translates into an increase in Net Present Value of A$18-33 million and Expected Monetary Value of A$50-58 million for a 50 MMBBL oil field.
LATE TERTIARY FLUID MIGRATION IN THE TIMOR SEA: A KEY CONTROL ON THERMAL AND DIAGENETIC HISTORIES?
Authors: O'Brien G.W. , Lisk M. , Duddy I. , Eadington P.J. , Cadman S. , Fellows M.
Published: August 2017

An integrated study of the fluid flow, hydrocarbon charge and thermal histories of a suite of traps from the Timor Sea has revealed the presence of a key fluid flow event in the latest Miocene/Early Pliocene. This event, which coincided with, and was driven by, the extensive tectonism and fault reactivation associated with the collision of the Australian and Eurasian plates, involved the flowage of hot (90-120°C), saline (>200,000 ppm) brines (probably from deeply buried Palaeozoic evaporite sequences) up major faults and through the Mesozoic and Tertiary sequences. The passage of these hot brines produced a Late Tertiary (100,000 to 1 million years). In contrast, strongly reactivated, low integrity traps such as East Swan appear to have been breached too quickly (
AUSTRALIAN PETROLEUM RESEARCH AND DEVELOPMENT: AN EXAMPLE OF PROBLEM-DRIVEN GEOSCIENCE RESEARCH MANAGEMENT
Authors: Loutit T.S.
Published: August 2017

The Australian petroleum exploration research program is customer-driven and reflects the balance between the need for the petroleum industry to reduce exploration risk in the short term and the government need to improve the perception of prospectivity in the longer term. Higher prospectivity will lead to greater exploration investment and competition, whereas risk-reduction will increase the efficiency and effectiveness of the exploration industry. Thus the objectives of the primary customers may be significantly different, with government intent on increasing the amount of investment and competition between explorers, whereas industry is intent on keeping expenditure to a minimum and maintaining competitive advantage. Despite the differences, collaboration between all groups involved in exploration and exploration-related research in Australia is essential to solve the range of exploration problems and generate new paradigms. Collaborative research ventures are most successful when new ideas stimulate explorer and researcher alike to focus resources on the key questions despite factors such as competitive advantage. Government geoscience researchers must play a significant role in generating and marketing new concepts to help maintain Australia's supply of domestic petroleum products.The scale of the petroleum research undertaken, and the degree of collaboration between industry and research groups in Australia, is remarkable. There is a productive balance between groups developing and applying new technology and those undertaking regional geological and petroleum systems research. This balance has been reached because of the long-term commitment by the Australian Government, via legislation and funding, to ensure the preservation of exploration data in national geoscience database systems, and that basic and applied research at all scales, from basins to wells, is undertaken in support of petroleum exploration and development.Despite the success of a number of collaborative research projects, research and development resources are still under-utilised by the Australian petroleum industry. Government research agencies must develop a higher marketing profile to ensure that the utilisation of the resources is at a maximum.
SUMHOLE DRILLING: WELLBORE STABILITY CONSIDERATIONS BASED UPON FIELD AND LABORATORY DATA
Authors: Addis M.A. , Jeffrey R.G.
Published: August 2017

Slimhole drilling is becoming an attractive option as it provides significant cost savings in the petroleum industry. Furthermore, many of the technical obstacles in adapting slimhole drilling for the petroleum industry have been addressed, such as rig modifications, small volume kick detection, drilling fluid design, etc. However, wellbore stability in slimholes is largely taken for granted, when it could potentially increase costs dramatically. In this paper, a review of the available information on the effects of hole size on hole stability is presented. Wellbore stability in holes of different diameters is discussed qualitatively based on published laboratory data and unpublished field data. The quantitative assessment of wellbore instability in slimholes is addressed using observations of instability in a well in which the far field stresses were measured.The field data presented here suggest that slimhole wells are not more stable than conventional wells. The slimhole drilled in NSW shows that even using the most conservative prediction model, wellbore instability would not be predicted—instability was however, observed.
RETROGRADE CONDENSATION OR WATER IMBIBITION ? A CASE STUDY OF GAS WELL PRODUCTIVITY DECLINE BEFORE AND AFTER HYDRAULIC FRACTURING
Authors: Yang Z. , Tamhane D. , Khurana A.K. , Crosby D.G. , Jones M.
Published: August 2017

Studies have been carried out to diagnose the cause of productivity decline for the Kaimiro-1 well in the Kaimiro gas field, Taranaki Basin, New Zealand. The gas flow rate for Kaimiro-1, declined from 5 MMSCFD (0.14 Mm3 per day) in 1983 to about 0.6 MMSCFD (0.017 Mm3 per day) in 1993, immediately prior to hydraulic fracturing. While hydraulic fracturing initially increased production rates, long term post-fracture results have been disappointing. The volumetric gas-in-place for the field was estimated to be at least 100 BCF (2.83 Gm3), whereas the total cumulative gas recovery to date is 5.1 BCF (0.14 Gm3). During the production period prior to hydraulic fracturing, reservoir pressure declined from an initial 6,109 psi to 5,625 psi (42.1 MPa to 38.8 MPa). The well has produced water at low rates over its entire production history. Analysis of pressure build-up data showed a continued decline trend in effective reservoir permea­bility with time. Thus, it appeal s that the productivity decline is due to a decrease in effective permeability to gas and not to natural depletion. However, the exact origin of this decrease in effective permeability has been the subject of much controversy. Two competing theories regarding the decrease in permeabiiity have been proposed: retrograde condensation and water imbibition. Based on black oil and compositional simulation studies of pre-and post-fracture production, together with hindsight analysis of hydraulic fracturing, it is concluded that retrograde condensation is more likely to be the primary cause of productivity decline.
TITLE TO PETROLEUM TENEMENTS
Authors: Radford G.
Published: August 2017

Commercial people often draw an analogy between the Torrens system and the system of registration of petroleum tenements to reach the conclusion that title to petroleum tenements is indefeasible or secure. The analogy is a false analogy.This paper examines some of the fundamental principles relevant to title to petroleum tenements to demonstrate why titles are not as secure as is sometimes supposed. The paper also highlights some of the key points resources lawyers need to remember when they consider title.In its conclusion, the paper outlines the reasons why Torrens system legislation is inappropriate for petroleum tenements. It also suggests some simple reforms the State Governments might introduce to improve security of title.
FACILITATING ENVIRONMENTAL APPROVALS PROCESS—EAST SPAR
Authors: Goff H. B.
Published: August 2017

A commitment was made in December 1994 to develop the East Spar gas and condensate field, located in Commonwealth waters approximately 40 km NW of Barrow Island. A number of development options were available and the preparation for the environmental approvals process was initiated in mid-1994. Environmental approval for the East Spar project required satisfying State and Federal Government requirements. In the midst of the approvals process, Justice Sackville of the Federal Court handed down his decision in the Gunn's Woodchip case, significantly altering the way in which the Commonwealth Environ-ment Protection (Impact of Proposals) Act (EP(IP)Act) would be interpreted.In the face of considerable uncertainty about how the federal approvals process would then operate, WMC Petroleum as the operator of the development actively promoted dialogue with and solicited input from, community groups and environmental agencies. This approach involved an intensive but relatively informal consultation process at the company's initiative, well in advance of any statutory requirements. When the project was formally assessed by the Commonwealth regulatory agencies, environmental approval was expedited through the informal consultation process. This pro-active approach offers a useful and efficient model for seeking and gaining environmental clearances.
GEOTECHNICAL PROCESSES AND MANAGEMENT STRATEGIES FOR MATURE BASINS: A CASE STUDY OF THE GIPPSLAND BASIN
Authors: Djakic A.W.
Published: August 2017

During the 1990s, exploitation and exploration processes in the Gippsland Basin have been expanded to cater to a surge in mature field redevelopment activity, and have supported continued activity in the more traditional functions of exploration and development of new resources.The first major field redevelopment project was initiated in 1991 on the West Kingfish Field. Since 1991, similar programs conducted on the Mackerel, Perch, Fortescue and Kingfish Fields have significantly mitigated oil production decline in the basin. The success of the field redevelopment programs has been attributed to the use of multi-disciplinary field teams, the use of high end geophysical interpretation technologies, and the ability of the field teams to integrate and synthesise often voluminous quantities of production and geotechnical information to identify drilling opportunities.Areas where we continue to improve field redevelopment geotechnical processes include decreasing data acquisition and analysis cycle time, and advancing the precision of geotechnical predictions.With over 30 years of intensive exploration activity in the Gippsland Basin placing it in a mature phase of development, focus on the risk management of exploration activities has increased. Focussed research efforts to both develop new geotechnical technologies and more accurately assess the limitations of currently utilised technologies have also been undertaken to ensure an economically viable exploitation and exploration strategy for the basin.The structure of geotechnical teams in the 1990s has seen production and exploration functions amalgamate to ensure that the benefits of operations synergies provided by the high level of platform drilling activity are fully realised. This is enabling the knowledge from intensive field drilling programs to be more readily applied to the evaluation of exploration opportunities. Field re-development drilling activities are at historically high levels and are predicted to remain so into the foreseeable future. Given the mature nature of exploration in the basin, future exploration activities will be undertaken within the defined limits of our technologies to ensure the opportunity to achieve continued economic success is maximised.
CRISIS MANAGEMENT
Authors: Sandman M.
Published: August 2017

In essence, a crisis is a Public Affairs event and it is important to distinguish between a crisis on the one hand and an emergency on the other. An emergency may not necessarily become a crisis because the focus of an emergency is internal whereas the focus of a crisis is external.At West Australian Petroleum Pty Limited (WAPET) we have a crisis management plan which has been developed to facilitate the rapid notification and response to emergency incidents involving WAPET personnel and facilities.The plan requires the organisation of an Emergency Management Team to deal with the immediate impacts of the emergency, initiate a response and address the problem as quickly as possible.In addition, a separate Crisis Management Team is mobilised to address the external crisis situation by identifying the impact of the problem on the business, initiate a media response, liaise with outside agencies and support the Emergency Management Team.The overall goal of the emergency management system is to move from a reactive to a proactive mode of operation as quickly as possible.Different levels of emergency have been identified and procedures initiated to respond by individuals at different levels within the organisation.The process is tested periodically through the use of practice drills, the objective being to ensure that if a crisis occurs, the Company has in place procedures to respond at all levels to minimise impact upon the operations of the Company both short-term and long-term and to react to media interest in any crisis event.
EASTERN GAS PIPELINE PROJECT: BREAKING NEW GROUND IN COORDINATED APPROVALS
Authors: Cutler J. , Farrar P.
Published: August 2017

The opening of 'free and fair trade' in natural gas from 1 July 1996 provides the opportunity to service Sydney and regional NSW energy markets with competitively priced Bass Strait gas.The Eastern Gas Pipeline Project (EGPP), proposed by BHP Petroleum Pty Ltd and a Canadian company, Westcoast Energy Inc, will link Victorian reserves to NSW transmission and distribution systems.The proponents have taken on a major coordination exercise to ensure that project planning, market development, communications, environmental assessment and regulatory approvals are integrated and managed against a demanding project schedule.Exposure to three regulatory jurisdictions has complicated this task.The project requires many approvals including approval under the Commonwealth government's foreign investment policy, pipeline permits and licences under Victorian and NSW Pipelines Acts and requires environmental impact assessment under Commonwealth, Victorian and NSW legislation.Early in the project's life the proponents recognised the need for a strongly coordinated approvals process and have since worked with government assessment and facilitation agencies to achieve a coordinated process. This ground-breaking project is now the subject of one Environmental Impact Assessment process, one process for public review and one coordinated decision-making process to meet the requirements of all three jurisdictions.This paper explores the challenges of coordination and suggests ways of improving future joint assessment and approval processes.
THE APPLICATION OF 3D SEISMIC INTERPRETATION TECHNIQUES FOR OPTIMISING WELL PLACEMENT: FORTESCUE FIELD RE DEVELOPMENT, GIPPSLAND BASIN
Authors: Ryan P.J. , Vinson T.E.
Published: August 2017

In order to achieve successful drilling results on mature fields, geophysical analysis has become increasingly focussed on the application of high precision 3D seismic interpretation and analysis techniques. These techniques were critical to the success of the re-development program recently completed on the Fortescue Field* Gippsland Basin. Fortescue, initially developed in 1983, contains an estimated oil reserve of 300 million barrels. The field is currently over 80 percent depleted. To offset declining production and develop remaining reserves, an 18 well additional drilling program together with upgrades to platform topsides and production facilities was conducted on the field from October 1994 to October 1996.Many of the proposed additional drilling opportunities relied on oil being trapped structurally updip from existing completions. Given the size (approx. 1 MSTB) and subtle, low relief nature of the targets being pursued, the precision of conventional 3D seismic interpretation techniques was inadequate to optimise the location of wells. This necessitated the development of a series of specific tools that could provide high resolution definition of both the trap and lithology as well as optimising well placement.These high precision interpretation techniques include: reservoir subcrop edge prediction through qualitative calibration of geological models to seismic data: the assessment of overburden velocity distortions of the seismic time field by utilising isochron mapping and interval attribute analysis; and prediction of trap geometries and lateral stratigraphic variations by the application of seismic waveform attributes.The application of these advanced 3D seismic interpretation techniques and their integration with related geoscience and engineering technologies resulted in the completion of a successful 18 well re-development program for the Fortescue field.
INTEGRATING SEISMIC, GRAVITY AND AEROMAGNETIC DATA IN THE STRUCTURAL INTERPRETATION OF THE MERLINLEIGH SUB-BASIN, WESTERN AUSTRALIA
Authors: Mory A. J. , lasky R. P.
Published: August 2017

The southern Merlinleigh Sub-basin is a frontier area for petroleum exploration within the onshore Southern Carnarvon Basin, with limited seismic coverage and only two deep exploration wells. High resolution aeromag- netic and semi-detailed gravity data acquired in 1995 provide relatively low cost structural inf ormation"comple- mentary to the regional seismic coverage.Two-dimensional seismic data can be mapped with confidence if the lines are closely spaced. By identifying lineaments on potential-field images, orientations for structures within the sedimentary succession, and at basement or intra-basement levels, can assist in the interpretation of faults and structures in areas of limited seismic coverage, and to extrapolate them outside areas of seismic control. Consequently, by integrating seismic and potential-field data, a more rigorous interpretation of the structural geometry can be achieved and thereby assists in reconstructing the evolution of a sedimentary basin.The aeromagnetic data provided only limited information about the structure of the Merlinleigh Sub-basin because magnetic anomalies appear to be dominated either by near-surface or deep intra-basement sources. In contrast, the gravity data provide a more reliable definition of the structure at basement level and, to a lesser extent, within the sedimentary sequence.Seismic, gravity and magnetic data show that the region is a large north-trending Late Carboniferous to Permian depocentre and can be sub-divided into two main troughs east of the Wandagee and Kennedy Range Faults. These are en-echelon fault systems with syn- depositional growth during the main period of rifting in the Late Carboniferous to Early Permian.
NEW APPROACHES TO DETECTION AND CORRECTION OF SUPPRESSED VITRINITE REFLECTANCE
Authors: Newman J.
Published: August 2017

Vitrinite reflectance is commonly used as an indicator of thermal history and the likely maturity of source rocks. However, comparison of reflectance with other thermal indicators, and assessment of downhole gradients, indicate that vitrinites sometimes have anomalously low reflectance. This phenomenon is referred to as suppression, and can affect vitrinite in both marine and terrestrial sedimentary rocks, and in coal seams. For coals it is possible to diagnose and correct reflectance suppression using bulk chemistry; however, dispersed organic matter in sedimentary rocks requires a petro- logical approach. Therefore, a new technique has been developed combining reflectance with quantitative vitrinite fluorescence (VRF). A VRF plot allows objective differentiation of sedimentary Type III and IV organic matter into suppressed vitrinite, normal vitrinite, recycled vitrinite, and inertinite, based on graphical relationships. This takes the guesswork out of vitrinite identification and overcomes the problem of suppression. Measurements are made in a nitrogen atmosphere to avoid fluorescence alteration. Examples of VRF plots show that fresh samples are not essential for vitrinite fluorescence, as previously assumed.
NATIVE TITLE AND THE PETROLEUM INDUSTRY IN WESTERN AUSTRALIA
Authors: Clarke J.D.
Published: August 2017

This paper explains the claimant and the future act processes of the Commonwealth Native Title Act and their operation in Western Australia, particularly in relation to petroleum titles. It then outlines the WA Government's response and future directives, focussing on the amendments needed to produce workable native title legislation.
DIRECTORS' ENVIRONMENTAL RISK—HOW TO CONTROL?
Authors: Epper M.S.
Published: August 2017

To date the petroleum industry in Australia has an excellent report card in relation to its environmental responsibilities and it is obviously in the interests of the individuals and companies involved in the industry, and the community at large, to maintain the high standards. The high standards of the petroleum companies no doubt reflect the good environmental practices undertaken in the industry to control environmental risk. What are the high standards that companies employ? Up until now the users of financial statement and community have been kept in the dark because this type of information has not been disclosed.The answer to satisfy the users of financial statements is greater disclosure of the high standards but obviously petroleum companies will also need to continue to employ standards and tailor them to the changing risk profile of the industry.This paper will examine directors' exposure to environmental risk and how environmental risks are accounted for and disclosed.
RENEWAL AND RECONSTRUCTION IN WORLDWIDE ENERGY INSURANCE MARKETS—TOWARDS A MORE COMPETITIVE 2000
Authors: Grierson W.N. , Curtin I. P.
Published: August 2017

Whilst the over-riding aim of insurance for oil and gas explorers/producers is to provide financial stability to their operations, the recent fortunes of the market, and consequently the availability and pricing of the protection it provides have been more volatile than any objective assessment would allow.Following record underwriting losses in the late 1980s and early 1990s, which quite literally bankrupted a large number of names and underwriters at Lloyds as well as several of the smaller speciality energy insurance companies, the market has been undergoing a period of significant change. This paper provides a 'snap shot5 of the current position, including reference to major influential factors such as:the changing structure of the market and the emergence and effect of new underwriting capital;the progress of the 'renewal and reconstruction' program at Lloyds-still the undoubted international leader in energy insurance;the increase in capacity of oil industry mutuals and other alternatives to the traditional insurance market;the effects of new technologies on pure risk;the safety imperative worldwide; andglobal loss trends and possible effects of escalating weather-related catastrophes.The paper reaches the conclusion that whilst nothing in the oil industry is certain, the combination of factors currently in play should provide a more competitive and stable energy insurance market for Australian explorers/producers into the year 2000.
CASE STUDY OF ABORIGINAL INVOLVEMENT AND ISSUES—SOUTH WEST QUEENSLAND PIPELINE
Authors: Winters T.A.
Published: August 2017

The South West Queensland Pipeline project has set a new benchmark for Aboriginal involvement in corridor project planning and construction in Australia.Before the final pipeline alignment was decided, Tenneco Energy Australia (now Epic Energy), the Queensland Government and the Goolburri Aboriginal Corporation Land Council arranged for Aboriginal Researchers to conduct a foot survey along a 200 in wide corridor for the full 756 km of the pipeline route. The final alignment was selected to avoid all cultural heritage sites identified by the Aboriginal Researchers.At the commencement of the construction phase, a Cultural Heritage Management Plan (CHMP) covering construction activities was developed. Key components were as follows:Goolburri Aboriginal Corporation Land Council engaged as a service provider to provide Aboriginal Researchers, a Cultural Heritage Management Officer (CHMO), and an auditor for the project;Four Aboriginal monitors to be present on the project during clear, grade and trenching activities;An archaeologist to be present on the project to coordinate Aboriginal monitoring and cultural heritage management activities;A cultural heritage management audit to be conducted at the end of each four-week work cycle to identify non-conformances with the CHMP and recommend improvements;Cultural awareness training to be undertaken by the workforce and presented by Aboriginal representatives; andInstant dismissal provisions for serious infringements of the CHMP.The cultural heritage clearance process and the CHMP were probably the most extensive ever implemented for a pipeline project in Australia in terms of the extent and nature of Aboriginal involvement. Despite this, there was ongoing concern about whether the appropriate Aboriginal groups were being involved in the project. Cultural heritage management of the project became linked to the question of traditional association with the land and native title rights. Disparate views about the rights of different Aboriginal groups continually emerged.Of particular note was a tribal boundary dispute which resulted in prematurely closing down the first cycle of construction and leapfrogging the 108 km stretch under dispute to provide Aboriginal groups with time to resolve the issue. This action directly resulted in additional project costs (construction rescheduling and backtracking crews) in the order of $5 million.This case study will look particularly at:the process of cultural clearance and cultural heritage management which evolved for the project;issues associated with establishing appropriate Aboriginal representation for involvement in the project;native title claims; andsuggestions for improving management of native title, cultural heritage and Aboriginal involvement issues for future projects.
STATISTICAL COMPARISON OF OIL AND GAS WITH OTHER INDUSTRIES
Authors: Mackay A. , Freeman M.P. , Nitschke T.A.L. , Tuck M. J. , Middleton A. R.
Published: August 2017

The Australian Bureau of Statistics collects and publishes a range of data which allows comparisons to be made between industries and over time. The annual Economic Activity and Manufacturing Surveys and Mining Census provide the data from which these comparisons are drawn.This paper compares the oil and gas extraction industry with the electricity, mining and manufacturing industries, and other major industry groups in the Australian economy in the last five years in terms ofproduction;income;expenses;profitability; andemployment.The paper also presents a brief overview of the results of recent ABS surveys covering the use of technology in the Mining and Manufacturing industries.Looking to future industry activity, the paper presents summary data on:petroleum exploration expenditure; andcapital expenditure, including expected expenditure.
THIRTY YEARS IN AN OIL CITY
Authors: Warr B.G.
Published: August 2017

The oil industry often provides economic stability for those areas in which it sets up production and processing facilities. In Victoria the City of Sale has benefitted from the activities of the Esso/BHP facilities at Longford. While until recently the direct effect of Sale's municipal finances was relatively small, the facility and Esso/BHP activities at Longford and Sale (and offshore in the Bass Strait) resulted in direct benefits to business houses and other commercial activites in the City of Sale. These benefits arose not only from the joint venture itself but from the domestic requirements of its employees.The Esso/BHP involvement matured at a relatively early stage and there has been a plateau in the growth resulting from exploration and production activities. However, the economic contribution-at a number of levels-played an important part in underpinning the stability of the city following the withdrawl of the Esso/BHP offices and the closure of the National Safety Council.
DEVELOPING YOUR SECOND SYSTEM: THE CHALLENGE OF INTEGRATION
Authors: Fletcher D.L.
Published: August 2017

Developing and implementing your first management system (i.e. formalised), be it focussed on safety, quality or environmental issues is a major task. In contrast much of the ground work may already be established when introducing a second system. However this in itself can create some unique challenges.This paper examines how those challenges were addressed during development of West Australian Petroleum's Environmental Management System (EMS), and highlights some of the issues associated with integrating management processes.Development followed a staged approach, initially focussing on assessment of existing processes and their potential for use in environmental management. Surveys of internal and external customers were conducted, along with external benchmarking to identify potential issues and alternatives.The strategy that emerged was to align with existing safety processes, such as planning, communication, hazard management and audit wherever possible. The underlying issue was whether to apply the processes in parallel or concurrently. Existing documentation was also reviewed to determine howr to effectively document the EMS while avoiding unnecessary duplication.A decision was taken to pilot the EMS at one site prior to company-wide deployment. Senior management support for the decision was linked to the detailed assessment of risks, resource requirements, and likely impacts on other business initiatives.Development is now underway with a number of conclusions or key learnings already apparent. These include an acceptance that if integration is to be successful any underlying differences between the management of environmental and safety issues need to be understood, and safeguards need to be put in place to ensure both receive adequate attention.
BAYU NUCLEAR MAGNETIC RESONANCE STUDY: COMMERCIAL APPLICATION OF APPLIED RESEARCH AND FIELD TECHNIQUES IN A GAS-CONDENSATE FIELD
Authors: Howard j.j. , Williams J.S. , Thorpe D.G.
Published: August 2017

Nuclear Magnetic Resonance (NMR) technology was applied to assist reservoir characterisation of the gas-bearing sandstones in the Bayu-Undan Field, Zone of Cooperation, Area A Blocks 91–12 and 91–13. NMR logs were run in several wells and laboratory NMR measurements on water-saturated core plugs were used to determine the sandstone pore structure and characterise effective porosity and permeability in the gas-bearing sands.These sandstones exhibit a range of pore size behaviour, ranging from those sandstones with no clay-bound water to those with a significant proportion of their porosity associated with micropores. Mean relaxation times tend to be slower than expected for the observed pore sizes in these sands by comparison with global analogs. Surface relaxivity is lower than the world-wide average for sandstones, and reflects a network of unusually clean pore- walls.Comparison between core permeability values and the log-estimated permeabilities over a four-order of magnitude range produces a correlation coefficient of greater than 0.7 in a single well.Integration of field- and laboratory-based NMR data proved that permeability and pore-size distribution models could be integrated with conventional core analysis results. These datasets are continuous over the reservoir interval and once calibrated are easily integrated into reservoir simulation models.
THE REMOTE DETECTION OF NATURAL FRACTURES FOR COAL SEAM METHANE
Authors: Evans B.J. , Urosevic M. , Poole G.
Published: August 2017

Coal seam methane (CSM) is an area of increasing significance to the eastern states of Australia, because by the year 2005, the gas supply from existing fields will be diminishing rapidly. CSM has the economic advantage of being present in seams at easily drillable depths of 300–600 m, and is clean so requires little filtering before use. Since well developed cleat systems are not generally found in Australia due to the presence of high lateral stresses, CSM production is dependent upon permeability, which is reliant on the presence of natural fracture systems.Work overseas has been progressing on the ability to sense the direction and orientation of fracture systems using three component seismic methods. Our approach has been to use three component methods to sense the presence of fractures, and also to develop new techniques to sense the presence of gas. We use explosive sources rather than controlled shear-wave vibrators. Therefore our methods are relatively inexpensive. Explosive sources generate very strong shear-waves which can be used to observe shear-wave splitting.This paper discusses a case history of a method to search for fractures in NSW. It shows how the three component seismic method has been used with a conventional explosive source, to indicate the presence of a fracture zone and its orientation, in the Sydney Basin.