Journal articles on the topic 'Esso Australia'
To see the other types of publications on this topic, follow the link: Esso Australia.
Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles
Consult the top 50 journal articles for your research on the topic 'Esso Australia.'
Next to every source in the list of references, there is an 'Add to bibliography' button. Press on it, and we will generate automatically the bibliographic reference to the chosen work in the citation style you need: APA, MLA, Harvard, Chicago, Vancouver, etc.
You can also download the full text of the academic publication as pdf and read online its abstract whenever available in the metadata.
Browse journal articles on a wide variety of disciplines and organise your bibliography correctly.
1
Pearson, Craig, and David Robinson. "Esso Australia 2013 SAFE themes." APPEA Journal 54, no. 2 (2014): 505. http://dx.doi.org/10.1071/aj13078.
Full textAbstract:
The 2012 APPEA Stand Together for Safety video used a particularly powerful message: Speak up Act mindfully Follow the rules Get engaged This aligned with Esso’s global safety learning focus and so it has used the SAFE theme to increase its own workforce engagement. The aim of this initiative was to build and refresh skills and knowledge in the leadership and execution of personal safety expectations using our existing baseline safety tools. A planning workshop was conducted and a small cross-functional team was established to develop the SAFE theme quarterly schedule and materials. The quarterly SAFE theme builds on safety leadership behaviours through the use of existing tools: First quarter: speak up—focuses on tools for intervention such as approaching others. Second quarter: act mindfully—hazard identification including StepBack 5x5 and job safety analysis and risk tolerance such as 10 factors influencing risk tolerance. Third quarter: follow the rules—life saving actions including nine procedural focus areas that save lives Fourth quarter: get engaged—in-field review such as peer-to-peer observation Key to the success of the initiative was the significant involvement of senior leadership and first line supervisors. This improved workforce accountability through the application, demonstration, and promotion of safety leadership values. The initiative has resulted in an improvement in our safety performance, and improved communication and alignment across our facilities.
2
Gill., R. S. "ESSO AUSTRALIA APPROACH TO OFFSHORE SAFETY CASES." APPEA Journal 34, no. 1 (1994): 144. http://dx.doi.org/10.1071/aj93013.
Full textAbstract:
Following major incidents and a worldwide trend to a more structured approach to managing offshore safety, the Australian Government has regulated for the preparation of Safety Cases for all new offshore projects which commence design work after 1 July 1992. The Safety Case is required to demonstrate that safety management systems are adequate to ensure design, construction and operation of the installation are safe, that potential major hazards have been identified and appropriate controls are provided to ensure that risks are as low as reasonably practicable, and that adequate provision has been made for safe evacuation, escape and rescue. The safety case should be prepared using a balanced approach that results in a practical and value-added case.This paper summarises the approach adopted by Esso Australia in the preparation of safety cases for two new Bass Strait developments. It specifically covers the development of detailed internal guidelines for use in preparing safety cases, the safety case structure, content and emphasis, and includes examples to illustrate the key aspects of the Esso Australia Safety Case approach. The methodology described provides an effective means of achieving the objectives of a safety case.
3
Smith, M. G. "ESSO AUSTRALIA'S APPROACH TO SAFETY MANAGEMENT." APPEA Journal 37, no. 1 (1997): 672. http://dx.doi.org/10.1071/aj96048.
Full textAbstract:
Esso Australia Ltd.'s current company-wide safety initiatives are aimed at challenging all employees and contractors to think about steps they can take to help move towards an injury-free workplace.The development and practical application of a number of occupational safety initiatives have contributed towards Esso employees achieving a period approaching 13 million workhours (nearly five years) without a Lost Time Injury (LTI) and which also assisted Esso's contractor workforce to achieve a period of more than 3 million work hours LTI free w hile performing exploration, heavy construction, drilling, production and maintenance operations.Esso produces 32 million litres of crude oil per day and up to 25 million cubic metres of gas per day from 18 Bass Strait platforms, and two onshore oil/gas facilities on behalf of the Esso/BHP Petroleum joint venture (Fig 1). More than 1200 employees and 800–1,000 contractors are involved in operations involving a high level of production drilling and construction activity.This level of safety performance has been achieved through the unwavering commitment and dedication from all levels in the organisation to create a safety culture which is genuinely accepted by employees and contractors as one of their primary core personal values.The framework for Esso's safety management is Esso's 'Operations Integrity Management System' (OIMS). This requires that all operations adopt a structured approach to safety management with particular emphasis on risk management including continuously looking for opportunities to improve safety management processes.We have been active in developing and refining innovative personal and work group risk management tools (Steback 5x5 and Task Analyss). These tolsare designed to promote increased levels of shop floor involvement in identifying and addressing safety issues, improving first line supervisor involvement and safety skills, and nurturing a '24-hour' safety culture which extends beyond the workplace into the home and family environment. The combined effect of these initiatives is helping create a mindset that n level of injury (not even first aid) is acceptable regardless of the activity being undertaken. It promotes the expectation that everyone approaches their daily work with the mindset that 'all injuries are preventable!'
4
Henry, W. C., A. M. Hyden, and S. L. Williams. "INNOVATIONS IN SUBSEA DEVELOPMENT AND OPERATION." APPEA Journal 40, no. 1 (2000): 437. http://dx.doi.org/10.1071/aj99025.
Full textAbstract:
Esso Australia Ltd on behalf of the Esso/BHP joint venture, recently completed Australia's first deep- water oil and gas development, Blackback, in 395 m water depth in eastern Bass Strait. Esso used a phased development approach and an innovative development concept to mitigate the effect of reserves uncertainty. The development consists of three wells in daisy-chain formation tied back to the existing Mackerel platform, 23 km distant. The development also used innovative approaches for installation of flexible flowline and umbilical jumpers from the drilling rig, management of hydrates in the production flowline and control system integration.In the same time frame, Esso repaired the failed electro-hydraulic control systems of two 10-year-old subsea wells. The repair program used an innovative approach to fault diagnosis and field work.
5
Reinten, Ron. "Esso Australia's process safety management process." APPEA Journal 49, no. 2 (2009): 570. http://dx.doi.org/10.1071/aj08043.
Full textAbstract:
Safety is a core value at Esso Australia. We strive to observe the highest standards of safety to ensure that nobody gets hurt in our operations. We believe this goal can be achieved through a broadly shared commitment to personal and process safety—both of which are managed using our operations integrity management system (OIMS). In the Gippsland region of Victoria, Esso Australia operates oil and gas production facilities ranging from sub-sea completions to substantial staffed offshore facilities, an onshore crude stabilisation, three gas processing plants and a natural gas liquids fractionation plant, all interconnected by a network of offshore and onshore pipelines. Every day Esso’s Gippsland operations produce millions of litres of crude oil and millions of cubic meters of natural gas. Having all this fuel energy flowing through these plants each day at high pressures, and widely ranging temperatures, it is imperative that it is safely controlled and contained by the process equipment. How do we do this? With process safety systems. Process safety is a crucial component of OIMS that ensures Esso’s assets are operated and maintained in keeping with corporate and industry safety standards. In this presentation we show how process safety is managed within OIMS and how the people within Esso individually and collectively contribute to it. Our work in this area has recently been captured in a training package that includes a DVD shown at the conference. It was created to raise the awareness and understanding of all Esso employees about the principles that underpin Esso’s approach to process safety. This abstract outlines how we approach process safety across the life-cycle of our facilities and the role people play in managing this very important aspect of our work. Our training reinforces the message that responsibility for effective management of process safety lies with every employee and how OIMS is designed to assist people to achieve the desired results where all risks are appropriately managed. We have sought to connect the concepts used to manage personal safety, which are well understood by the workforce, with those that are needed to understand how to manage process safety.
6
Gibbeson, J. M., and C. D. Shinners. "ESSO AUSTRALIA LTD'S APPROACH TO RISK ASSESSMENT AND MANAGEMENT." APPEA Journal 38, no. 1 (1998): 552. http://dx.doi.org/10.1071/aj97030.
Full textAbstract:
Management of operational risk has become critical in the hydrocarbon process industry. The Esso Australia Ltd Risk Assessment and Management System comprises three defined levels, covering field and management risk control through to formal structured risk assessment. The process steps within each level are common and include planning, hazard identification and assessment, reporting, follow-up and risk closure. Methodologies and degree of detail differ depending on the level and application. The core philosophies underlying the system are:clearly defined responsibilities and approvals for risk ownership, stewardship, follow-up and closure;risks identified and assessed at the lowest appropriate level in the organisation;a common process for risk evaluation and ranking.emphasis on risk reduction follow-up action; andappropriate competency and training.The system also specifies the risk assessment requirements for major facilities and activities. For the offshore platforms these are integrated with the Safety Case requirements.Since its development, the Esso system has played a significant role in improving Esso's overall safety by providing a formal, integrated and consistent process for identifying and controlling risks and hazards at all levels and through each phase of production operations and support activities.
7
Pike, P. J., M. G. Smith, R. S. Gill, S. Savva, and A. J. Fisher. "ESSO/BHPP BASS STRAIT SAFETY-ACHIEVING WORLD CLASS PERFORMANCE." APPEA Journal 34, no. 1 (1994): 160. http://dx.doi.org/10.1071/aj93015.
Full textAbstract:
This paper describes the key initiatives Esso Australia Ltd (Esso) has undertaken to improve employee and contractor safety performance to world class standards.Esso produces 50M litres of crude oil per day and up to 25 million cubic metres of gas per day (peak winter demand) from 13 manned and three unmanned satellite platforms in Bass Strait, and two onshore oil/gas/LPG processing plants. Esso operates the facilities on behalf of the Esso/BHP Petroleum joint venture. Over 1400 employees and two million contractor work hours per year are involved in the operations.In 1992, Esso employees worked over 2.8 million hours with no Lost Time Injuries (LTI's). As of October 1, 1993, Esso employees have worked over 5.2 million hours LTI free for the first time in over 22 years of operations in Bass Strait. Employee Total Injuries (LTI's plus medical treatment injuries plus restricted work cases) are also significantly down over the period.In 1992, contractors working on Esso managed sites worked 2.2 million hours and sustained nine LTI's, for a frequency per million hours of 4.1. This was about half of the previous year's performance. Eight of these injuries occurred in the first half of 1992. Over the past 15 months, there have been two contractor LTI's equating to a LTI frequency of 0.7. Contractor Total Injuries are also significantly down over the period.In addition to occupational injury performance, the number and severity of operational incidents such as hydrocarbon releases and fires are also down.This improved safety performance and operations integrity is the culmination of a major effort to create a culture where safety is an integral part of our business and where everyone is committed to working safely.
8
Turner, Lucas, and David Prismall. "Developing an in-depth understanding of PFAS to deliver an effective remediation strategy." APPEA Journal 62, no. 2 (May 13, 2022): S81—S86. http://dx.doi.org/10.1071/aj21103.
Full textAbstract:
Esso Australia Resources Pty Ltd and BHP Petroleum (Bass Strait) Pty Ltd own a range of offshore and onshore hydrocarbon production facilities, which have been operated by Esso Australia Pty Ltd (Esso) for over 50 years. The Longford Fire Training Ground (FTG) is located adjacent to the Longford Plants and has been utilised by Esso for many years to train personnel in practical hydrocarbon firefighting skills, including applying firefighting foams to extinguish liquid hydrocarbon pool fires. In line with historical standard oil-field practices, per and polyfluoroalkyl substance (PFAS) containing firefighting foams were used at the Longford FTG. In response to the reported use of these foams and the potential for contamination associated with historical site operations, the Longford premises were the subject of recent environmental audit and clean-up plans with oversight by an EPA Victoria auditor. Esso engaged a broad range of experts to complete the environmental investigation and develop a remediation action plan that complied with the PFAS National Environmental Management Plan. Key aspects of this project included: understanding the location and setting, with respect to geological conditions and groundwater impacts; development of remediation objectives and strategy; identification of practical remediation methods including short-term and longer-term measures to mitigate priority PFAS sources within the FTG; and a planning framework for future management of the premises. This paper shares how a responsible operator applies a disciplined and scientifically based environmental approach to further the state of knowledge on practical PFAS remediation methods and achieve a sustainable environmental outcome in the communities that they operate in.
9
Wilmshurst, Jan. "USE OF DRAG REDUCER CHEMICAL IN THE BASS STRAIT CRUDE OIL PRODUCING SYSTEM." APPEA Journal 25, no. 1 (1985): 119. http://dx.doi.org/10.1071/aj84010.
Full textAbstract:
Esso Australia Ltd (on behalf of the Esso/BHP joint venture) operates a crude oil and natural gas processing system based on the offshore fields in Bass Strait.Crude oil is discharged from the offshore fields via a 132-km pipeline to the crude stabilization plant at Longford. A 187-km pipeline is then used to transfer stabilized crude to Long Island Point, where the oil is held in storage prior to discharge to Australian refineries and to export.Without the use of drag reducer chemical, Bass Strait crude production is limited by pipeline hydraulic capacity. Since the last quarter of 1983, drag reducer has been injected at both Halibut platform and Longford as required to meet the demand for crude oil. As a result, daily production rates have been increased by more than ten per cent.Drag reducer chemical is a long chain polymer which acts to reduce the extent of turbulence in the flowing oil stream. The chemical is highly viscous, and specifically designed gear pumps are required to achieve satisfactory injection into the pipeline systems.
10
Angove, Ron. "THE POINT TORMENT SEISMIC SURVEY: A SEMI-PORTABLE SEISMIC OPERATION." APPEA Journal 25, no. 1 (1985): 248. http://dx.doi.org/10.1071/aj84021.
Full textAbstract:
Point Torment, an area of low-lying tidal mudflats and adjacent coastal peninsula, was the site of a seismic survey unique to Australian geophysical exploration. This survey was conducted by Esso Australia Ltd and the area, part of EP 104, is located north of the township of Derby in Western Australia.Surface conditions in the area varied from thickly wooded grassland on the peninsula to open mudflats. Vehicle access to the mudflats was severely restricted and helicopter support was necessary to maintain the seismic operation throughout. The operation was extremely labour intensive; for example, line-cutting through mangrove areas was carried out by hand.Seismic recording was achieved using an OPSEIS* 5500 digital radio telemetry system. With this system data is collected by portable field units labelled Remote Telemetry Units (RTU's) and subsequently retrieved by Radio telemetry and permanently stored on magnetic tape by a Central Recording Station (CRS). This was the first instance of this system being employed in Australia.
11
Webb, C. F. "ZERO INJURIES." APPEA Journal 40, no. 2 (2000): 126. http://dx.doi.org/10.1071/aj99068.
Full textAbstract:
Esso Australia Pty Ltd, on behalf of the Esso/BHP Petroleum Joint Venture, recently completed Australia’s first deepwater oil and gas subsea development, Blackback, in Bass Strait. The project consisted of fabrication and installation of new facilities for the existing Mackerel platform, fabrication and installation of a 23 km pipeline and the installation of three subsea wells. The facilities were installed injury-free. This paper focusses on the application of safety systems to achieve this result.The Project.The vision of a zero Total Recordable Injury (TRI)-free workplace.Management commitment and leadership.Application of effective safety management systems.Empowering safety leadership.Taking the Blackback story further.Safety performance and other business outcomes.Conclusions/accomplishments lessons learnt and recommendations.
12
Corbould, H. M., and M. J. Nolan. "INJURY- FREE WORK ENVIRONMENT: MYTH OR REALITY?" APPEA Journal 29, no. 1 (1989): 80. http://dx.doi.org/10.1071/aj88012.
Full textAbstract:
Sound management practices, and employee awareness and commitment, are the keys to eliminating workplace injury. In Esso Australia's production operations, the goal is NO INJURIES for both company and contractor employees. Achieving this goal entails significant commitment to putting safety first, and elimination of conflicting messages about the production versus safety priorities.Throughout the last decade, Esso Australia has increasingly sought to heighten the safety awareness of all people working within and supporting its production operations. The emphasis has gradually moved from hardware safety to focusing on attitudes within the workforce — at the same time, however, ensuring that facilities meet industry standards.Results in 1988 show a marked drop in injury days lost for the total company and contractor employee group in production operations.A safe work environment is good business. Putting safety first need not cost money; indeed a safer workplace can be more efficient. Achieving a safe environment involves clear communication of goals and values, employee participation, delegation of authority, increasing accountability, effective incident investigation and follow- up, appropriate discipline, and recognition of positive contributions. Of paramount importance is a clear direction from top management that safety is the top priority.
13
Hayes, John J. "BASS STRAIT WATER HANDLING DEVELOPMENTS." APPEA Journal 25, no. 1 (1985): 114. http://dx.doi.org/10.1071/aj84009.
Full textAbstract:
Esso Australia Ltd operates, on behalf of Esso/BHP, a crude oil and natural gas producing and processing facility in the Gippsland Basin, Victoria. Saline formation water produced with the oil is treated and discharged overboard from offshore platforms wherever possible to limit the volume of saline water in the pipeline system and avoid onshore disposal of saline water. Esso has developed oily water treatment and continuous oil-in- water monitoring beyond conventional technology and operates within stringent overboard water discharge regulations. Initial oily water treating installations were Cross Flow Interceptors, a corrugated plate gravity separator. Unsatisfactory performance prompted investigations leading to development of the Dissolved Gas Flotation unit using evolved gas to lift oil droplets to the surface. These units operate successfully offshore today. The most recent developments have been associated with a liquid-liquid hydrocyclone trade named 'Vortoil'. This has been tested offshore with an 'Purometer' continuous oil-in-water monitor. The Vortoil and Purometer have both performed favourably and proven a compact, low cost combination for future water treating installations.
14
Titus, P. G. "WEST TUNA I BREAM B: APPLICATION OF CONCRETE TECHNOLOGY OFFSHORE AUSTRALIA." APPEA Journal 37, no. 1 (1997): 546. http://dx.doi.org/10.1071/aj96033.
Full textAbstract:
Esso/BHPP's West Tuna and Bream B Platforms are the first completed concrete-based platforms in Australia and are Exxon's first designed, built and operated concrete gravity structures (CGSs). Both platforms were towed to location, complete with commissioned topsides facilities, in fourth quarter 1996 and successfully installed in 61 m of water. They will add in excess of 45,000 BOPD (7200 kl/d) of oil production to Bass Strait volumes. West Tuna, with 48 well slots, will be Esso/BHPP's largest and most complex Bass Strait production facility, whereas Bream B will be an 18-slot, unstaffed minimum facility satellite platform with a 720-tonne topsides. By comparison, West Tuna's topsides weigh 7,300 tonnes.Esso/BHPP chose the CGS concept for the two developments following extensive conceptual studies with selected North Sea designers. Because of rising derrick barge day rates in the early 1990s (required for steel pile jacket installations), coupled with the availability of a suitable casting basin near Sydney, the CGS concept was judged economically attractive, with savings estimated at 10 per cent of the total facilities capital expenditure relative to its steel pile jacket alternative.The project saw a number of firsts, including the use of the world's largest land-based crawler cranes to lift and set the completed production modules over 75 m in the air onto the completed CGS structures. CGS fabrication productivity problems were experienced during the early phase of construction reflecting the complex nature of the construction, however implementation of a number of project management initiatives resulted in achievement of world-class productivity by completion of the works.
15
Hyden, A. M. "OFFSHORE FACILITIES REMOVAL — A MAJOR ISSUE NOW AND FOR THE FUTURE." APPEA Journal 29, no. 1 (1989): 6. http://dx.doi.org/10.1071/aj88002.
Full textAbstract:
The costs associated with removal of offshore production facilities can have a serious impact on project economics, especially for the shorter- life marginal fields. The requirements for removal of offshore facilities are set out in the Petroleum (Submerged Lands) Act and the guidelines prepared by the International Maritime Organisation, a United Nations agency. Esso Australia Limited has completed a major study of the removal of Bass Strait platforms and has evaluated the costs of platform removal by various methods. Environmental considerations, the needs and safety of other users of the sea, and cost need to be considered when examining options for removal of offshore platforms. The Australian Government needs to act soon to resolve the issues of residual liability and tax deductibility and so enable the oil industry to select the optimum removal methods and reliably predict future costs for removal.
16
Terrens, G. W., D. Gwyther, and M. J. Keough. "ENVIRONMENTAL ASSESSMENT OF SYNTHETIC-BASED DRILLING MUD DISCHARGES TO BASS STRAIT, AUSTRALIA." APPEA Journal 38, no. 1 (1998): 610. http://dx.doi.org/10.1071/aj97037.
Full textAbstract:
Esso Australia Ltd. (Esso) on behalf of the Esso/BHP joint venture undertakes exploration and development drilling activities to produce oil and gas from the Gippsland Basin in eastern Bass Strait. As part of the environmental management of the operation, a field monitoring program was undertaken to verify the predicted limited effect on the seabed of the discharge of residual synthetic based mud (SBM) adhered to drill cuttings.Reservoir studies of the mature Fortescue oil field identified scope to more efficiently deplete existing reserves as well as develop undrained oil pools within the known reservoir system. As such, 18 additional wells were drilled from the Fortescue platform in 1994-1996 following the original development drilling program when 21 wells were drilled in 1983-1985.Esso's standard drilling fluid in Bass Strait is an environmentally acceptable water based mud (WBM). However, due to the high frictional forces involved the greater lubricating properties of a non-water based drilling mud were required to drill the long reach, high angle sections of seven of the additional wells. The ester SBM was chosen on the basis of its lubricity and biodegradability, to reduce any potential environmental effects from the persistence of non-water based mud in seabed sediments.A seabed monitoring program was undertaken around the Fortescue platform by taking seabed samples from August 1995 to August 1997 at sites along a transect following the predominant ocean current and at control sites, before, during and after the period in which SBM cuttings were discharged. The seabed sediments were measured for esters, barium, biological changes and grain size. Results show clearly the increase in esters concentration in sediments during drilling, then the rapid decrease after completion of cuttings discharge. After a recovery period of 11 months from completion of SBM drilling, SBM esters were not detected in sediments. Sediment barium concentration was also found to be elevated, but only after SBM had been used, indicating greater dispersion of WBM than the more cohesive SBM. The barium concentrations found generally do not have measurable effects on biota. The impact on the sediment biology was found to be limited to the sampling site 100 m from the platform discharge point with recovery evident within four months of completion of drilling.Mechanisms for recovery of the minimal zone of effect are thought to be a combination of the biodegradation of the ester SBM used and the physical seabed dispersion process evident in eastern Bass Strait generated by the continuous series of storms which pass through especially in winter.
17
Barton, A. D. "RISK-BASED MANAGEMENT OF STRUCTURAL INTEGRITY FOR BASS STRAIT PLATFORMS." APPEA Journal 41, no. 1 (2001): 727. http://dx.doi.org/10.1071/aj00042.
Full textAbstract:
Esso Australia Pty Ltd (Esso) has embraced the framework of risk management to improve the focus and priorities of its inspection and maintenance activities. Structural integrity is one of the disciplines that has adopted a risk-based approach to inspection and integrity assessment and this has been applied to Esso/BHP’s 18 offshore platforms located in Bass Strait.The paper provides a discussion of the issues faced in the management of structural integrity of offshore platforms which lead to the development of a risk-based inspection (RBI) strategy. RBI is applied to improve the prediction of the structures’ condition and provides a consistent basis for continued improvement in the future. The RBI model generates targeted inspection workscopes for each platform that, coupled with the implementation of appropriate inspection techniques, ensure that the integrity of the platforms can be managed with greater confidence and at lower cost.The RBI approach has resulted in reduced focus on traditional areas of uncertainty such as fatigue of tubular joints, and increased focus on secondary structures, for example service caissons. This shift in focus is made possible by building into the risk model a calibration process that considers previous inspection data. A key component of this calibration is a new method developed to calibrate tubular joint fatigue lives.
18
Kubik, John, Grant Shaw, and Melissa Vicario. "Overcoming COVID challenges in project execution – West Barracouta." APPEA Journal 62, no. 2 (May 13, 2022): S295—S298. http://dx.doi.org/10.1071/aj21153.
Full textAbstract:
The West Barracouta (BTW) field, one of the largest proven undeveloped gas fields off the south-eastern Australian coast, commenced production in April 2021. The project was developed by Esso-BHP Gippsland Basin Joint Venture (GBJV), a 50–50 JV between ExxonMobil’s subsidiary Esso Australia and BHP Petroleum. The BTW gas field is situated ~6 km south west of the existing Barracouta gas field and platform, the first GBJV platform in Bass Strait. The BTW development involved drilling two subsea production wells, installation of umbilical controls from the existing platform and installation of a ~6 km subsea flowline to connect to existing gas pipeline via a hot tap. The BTW team successfully navigated through engineering, fabrication, testing, mobilisation of an international team and installation of the facilities in a COVID environment. The paper shares insights on how to: manage fabrication impacts with closures and restricted workhours to minimise disruption to the project; complete videoconference Hazid Identification Risk Assessment workshops across different geographical locations; develop and execute methodology for distributed component integrated testing with hardware located in different geographical locations; complete remote inspections, Factory Acceptance Tests (FAT)/verification using videoconference; complete enhanced familiarisation and testing activities at shorebase, prior to offshore installation, given restrictions in overseas travel/access to FAT locations; and safely manage installation personnel to ensure continuity of activities in a COVID environment, e.g. platform, installation vessel and diver COVID requirements.
19
Payne, Harold, and Janelle Manton. "Evolution of the Australian fiscal landscape and its impact on oil and gas investments in Australia." APPEA Journal 53, no. 2 (2013): 445. http://dx.doi.org/10.1071/aj12056.
Full textAbstract:
The oil and gas industry is among the most regulated and highly taxed sectors of the Australian economy. In recent times, the industry has been confronted with ongoing tax reforms that significantly impact the after-tax economics of projects. Examples include the introduction of the carbon pricing mechanism, the extension of the Petroleum Resource Rent Tax (PRRT) to the onshore oil and gas sector, the decision in the Esso case impacting on PRRT taxpayers, amendments to R&D tax incentives and modifications to the taxation system affecting mobile employees. Although the Business Tax Working Group recently did not make any recommendations to broaden the tax base to fund a reduction in the company tax rate, the desire to undertake further reforms that may impact the sector remains. The year ahead will see implementation of further transfer pricing reforms, ongoing consultation and review regarding the definition of exploration expenditure, and increasing focus on corporate international tax reform in line with global trends. Any reform has the potential to have a material impact on the capital- and exploration-intensive oil and gas industry, which also relies heavily on capital funding from multinational investors. This extended abstract analyses the recent reforms and their impact on the oil and gas sector, provides an outlook of other relevant areas of potential fiscal change, and assesses what this might mean for the Australian oil and gas industry.
20
Spencer, Steven. "The story of Esso Australia’s push to explore the frontier Gippsland Basin with the ultra-deep water Sculpin-1 exploration well." APPEA Journal 62, no. 2 (May 13, 2022): S497—S501. http://dx.doi.org/10.1071/aj21064.
Full textAbstract:
In late 2018, Esso Australia embarked on the drilling of Sculpin-1. Drilled in 2278 m of water, this is Australia’s deepest water exploration well and the first ultra-deep water well in the Gippsland Basin. Drilling of this well was the culmination of a bold exploration campaign in the VIC/P70 permit at the southeastern margin of the prolific hydrocarbon producing Gippsland Basin, which also saw the drilling of Baldfish-1 and Hairtail-1 in 2018. An east coast gas market with a high demand for additional gas resources combined with Esso Australia’s renewed technical focus on the deep and ultra-deep water sectors of the VIC/P70 exploration permit led to the identification of the Sculpin prospect, a stratigraphic lead premised on a late Cretaceous deep water reservoir system flowing into the south east Gippsland Basin depocentre from southern hinterlands. Technical analysis including integrated seismic toolkits, spectral decomposition and colour-blend imaging, rock properties and amplitude versus offset/direct hydrocarbon indicator modelling were key to Esso’s decision to test the new play with the Sculpin-1 well. Although the well did not encounter hydrocarbons, it did provide insights into reservoir quality, source and migration in the previously untested southeastern margin of the basin.
21
McNulty, Patti, and Mark Mathieson. "Esso Highlands Limited—committed to world's best practice assessment processes for the PNG LNG Project." APPEA Journal 51, no. 2 (2011): 709. http://dx.doi.org/10.1071/aj10089.
Full textAbstract:
The PNG LNG Project is a major resource project in Papua New Guinea that should double the GDP of PNG and provide significant benefits to numerous remote, regional and metropolitan communities. Through a commitment to providing optimal training and employment opportunities for PNG nationals, Esso Highlands Limited is recruiting candidates from all over PNG to take up training and employment opportunities. One opportunity for PNG candidates is the Operations and Maintenance Technician Traineeship Program. This involves 18 months of preparatory training in Port Moresby and 12 months at advanced technical training facilities overseas followed by up to 24 months on the job training at the actual facility; either the Hides gas conditioning plant in the Southern Highlands or at the LNG plant outside Port Moresby in PNG. This program is structured to establish a highly-trained workforce of more than 150 technicians for key operational roles in the PNG LNG Project. A nationwide recruitment drive attracted more than 8,000 applicants. Although the scale of this response—in a country with poor socio-economic conditions and limited paid employment opportunities—was anticipated, the linguistic and cultural diversity of the candidates provided a major challenge for Esso Highlands. The challenge involved how to appropriately and fairly assess and select the required number of trainees from this massive pool of candidates. To address some of the assessment and selection needs, Esso Highlands Limited commissioned ValueEdge Consulting in light of their experience and expertise in delivering similar culturally appropriate assessment programs throughout Australia and southeast Asia. This presentation will provide an overview of the staged assessment model used to select the 76 most suitable candidates from the original 8,000 applicants for the first traineeship program, which commenced in Port Moresby in July 2010. The success of this recruitment program in a culturally, linguistically and educationally diverse country is highlighted by the fact that another significant-sized group of the candidates were retained by Esso Highlands Limited in internship positions—this is in addition to the 76 candidates selected for trainee positions. Due to the high-calibre talent pool attracted by this opportunity and assessed through this program, the extended pool of retained candidates enabled Esso Highlands Limited to meet their needs for the traineeships and also to identify suitable candidates to fulfill a range of their other training and employment opportunities. This presentation will outline details of the selection methods and tools used for the assessment of: training potential, technical aptitude, interpersonal skills, technical knowledge, team work, and individual competencies. The presentation also outlines a model for other green-field sites in countries where traditional recruitment methodologies are ineffective or culturally and linguistically biased against the local population.
22
Barnes, Lachlan, Katrina Hall, Craig Blount, Madelaine Hooper, David van Senden, Andrew Costen, Chris Scraggs, David Provis, and Daniel Pygas. "Monitoring marine effects of produced formation water discharge in Bass Strait." APPEA Journal 59, no. 1 (2019): 1. http://dx.doi.org/10.1071/aj18226.
Full textAbstract:
Esso Australia Pty Ltd (Esso), in a joint venture with BHP Petroleum Pty Ltd, operates 23 oil and gas production platforms and subsea facilities off the Victorian coast near Gippsland, Australia. The underlying reservoirs have multi-darcy sands and a strong aquifer water drive, so in addition to oil and gas, the extraction activities result in substantial amounts of produced formation water (PFW). Following on-platform treatment, PFW containing a variety of hydrocarbons, ions and inorganics, such as calcium, ammonia, sulfate and trace metals, is discharged into the receiving environment. This paper reports on a study undertaken to investigate the potential effects of PFW discharges from two platforms (Tuna (TNA) and West Kingfish (WKF)) on the receiving environment. Four complementary sampling approaches were used to address the objectives of the study: (1) measure and estimate the dilution of Rhodamine FWT dye solution in the receiving environment following injection into the PFW discharge line, (2) collect and analyse undiluted PFW samples before discharge, (3) collect and analyse marine water samples from within the discharge plume and (4) collect and analyse sediment and benthic infauna samples at various distances away from platforms and at reference locations. Results indicate the rate of PFW dilution within the receiving environment is more rapid than predicted by existing numerical models and that the concentration of all analytes present in PFW were below Australian and New Zealand Environment Conservation Council (ANZECC) 2000 guideline trigger values for 80% protection; moreover, with one exception, analytes were not detected above background levels more than 59 m from the platform. With the exception of a few samples containing metals, specifically arsenic, copper, lead, zinc and nickel, concentrations of analytes in the majority of sediment samples collected were below the ANZECC 2000 and revised 2013 sediment quality guidelines. A diverse range of benthic infauna were sampled, with the abundance of a limited number of taxa influenced by distance from individual platforms. No substantial differences in abundances of benthic infauna were detected at distances greater than 1.3 km from TNA and 1.0 km from WKF, compared with reference locations. These results indicate that PFW discharges from TNA and WKF likely represent a low risk to the receiving environment.
23
Kubik, John, Grant Shaw, and Melissa Vicario. "Unlocking Gippsland reserves with a minimum kit solution – West Barracouta." APPEA Journal 62, no. 2 (May 13, 2022): S137—S141. http://dx.doi.org/10.1071/aj21143.
Full textAbstract:
The West Barracouta (BTW), field one of the largest proven undeveloped gas fields off the south-eastern Australian coast, commenced production in April 2021. The project was developed by Esso-BHP Gippsland Basin Joint Venture (JV), a 50–50 JV between ExxonMobil’s subsidiary Esso Australia and BHP Petroleum. The BTW gas field is situated ~6 km south west of the existing Barracouta gas field and platform, the first Gippsland Basin Joint Venture platform in Bass Strait. The BTW development involved drilling two subsea production wells, installation of umbilical controls from the existing platform and installation of a ~6 km subsea flowline to connect to existing gas pipeline via a hot tap. The BTW team will share insights on how it: (1) utilised minimum kit solution and verification of existing asset condition; subsea hot tap into operational gas pipeline and re-use of existing platform J-tube to minimise works on and around the Barracouta Platform (including diving work). (2) Managed an Operator first – co-mingled wet gas subsea pipelines while operating in hydrate regions; via detailed water detection metre/software solution, downhole zone isolation and systematic operating guidelines. (3) Leveraged Installation Contractor competitive Front End Engineering and Design (FEED) enabling optimisation of facilities design/execution strategies to align with strengths and maximise overall project value. (4) Leveraged the OneSubsea/Subsea 7 Subsea Integration Alliance and global worldwide network to execute the subsea design (including qualification), manufacture and installation. (5) Utilised the incumbent Engineering, Procurement and Construction (EPC) contractor to integrate the subsea and topsides control systems to support a single operation system linked to the existing to Distributed Control System (DCS).
24
Netscher, Nick, and Jaime Thompson. "Managing escape, evacuation and rescue (EER) risk on aging offshore facilities." APPEA Journal 59, no. 1 (2019): 260. http://dx.doi.org/10.1071/aj18133.
Full textAbstract:
Esso Australia Resources Pty Ltd and BHP Petroleum (Bass Strait) Pty Ltd own numerous offshore facilities, which have been operated by Esso Australia Pty Ltd (EAPL) for over 40 years. With respect to escape, evacuation and rescue (EER), the long standing philosophy for these facilities has been to muster at the external assembly areas (EAA) near the evacuation lifeboat stations, to allow for swift evacuation when the need is apparent. This philosophy has underpinned the design of these offshore assets to date. For new-build offshore facilities, typical EER philosophies include the provision of an enclosed temporary refuge (TR), specifically to maintain a safe environment for personnel (in the event of an emergency) such that they can muster before evacuation, or remain on the facility until the event is brought under control. TRs typically provide protection to personnel from hazards that the EAA may not (i.e. smoke), but may increase the duration of a potential evacuation if they are not located within close proximity to evacuation stations. This paper considers the potential changes in risk presented by the two evacuation philosophies, and the potential implications of changing from one philosophy to another on an existing facility. The analysis expands to facility operational and design considerations. This paper also describes a methodology to leverage existing quantitative risk assessments to assess (a) how the risk profile to personnel may change depending on the EER philosophy; (b) how the implementation of additional risk controls will impact risk; and (c) how the results of the assessment can be used to establish an ‘as low as is reasonably practicable’ (ALARP) position.
25
Henzell, S. T., H. R. Irrgang, E. J. Janssen, R. A. H. Mitchell, G. O. Morrell, I. D. Palmer, and N. W. Seage. "FORTESCUE RESERVOIR DEVELOPMENT AND RESERVOIR STUDIES." APPEA Journal 25, no. 1 (1985): 95. http://dx.doi.org/10.1071/aj84007.
Full textAbstract:
The Fortescue field in the Gippsland Basin, offshore southeastern Australia is being developed from two platforms (Fortescue A and Cobia A) by Esso Australia Ltd. (operator) and BHP Petroleum.The Fortescue reservoir is a stratigraphic trap at the top of the Latrobe Group of sediments. It overlies the western flank of the Halibut and Cobia fields and is separated from them by a non-net sequence of shales and coals which form a hydraulic barrier between the two systems. Development drilling into the Fortescue reservoir commenced in April 1983 with production coming onstream in May 1983. Fortescue, with booked reserves of 44 stock tank gigalitres (280 million stock tank barrels) of 43° API oil, is the seventh major oil reservoir to be developed in the offshore Gippsland Basin by Esso/BHP.In mid-1984, after drilling a total of 20 exploration and development wells, and after approximately one year of production, a detailed three-dimensional, two-phase reservoir simulation study was performed to examine the recovery efficiency, drainage patterns, pressure performance and production rate potential of the reservoir.The model was validated by history matching an extensive suite of Repeat Formation Test (RFT)* pressure data. The results confirmed the reserves basis, and demonstrated that the ultimate oil recovery from the reservoir is not sensitive to production rate.This result is consistent with studies on other high quality Latrobe Group reservoirs in the Gippsland Basin which contain undersaturated crudes and receive very strong water drive from the Basin-wide aquifer system. With the development of the simulation model during the development phase, it has been possible to more accurately define the optimal well pattern for the remainder of the development.* Mark of Schlumberger
26
Keen, G. R., and M. G. Sethi. "LONG ISLAND POINT FRACTIONATION PLANT FACILITIES LIFE EXTENSION." APPEA Journal 47, no. 1 (2007): 301. http://dx.doi.org/10.1071/aj06021.
Full textAbstract:
ExxonMobil Australia Pty Ltd’s subsidiary, Esso Australia Resources Pty Ltd (ExxonMobil), and BHP Billiton jointly own and operate an LPG fractionation facility at Long Island Point, near Hastings in Victoria. This facility began operating in 1970 as part of the overall development of Gippsland oil and gas resources. The facility had a nominal design life of 30 years; however, the facility will be required to operate for many more years, given the significant gas reserves remaining in Bass Strait. A plan was developed to identify and progress plant facility upgrades to ensure continued, safe operation to life end. Nine separate projects with a total value in excess of A$250 million were developed and are now in various stages of progress. The key projects include: refrigerated LPG storage tank refurbishment, fire system upgrade, a new control room and control system, and plant emergency shutdown system upgrades. These projects focus on achieving high standards of safe operations and long-term reliability through application of advances in technology to ready the facilities for their remaining life.
27
Savage, T. M. "CRUDE OIL MARKETING DEREGULATION." APPEA Journal 28, no. 1 (1988): 366. http://dx.doi.org/10.1071/aj87031.
Full textAbstract:
The Australian Government's decision to deregulate indigenous crude oil marketing from 1 January 1988 brings to an end the period of the Government's involvement in this area of the petroleum industry. The determination of price, the development and monitoring of administrative procedures to ensure equitable allocation of indigenous crude, and the resolution of differing views between producers, refiners and marketers were all areas where Government was actively involved. While the extent of future involvement is uncertain, the policy changes put a different dimension on exploration and production efforts for all companies and on their relationship with the marketplace, both locally and overseas.The move to deregulation widens the available options for all parties - producers, refiner/ marketers and international traders. WTiile these options exist, the most probable situation in 1988 is not expected to be greatly different from that which has existed in the last couple of years. No refineries will be shut down; product imports will increase slightly but not significantly enough to affect total demand on Australian refineries. A reduced level of indigenous crude should be run to enable greater flexibility in crude/feedstock selection for optimising refinery profitability. However, at least 75 per cent of indigenous production should be continued to be absorbed within Australia with the bulk of the exports being made from Gippsland and Jabiru areas.The change in emphasis towards product excise has ensured that the Australian Government has the mechanism to sustain revenue, essentially independent of the prices obtained for indigenous crude. As such, the Government's involvement in crude oil marketing, if at all, will be significantly reduced.Factors affecting negotiations between producers and other interested parties have been explored. It is considered that, although it is highly unlikely that firm markets will have been established by early 1988, a workable set of arrangements will have been developed to ensure that crude oil production is moved. As many uncertainties will exist on the validity of these arrangements for the long term, there will be a tendency towards spot or short-term sales agreements so that the options are left open. The key pricing points are seen to be the value BP Australia is prepared to pay for Western Australia and Queensland production, at Kwinana and Brisbane respectively, and the prices being obtained by Esso/BHP for Gippsland crude in the export market.
28
Gray, Alasdair, and Chris Wilson. "Industry-wide learnings from the independent review of Australia’s most complex decommissioning program." APPEA Journal 62, no. 2 (May 13, 2022): S268—S273. http://dx.doi.org/10.1071/aj21163.
Full textAbstract:
In 2019, the Minister for Resources and Northern Australia issued a Statement of Expectations to the National Offshore Petroleum and Safety Environmental Management Authority (NOPSEMA) establishing heightened expectations for duty holder compliance with their decommissioning obligations. In response, NOPSEMA increased compliance monitoring and enforcement activities to assess adequacy of the level of decommissioning planning and implementation by duty holders. On 20 May 2021, NOPSEMA issued a general direction to Esso Australia relating to their Bass Strait decommissioning program, likely one of Australia’s most significant and complex decommissioning projects. The direction included a requirement to undertake an independent review of Esso’s engineering and project management approach and consider if there were opportunities for reducing the timeframe to commence and subsequently complete all necessary decommissioning activities. This review was subsequently awarded to Xodus, in partnership with Labrador and focussed on core disciplines such as project management, regulatory approvals, stakeholder engagement, well plugging and abandonment, contracting, topsides and subsea facilities and waste management. Australia is at a pivotal stage in the context of decommissioning oil and gas infrastructure. With heightened regulatory oversight alongside recent and continuing changes to legislation, ensuring supply chain is ready to deliver against this backdrop will be critical to the future success of regional decommissioning and ensure all parties bearing the cost of this work are satisfied. This paper will discuss the independent review process of Esso’s decommissioning program and outline key challenges and opportunities the industry faces in realising improved decommissioning efficiency in the region.
29
Fagg, Kathryn J. "GAS LIFT IN BASS STRAIT." APPEA Journal 25, no. 1 (1985): 107. http://dx.doi.org/10.1071/aj84008.
Full textAbstract:
Gas lift has proved a most effective artificial lift method for the fields operated by Esso Australia Ltd in Bass Strait for the Esso-BHP joint venture. Gas lift is now used to produce approximately 5 st ML/d of the total crude production from the Strait. It has enabled wells to be produced to water cuts higher than 90 per cent, increasing the oil recovery from the fields by up to 35 per cent.Gas lift work in Bass Strait to date has included the use of special packoff gas lift assemblies for wells with sliding sleeves, the development of a tool to assist the opening of the sleeves, improved operating techniques to limit slugging from gas-lifted wells, and the testing of gas lift performance. Gas lifting has been more successful than expected, and as a result, workovers initially planned to install full gas lift strings for older wells have not been necessary. The two phase flow correlations available have been improved to match the performance of the gas-lifted wells. The correlations are now used to design tubing strings with a number of gas lift mandrels prior to running the initial completions and to select the optimum gas injection depth.Future work in gas lift for Bass Strait will involve the optimisation and automation of lift gas distribution on the platforms. Gas lift will also be used for planned future developments, including mini-platforms and subsea completions.
30
McKay, Ian, Paul Russ, and Jack Mohr. "A sand management system for mature offshore production facilities." APPEA Journal 48, no. 1 (2008): 13. http://dx.doi.org/10.1071/aj07002.
Full textAbstract:
ExxonMobil subsidiary Esso Australia Pty Ltd has implemented a sand management system to minimise the impact of sand to its operations in the Bass Strait. Some of these facilities have been in operation for more than 30 years and no downhole sand control was installed during original drilling completions. Over time, with increased water production, sand production has become more problematic. This paper examines the strategies used to minimise the impact of sand production on facilities including the impact of corrosion and erosion on downhole, offshore topsides, pipeline and onshore plant infrastructure. The sand management system includes detailed operational instructions for flowing wells, monitoring sand production, and installing retrofit sand control where required. The system also defines a management structure with assigned responsibilities to ensure that operational guidelines are followed and continuous improvement opportunities are implemented.
31
Percival, I. G., and P. M. Cooney. "PETROLEUM GEOLOGY OF THE MERLINLEIGH SUB-BASIN, WESTERN AUSTRALIA." APPEA Journal 25, no. 1 (1985): 190. http://dx.doi.org/10.1071/aj84017.
Full textAbstract:
Esso's recent drilling program in the Merlinleigh Sub-basin, onshore Carnarvon Basin, represents the culmination of the first phase of concerted exploration activity in the area since the WAPET era of the 1960s. The region is unusual among Australian petroleum provinces in having excellent exposures of reservoir, source and seal rocks of Palaeozoic age. While both Esso wells (Burna 1 and Gascoyne 1) failed to encounter hydrocarbons in the primary Wooramel Group play, encouraging potential still exists. The reservoir in the Wooramel Group play is the Early Permian Moogooloo Sandstone, a fluviodeltaic to nearshore sheet-sand facies with porosities to 23 per cent and permeabilities in excess of 100 millidarcys. Likely hydrocarbon sources are siltstones in the overlying Byro Group, with total organic carbon contents averaging 3 per cent, and calcilutites in the subjacent Callytharra Formation with similar organic content. Locally, the Jimba Jimba Calcarenite Member (Billidee Formation) and the Cordalia Sandstone also provide rich source units. The least certain aspects of the Early Permian play are fault and top seal, and reservoir quality at depth. Notwithstanding the relatively shallow depths to source strata in the area, vitrinite reflectance analyses from drill cores indicate that maturation is attained as shallow as 900 m on the folded and faulted western margin of the sub-basin, and at an approximate depth of 1200 m in the depocentre beneath the Kennedy Range. This can be related to high regional heat flow, and to erosion of some 1500-2000 m of sediments prior to the regional Early Cretaceous transgression.Older plays which have been identified in the area remain to be adequately evaluated. Potential reservoir sands are present in the Silurian Tumblagooda Sandstone, the Middle and Late Devonian Nannyarra and Munabia Sandstones, and the Early Carboniferous Williambury Formation. Possible source rocks include carbonates of Middle Devonian and Early Carboniferous age. One of the objects of current research has been to locate areas where seal, provided by the glacigene Lyons Formation of Late Carboniferous-Early Permian age, is sufficiently thin to permit economic drilling.
32
Heath, N. M. "GIPPSLAND—NEW POTENTIAL FROM A MATURE BASIN." APPEA Journal 43, no. 1 (2003): 223. http://dx.doi.org/10.1071/aj02011.
Full textAbstract:
It is now 39 years since the first gas was discovered in Bass Strait’s Gippsland Basin. Advances in exploration and production technology mean that today Australia’s longest producing offshore basin is also one of Australia’s most prospective. Gippsland is now producing around 160,000 barrels of crude and 570 million cubic feet of gas per day. To date it has produced more than 3.5 billion barrels of oil and 5 trillion cubic feet of gas and the value of the infrastructure in place is estimated to be around A$16 billion.Australia’s evolving energy market means that gas demand continues to grow. Following the re-structuring of energy markets in southeastern Australia and the installation of new pipeline infrastructure, Gippsland gas now flows to Victoria, NSW, Tasmania and will supply into South Australia from 2004. To meet this growing demand the Esso/BHPBilliton joint venture partners are investing heavily and utilising a vast array of 3D exploration technology to unlock new opportunities. In 2002 they conducted the largest 3D survey ever undertaken in Bass Strait and expect to conduct another in early 2003. A program of exploration drilling is expected to commence in late 2003. With expanded market opportunities and a gas resource base of more than 5 trillion cubic feet, the future looks bright for Gippsland.
33
Edwardes, A. K. Khurana R. J. "NEW DEVELOPMENTS IN BASS — STRAIT THE LOW- COST CHALLENGE." APPEA Journal 29, no. 1 (1989): 1. http://dx.doi.org/10.1071/aj88001.
Full textAbstract:
Esso Australia, with its co- venturer BHP Petroleum, is planning to bring five new fields into production in 1989. These fields are relatively small, with total reserves of approximately 50 million barrels (7950 ML). Development concepts new to Bass Strait have been identified to make them economically attractive.The significant change made to the fiscal environment of Bass Strait in June 1987, when the Government provided an exemption from excise for the first 30 million barrels (4770 ML) of oil production for certain offshore projects, has played a key role in the economic viability of these developments.The Whiting field will be developed with a mini- platform, the Seahorse and Tarwhine fields with satellite sub- sea wells, and the Perch and Dolphin project will use mono- towers.New organisational and technical approaches have been used to select cost- effective development options for these fields. These approaches include increased integration between exploration and production activities, reductions in capital expenditure through applying novel concepts and researching big ticket items such as facilities installation, and minimising of operating costs by remote operation of facilities.With the developments planned for 1989, and with ongoing research, the outlook can be described as optimistic provided tax regimes continue to encourage development of small fields both in Bass Strait and elsewhere offshore in Australia.
34
Hale, A. R. "Lessons from Longford: the Esso Gas Plant Explosion. Andrew Hopkins. CCH Australia, Sydney. 2000. ISBN 1 86468 422 4. p. 172. Price AU$44.95 soft cover." Safety Science 38, no. 3 (August 2001): 257–59. http://dx.doi.org/10.1016/s0925-7535(00)00055-2.
Full text
35
Bon, R. A., and D. K. Castles. "WATER MIST AS AN ALTERNATIVE TO HALON." APPEA Journal 37, no. 1 (1997): 698. http://dx.doi.org/10.1071/aj96052.
Full textAbstract:
Halon is being removed from all Esso facilities in accordance with Victorian Environment Protection Legislation for the control of ozone depleting substances. The phasing out of halon as a fire protection system required critical evaluation of available alternatives for protection of turbine machinery and switchgear rooms.Esso Australia Ltd., having evaluated and tested a range of available halon replacement systems, has selected a European manufactured water mist as the preferred alternative for fire protection of turbine machinery enclosures. The system selected required significant modifications from the vendor's standard configuration in order for it to be applied to the offshore environment, be accepted by turbine Original Equipment Manufacturers and achieve independent third party certification. Water mist cannot be applied in all situations to replace halon, with an inert gaseous agent required for the protection of switchgear rooms and for flare snuffing.This paper discusses the issues associated with the selection and installation of this new technology and the lessons learnt. It also discusses issues associated with the evaluation, testing, design and installation of over 80 systems on 14 offshore platforms and two onshore plants.
36
Mathers, A. J., and S. Savva. "EFFECTIVE SAFETY CASE DEVELOPMENT." APPEA Journal 43, no. 1 (2003): 805. http://dx.doi.org/10.1071/aj02050.
Full textAbstract:
Esso Australia Pty Ltd, in Victoria, Australia has recently been involved in the preparation of over 20 safety cases to meet both offshore (Victoria and Western Australia) [Petroleum {Submerged Lands} Act] and onshore [Victorian Occupational Health and Safety Act] regulatory requirements.This paper focusses on the development of the onshore safety cases for both Longford and Long Island Point plants to meet the Victorian Occupational Health and Safety (Major Hazard Facilities) Regulations 2000. Both plants have been granted a five-year unconditional licence to operate.The objectives of the safety case development were to ensure that Esso:addressed major hazard facilities regulatory requirements; maximised benefit from the process, and to maximise benefit from existing work; was consistent with site approach to risk assessment/ safety culture; involved appropriate workforce from all areas— operations, maintenance and technical support; enhanced the effective knowledge and understanding of the workforce; and developed a communication tool to enable ease of understanding by site personnel.Esso’s approach of using qualitative risk assessment techniques (familiar to many site personnel) enabled the process to use tools that provided ease of involvement for the non-technical or safety specialists. This paper will explain this approach in greater detail, demonstrating how this successfully met the stringent requirements of the regulations whilst providing Hazard Register documentation readily understood by the key customer— our site workforce.The hazard register clearly identifies the relevant hazards and their controls, as well as highlighting the linkages to the safety management system and documented performance standards. A comprehensive training program provides all personnel working at site with an overview of the safety case, and the necessary skills and knowledge to be able to use the safety case and hazard register to its maximum advantage. The safety case resource booklet (similar to our offshore approach) is an integral part of the training program, and provides an ongoing reference source for trainees. It continues to receive recognition by both regulators and industry.
37
Graham, E. D. "DRIVERS FOR THE DEVELOPMENT OF AN INTEGRATED SUPPLY BASE AND OFFSHORE SUPPLY CHAIN, NORTH WEST SHELF, AUSTRALIA." APPEA Journal 44, no. 1 (2004): 593. http://dx.doi.org/10.1071/aj03027.
Full textAbstract:
Since the commencement of the major developments on the North West Shelf, the offshore resource industry, during both its construction and operational phases, has faced considerable logistical impediments to cost-effective solutions for the offshore supply chain. These impediments have included distance, scant resources, lack of infrastructure both on and offshore and lack of critical mass.Throughout the world, offshore projects have greatly benefitted from the availability of integrated services to cater for the transport of equipment from the point of manufacture or distribution to the offshore location.Within the Australian context the privately controlled Esso Barry Beach and Dampier Woodside facilities are examples of integrated services, but both differ considerably from a public multi-user facility. The model used in the Timor Sea of one vessel or vessels for the use of several operators is another example.The NorthWest Shelf has now reached the critical mass and it became apparent several years ago that the area needed an integrated supply base available to multiple operators. It would need to include a heavy loadout wharf, laydown areas, slipway and engineering facilities and office space to service forthcoming projects, as well as planning and cooperation amongst all players to maximise efficiency and use of scant resources as drivers for economic benefits to offshore operators in the region.Furthermore the fallout from the events of 11 September 2001 and continuing threats of terrorism has meant the security of marine assets has become an important part of each operator’s everyday life. The introduction of new legislation relating to this security issue is planned for mid 2004.In 2000 and 2001 Mermaid Marine Australia Limited undertook a major expansion of its Dampier supply base, and established a world-class facility to meet the growing demands of the region.This complex has for the first time provided the northwest of Australia, particularly the North West Shelf, Carnarvon Basin and the onshore developments on the Burrup Peninsula, with a facility for offloading and loadout of heavy shipments and fabrication and slipway facilities, coupled with the advantages of a large supply base. This facility can also be expanded to meet growth and the emerging requirements related to security.This paper describes the drivers for change commencing with the earliest supply chains and following through to the integrated service now availabe. These drivers meet the requirements of the offshore operators in the region as well as showing the benefits anticipated from this integrated service. The paper also outlines in detail the requirements of the International Maritime Organisation for worldwide changes to port and offshore security.
38
VAN DER ENG, PIERRE. "Turning Adversity into Opportunity: Philips in Australia, 1945-1980." Enterprise & Society 19, no. 1 (September 5, 2017): 179–207. http://dx.doi.org/10.1017/eso.2017.12.
Full textAbstract:
Philips Australia, the Australian subsidiary of Dutch MNE Philips Electronics, experienced difficulties during 1942–1943, when it came close to being nationalized as enemy property. In response, the company set out to improve its reputation in the local radio parts and electronics industry and in Australian markets. Its strategy of embedding itself in Australian society served the purpose of improving company performance and influencing the government policies that guided the rapid development of Australia’s postwar electronics industry. With this strategy, Philips Australia minimized the risks and maximized the commercial opportunities it faced. The firm localized senior management, maximized local procurement and local manufacturing, took a leading role in industry associations, engaged politically influential board members, and used marketing tools to build a strong brand and a positive public profile in Australia. However, the company became aware of the limitations of this strategy in 1973, when a new Labor government reduced trade protection. Increasing competition from Japanese electronics firms forced Philips Australia to restructure and downsize its production operations. Despite increasing reliance on imports from the parent company’s regional supply centers and efforts to specialize production on high-value added products, the firm saw its profitability and market share in Australia decrease.
39
Mustoe, S. H., M. C. Greenwood, and J. F. Moore. "ENVIRONMENTAL MANAGEMENT IN THE BASS STRAIT NORTHERN FIELDS 3D SEISMIC SURVEY." APPEA Journal 43, no. 1 (2003): 761. http://dx.doi.org/10.1071/aj02046.
Full textAbstract:
The Northern Fields 3D seismic survey in Bass Strait was a large survey of 4,000 km2, carried out between the months of October 2001 to July 2002. The program attracted interest from various groups regarding the possible impacts of the survey on fisheries and cetaceans (whales and dolphins).The survey was the first to operate in eastern Bass Strait after the Environment Australia Guidelines for Minimising Acoustic Disturbance to Whales, came into force, in September 2001.The Northern Fields program was conducted in accordance with a method statement for the mitigation of impacts to cetaceans, developed by Esso to meet the requirements of Australian environmental legislation and acknowledge environmental best practice. The program utilised teams of three whale watchers who maintained a continuous rotational watch of two observers throughout the day. This proved to be a reliable element of the program and was one of several key learnings that may assist other companies in developing comprehensive and cost-effective mitigation strategies for future surveys.Concerns raised by the fishing industry and some conservation groups about the potentially detrimental impact of seismic sources on commercial scallop larvae and fish populations were effectively addressed by avoiding commercial scallop areas during spawning periods. A controlled, in-situ study of scallops exposed to the acoustic source completed during the program conclusively demonstrated no significant variation in scallop mortality or muscle strength.Observation data collected during this survey provided a sample of the cetacean population in Eastern Bass Strait during a large part of the annual migration cycle. These observations, which may be relevant to the planning and execution of future seismic surveys in the region, are discussed. The findings also provide valuable information for continued research into the distribution and conservation of whales and dolphins in Bass Strait.
40
Norman, G. M. "KEEPING IT GOING—LONGFORD COMBINAIRE REFURBISHMENT." APPEA Journal 47, no. 1 (2007): 293. http://dx.doi.org/10.1071/aj06020.
Full textAbstract:
ExxonMobil Australia Pty Ltd’s subsidiary, Esso Australia Resources Pty Ltd (ExxonMobil), is undertaking a refurbishment program on the critical combinaire cooling units at its Longford Gas Plant 1. The combinaires are combination air-cooled heat exchangers with evaporative cooling supported on a large concrete structure. The functions performed include gas treating, inlet gas cooling, distillation reflux and condensate cooling.The Longford combinaire units have already been in operation in excess of 30 years and the facility will be required to operate for many more years, given the significant reserves remaining in Gippsland. The combinaire units provide the central cooling duties in both the Longford crude stabilisation plant and Gas Plant 1. Shutdown of these units has a major impact on the plant processing capacity for both oil and gas. An in-depth understanding of forecast market demand, processing requirements and interaction of the process units throughout the Longford facility has enabled the identification of discrete annual periods when certain sections of the combinaire unit can be brought offline.The refurbishment campaign was developed to systematically refurbish sections of the combinaire unit that were not at full capacity seasonally. Critical to achieving the tight timelines is having timely delivery of refurbished and new components to site. This is being achieved through close collaboration with numerous vendors and initiatives such as setting up a local workshop for tube bundle refurbishment.The combinaire refurbishment campaign is on track to meet the target completion date and continues with minimal impact on Bass Strait production of oil and gas. Success is being achieved through detailed analysis across a range of disciplines and the application of a design-one, build-multiple philosophy. A large and complex project being undertaken whilst keeping the plant going.
41
Fowler, Keirnan J. A., Suwash Chandra Acharya, Nans Addor, Chihchung Chou, and Murray C. Peel. "CAMELS-AUS: hydrometeorological time series and landscape attributes for 222 catchments in Australia." Earth System Science Data 13, no. 8 (August 6, 2021): 3847–67. http://dx.doi.org/10.5194/essd-13-3847-2021.
Full textAbstract:
Abstract. This paper presents the Australian edition of the Catchment Attributes and Meteorology for Large-sample Studies (CAMELS) series of datasets. CAMELS-AUS (Australia) comprises data for 222 unregulated catchments, combining hydrometeorological time series (streamflow and 18 climatic variables) with 134 attributes related to geology, soil, topography, land cover, anthropogenic influence and hydroclimatology. The CAMELS-AUS catchments have been monitored for decades (more than 85 % have streamflow records longer than 40 years) and are relatively free of large-scale changes, such as significant changes in land use. Rating curve uncertainty estimates are provided for most (75 %) of the catchments, and multiple atmospheric datasets are included, offering insights into forcing uncertainty. This dataset allows users globally to freely access catchment data drawn from Australia's unique hydroclimatology, particularly notable for its large interannual variability. Combined with arid catchment data from the CAMELS datasets for the USA and Chile, CAMELS-AUS constitutes an unprecedented resource for the study of arid-zone hydrology. CAMELS-AUS is freely downloadable from https://doi.org/10.1594/PANGAEA.921850 (Fowler et al., 2020a).
42
Bok, Melanie, Scott Chidgey, and Peter Crockett. "Five years on: monitoring of Long Island Point’s Western Port wastewater discharge." APPEA Journal 57, no. 1 (2017): 10. http://dx.doi.org/10.1071/aj16193.
Full textAbstract:
The Esso Long Island Point facility is situated on the edge of Western Port, an important Ramsar designated wetland for migratory birds in Victoria, Australia. The gas fractionation and crude oil storage facility has operated for over 40 years and has discharged treated wastewater to Western Port for most of these years in accordance with its environmental regulatory licence. The 2003 State Environment Protection Policy for Waters of Western Port is the Victorian Environment Protection Authority’s regulatory framework for licensing wastewater discharges to the wetland, and among other items, requires that discharges must cause no ‘detrimental change in the environmental quality of the receiving waters’ or ‘chronic impacts outside any declared mixing zone’. A major upgrade to the water treatment facility in 2010 included a risk-based marine ecosystem program to monitor key environmental indicators including water quality, jetty pile invertebrate communities and seagrass condition. The program’s longer-term monitoring record has allowed assessment of potential chronic effects on invertebrates and seagrass by comparing temporal changes at monitoring sites over the period from pre-operations (2010) to present (2016) and spatial changes between near-field to far-field sites, kilometres from the discharge point. The program has shown that management of the discharge maintains beneficial uses and environmental objectives at the boundary of the mixing zone, and the marine ecosystem is protected from potentially slower and longer-term adverse effects in the far-field. The program demonstrates that the treated wastewater discharge has had no adverse impact on key environmental indicators in Western Port over the longer-term study period.
43
Younes, A. M., G. O. Morrell, and A. B. Thompson. "USE OF COMPUTER GRAPHICS: THE WEST KINGFISH POST DEVELOPMENT RESERVOIR SIMULATION STUDY." APPEA Journal 26, no. 1 (1986): 447. http://dx.doi.org/10.1071/aj85038.
Full textAbstract:
The West Kingfish Field in the Gippsland Basin, offshore Victoria, has been developed from the West King-fish platform by Esso Australia Ltd (operator) and BHP Petroleum.The structure is an essentially separate, largely stratigraphic accumulation that forms the western flank of the Kingfish feature. A total of 19 development wells were drilled from the West Kingfish platform between October 1982 and May 1984. Information provided by these wells was used in a West Kingfish post-development geologic study and a reservoir simulation study.As a result of these studies the estimated recoverable oil volume has been increased 55 per cent to 27.0 stock tank gigalitres (170 million stock tank barrels). The studies also formed the technical basis for obtaining new oil classification of the P-1.1 reservoir which is the only sand body that has been found in the Gurnard Formation in the Kingfish area.The simulation study was accomplished with an extremely high level of efficiency due to the extensive and effective use of computer graphics technology in model construction, history matching and predictions.Computer graphics technology has also been used very effectively in presenting the simulation study results in an understandable way to audiences with various backgrounds. A portable microcomputer has been used to store hundreds of graphic displays which are projected with a large screen video projector.Presentations using this new display technology have been well received and have been very successful in conveying the results of a complex reservoir simulation study and in identifying future field development opportunities to audiences with various backgrounds.
44
Cary, Olivia K., and Nick Netscher. "Effective engagement on process safety fundamentals in challenging times." APPEA Journal 61, no. 2 (2021): 540. http://dx.doi.org/10.1071/aj20048.
Full textAbstract:
Esso Australia Resources Pty Ltd (EAPL) and BHP Billiton Petroleum (Bass Strait) Pty Ltd own a range of offshore and onshore hydrocarbon production facilities, which have been operated by EAPL for over 50 years. Over this time, EAPL has lived a rich history of process safety experiences, and developed a range of processes and systems to manage process safety risks. Despite technical system refinement and advances across industry we continue to experience process safety events, and manage risks with plant both at the start and end of its lifecycle. Many of our major hazards are inherent to our operations, and do not become lower risk with lower product price or field activity levels. It is therefore critical that we maintain a laser focus on managing process safety risks during this time of unprecedented change, and find impactful opportunities to engage with operations, maintenance and technical teams on their role in process safety. To this end, EAPL have commenced a journey of scenario based process safety management and applying it to our most significant risks. The outcome has been a step change in process safety literacy across our business, an increased awareness of safe operating conditions and a workforce engaged in managing safeguard health. This study shares how a scenario based approach can leverage a traditional safety case and safety management system approach and make process safety personal: Simplifying communication of higher risks and the equipment and processes that keep us safe Clarifying safeguard ownership and responsibilities for safeguard health management Embedding safeguard health management in routine operations and maintenance tasks Strengthening critical safeguards which mostly depend on human performance to be effective
45
Williamson, A. J. "BLACKBACK SUBSEA A1A REMOTE WELL KILL." APPEA Journal 46, no. 1 (2006): 385. http://dx.doi.org/10.1071/aj05021.
Full textAbstract:
Esso Australia Pty Ltd has recently completed a unique wellwork operation to secure the A1A well on its Blackback facility in Bass Strait. The Blackback facility consists of three subsea wellheads, linked in daisy-chain formation, sitting in 400 m of water depth. The field is approximately 19 km southeast of host platform Mackerel and 87 km from shore.The Blackback A1A well recently developed leak rates through the subsurface safety valve and production master valve which exceeded Esso’s internal acceptance criteria. Production rates on the A1A well did not justify an immediate workover to restore the integrity of the passing valves. Although there were no immediate environmental concerns, inadvertent damage to the wellhead had potential to create an environmental exposure, so the decision was made to kill the well temporarily until a workover opportunity arose.An innovative remote well kill procedure was developed, utilising the 23 km gaslift pipeline to pump kill fluids down to the well from host platform Mackerel. The procedure involved a unique and intricate shut-down procedure and pumping strategy. The main operational risks pre-identified and mitigated in the procedure included potential hydrate formation in the pipelines, over-pressure or blockage of the gaslift pipeline, and use of significant volumes of methanol for hydrate management.The Blackback well kill operation was executed to plan, with no safety, environmental or facility related issues. The A1A well remains in a killed state with positive overbalance, while start-up of the A3 well following the procedure was successfully executed. This achievement has opened new doors for conducting well kill operations on subsea facilities, with significant cost efficiencies when compared to the alternative—mobilisation of a floating drill rig.
46
Bapat, Dilip, and David Standfield. "Esso pipeline replacement project." APPEA Journal 58, no. 2 (2018): 674. http://dx.doi.org/10.1071/aj17125.
Full textAbstract:
Esso recently commissioned (October 2017) a new 350-mm 187-km-long pipeline for carrying crude and condensate from Esso’s Longford Plant (Longford) in Gippsland Victoria, along an existing easement to the Long Island Point facility (LIP) at Hastings, Victoria. This pipeline replaces an existing 700-mm pipeline that was approaching the end of its operational life. Through continued delivery of crude and condensate, this pipeline also ensures that the natural gas which is produced along with these liquids continues to flow to Australian households and businesses. The project included pig launching and receiving facilities at Longford and LIP terminals, 10 main-line valve stations as well as fibre-optic cable for control, leak detection and communications purposes. Early engagement of its contractor partners played a key role in the successful execution of the project. Today’s landscape along the pipeline route significantly differs from that when the original pipeline was installed. Individual needs of the landowners affected by the construction were carefully considered. Significant measures were taken to minimise any impact to the unique flora and fauna of the region. Sensitivities around cultural heritage locations were taken into account while finalising the construction methods. Construction of the pipeline occurred in two summer phases (2015–2016 and 2016–2017) to make efficient use of dry weather and to minimise disturbance to landowners and the environment. The project was completed within budget and ahead of schedule.
47
KENELEY, MONICA J. "Marketing the Message: The Making of the Market for Life Insurance in Australia, 1850–1940." Enterprise & Society 16, no. 4 (September 21, 2015): 929–56. http://dx.doi.org/10.1017/eso.2015.40.
Full textAbstract:
During the late nineteenth century, sales of life insurance products in Australia increased at a rapid rate. An investigation of the way in which life insurance products were targeted to the consumers provides insights not only into the marketing approaches, but also the changing nature of the mutual organization. This article uses a “stages” approach to analyze the evolution of the marketing message. The experience of Australian mutual insurers suggests that marketing strategies, as with other types of organizational skills, evolve in response to both the prevailing business environment and the ability of the firm to acquire and implement new knowledge and ways of conducting business.
48
Codilean, Alexandru T., Henry Munack, Timothy J. Cohen, Wanchese M. Saktura, Andrew Gray, and Simon M. Mudd. "OCTOPUS: an open cosmogenic isotope and luminescence database." Earth System Science Data 10, no. 4 (November 30, 2018): 2123–39. http://dx.doi.org/10.5194/essd-10-2123-2018.
Full textAbstract:
Abstract. We present a database of cosmogenic radionuclide and luminescence measurements in fluvial sediment. With support from the Australian National Data Service (ANDS) we have built infrastructure for hosting and maintaining the data at the University of Wollongong and making this available to the research community via an Open Geospatial Consortium (OGC)-compliant web service. The cosmogenic radionuclide (CRN) part of the database consists of 10Be and 26Al measurements in modern fluvial sediment samples from across the globe, along with ancillary geospatial vector and raster layers, including sample site, basin outline, digital elevation model, gradient raster, flow-direction and flow-accumulation rasters, atmospheric pressure raster, and CRN production scaling and topographic shielding factor rasters. Sample metadata are comprehensive and include all necessary information for the recalculation of denudation rates using CAIRN, an open-source program for calculating basin-wide denudation rates from 10Be and 26Al data. Further all data have been recalculated and harmonised using the same program. The luminescence part of the database consists of thermoluminescence (TL) and optically stimulated luminescence (OSL) measurements in fluvial sediment samples from stratigraphic sections and sediment cores from across the Australian continent and includes ancillary vector and raster geospatial data. The database can be interrogated and downloaded via a custom-built web map service. More advanced interrogation and exporting to various data formats, including the ESRI Shapefile and Google Earth's KML, is also possible via the Web Feature Service (WFS) capability running on the OCTOPUS server. Use of open standards also ensures that data layers are visible to other OGC-compliant data-sharing services. OCTOPUS and its associated data curation framework provide the opportunity for researchers to reuse previously published but otherwise unusable CRN and luminescence data. This delivers the potential to harness old but valuable data that would otherwise be lost to the research community. OCTOPUS can be accessed at https://earth.uow.edu.au (last access: 28 November 2018). The individual data collections can also be accessed via the following DOIs: https://doi.org/10.4225/48/5a8367feac9b2 (CRN International), https://doi.org/10.4225/48/5a836cdfac9b5 (CRN Australia), and https://doi.org/10.4225/48/5a836db1ac9b6 (OSL & TL Australia).
49
Framenau, Volker W., and Pedro de S. Castanheira. "A new genus of Australian orb-weaving spider with extreme sexual size dimorphism (Araneae, Araneidae)." Zoosystematics and Evolution 98, no. 1 (May 5, 2022): 137–49. http://dx.doi.org/10.3897/zse.98.82649.
Full textAbstract:
The new Australian orb-weaving spider genus Mangrovia in the family Araneidae Clerck, 1757 is described. It is characterised by extreme sexual size-dimorphism (eSSD) with females (total length 8–10 mm) ca. 3 to 5 times larger than males (2.5–3 mm). Whilst Mangrovia shares with the informal Australian ‘backobourkiine’ clade a single seta on the male pedipalp patella, the genus is probably more closely related to the ‘zealaraneines’ or associated genera. In addition to eSSD and the single patellar spine, the genus is characterised by a distinct subterminal embolus branch in males. The new genus includes two species: the type species Mangrovia albida (L. Koch, 1871) comb. nov. (= Epeira fastidiosa Keyserling, 1887, new syn.) from Queensland and Mangrovia occidentalissp. nov. from Western Australia. Both species are apparently coastal and occur in mangroves, but also in riparian woodland. Spiders were found resting in rolled-up leaves adjacent to their orb-web.
50
Jong, Lenneke M., Christopher T. Plummer, Jason L. Roberts, Andrew D. Moy, Mark A. J. Curran, Tessa R. Vance, Joel B. Pedro, et al. "2000 years of annual ice core data from Law Dome, East Antarctica." Earth System Science Data 14, no. 7 (July 19, 2022): 3313–28. http://dx.doi.org/10.5194/essd-14-3313-2022.
Full textAbstract:
Abstract. Ice core records from Law Dome in East Antarctica collected over the last four decades provide high-resolution data for studies of the climate of Antarctica, Australia, and the Southern and Indo-Pacific oceans. Here, we present a set of annually dated records of trace chemistry, stable water isotopes and snow accumulation from Law Dome covering the period from −11 to 2017 CE (1961 to −66 BP 1950) and the level-1 chemistry data from which the annual chemistry records are derived. Law Dome ice core records have been used extensively in studies of the past climate of the Southern Hemisphere and in large-scale data syntheses and reconstructions in a region where few records exist, especially at high temporal resolution. This dataset provides an update and extensions both forward and back in time of previously published subsets of the data, bringing them together into a coherent set with improved dating to enable continued use of this record. The data are available for download from the Australian Antarctic Data Centre at https://doi.org/10.26179/5zm0-v192 (Curran et al., 2021).