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NAGAR, Anirudha. "The Juukan Gorge Incident: Key Lessons on Free, Prior and Informed Consent." Business and Human Rights Journal 6, no. 2 (May 25, 2021): 377–83. http://dx.doi.org/10.1017/bhj.2021.18.
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On 24 May 2020, Rio Tinto detonated an area of the Juukan Gorge in the Pilbara in Western Australia as part of its iron ore mining operations, damaging two ancient rock shelters with profound cultural significance to the Puutu Kunti Kurrama and Pinikura (PKKP) People.1 The incident has brought international attention to the importance of Indigenous cultural heritage within broader environmental, social and governance (ESG) considerations.
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Blain, Nicholas, and Norman Dufty. "Industrial Relations in Western Australia." Journal of Industrial Relations 31, no. 4 (December 1989): 552–77. http://dx.doi.org/10.1177/002218568903100406.
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Keirath, G. D. "Industrial Relations Reforms in Western Australia, 1993." Journal of Industrial Relations 37, no. 1 (March 1995): 52–62. http://dx.doi.org/10.1177/002218569503700103.
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Ellem, Bradon, Johan Sandström, and Curt Persson. "Neoliberal trajectories in mining: Comparing Malmfälten and the Pilbara." European Journal of Industrial Relations 26, no. 3 (May 9, 2019): 297–312. http://dx.doi.org/10.1177/0959680119847873.
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We compare the iron ore sectors and mining regions of Malmfälten in Sweden and the Pilbara in Australia. Both are physically isolated and the product is economically vital, but we find differences in industrial relations which accord with what would be expected in coordinated and liberal market economies. A closer examination, attentive to history and geography and in which changes in institutional form and function are highlighted, reveals, however, that these differences are more apparent than real, and that there is a common neoliberal trajectory. This analysis also suggests that changes in these sites at times drive transformations in national industrial relations.
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Ellem, Bradon. "Resource Peripheries and Neoliberalism: the Pilbara and the remaking of industrial relations in Australia." Australian Geographer 46, no. 3 (July 3, 2015): 323–37. http://dx.doi.org/10.1080/00049182.2015.1048587.
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Gilmour, James, Conrad W. Speed, and Russ Babcock. "Coral reproduction in Western Australia." PeerJ 4 (May 18, 2016): e2010. http://dx.doi.org/10.7717/peerj.2010.
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Larval production and recruitment underpin the maintenance of coral populations, but these early life history stages are vulnerable to extreme variation in physical conditions. Environmental managers aim to minimise human impacts during significant periods of larval production and recruitment on reefs, but doing so requires knowledge of the modes and timing of coral reproduction. Most corals are hermaphroditic or gonochoric, with a brooding or broadcast spawning mode of reproduction. Brooding corals are a significant component of some reefs and produce larvae over consecutive months. Broadcast spawning corals are more common and display considerable variation in their patterns of spawning among reefs. Highly synchronous spawning can occur on reefs around Australia, particularly on the Great Barrier Reef. On Australia’s remote north-west coast there have been fewer studies of coral reproduction. The recent industrial expansion into these regions has facilitated research, but the associated data are often contained within confidential reports. Here we combine information in this grey-literature with that available publicly to update our knowledge of coral reproduction in WA, for tens of thousands of corals and hundreds of species from over a dozen reefs spanning 20° of latitude. We identified broad patterns in coral reproduction, but more detailed insights were hindered by biased sampling; most studies focused on species ofAcroporasampled over a few months at several reefs. Within the existing data, there was a latitudinal gradient in spawning activity among seasons, with mass spawning during autumn occurring on all reefs (but the temperate south-west). Participation in a smaller, multi-specific spawning during spring decreased from approximately one quarter of corals on the Kimberley Oceanic reefs to little participation at Ningaloo. Within these seasons, spawning was concentrated in March and/or April, and October and/or November, depending on the timing of the full moon. The timing of the full moon determined whether spawning was split over two months, which was common on tropical reefs. There were few data available for non-Acroporacorals, which may have different patterns of reproduction. For example, the massivePoritesseemed to spawn through spring to autumn on Kimberley Oceanic reefs and during summer in the Pilbara region, where other common corals (e.g.Turbinaria&Pavona) also displayed different patterns of reproduction to theAcropora. The brooding corals (Isopora&Seriatopora) on Kimberley Oceanic reefs appeared to planulate during many months, possibly with peaks from spring to autumn; a similar pattern is likely on other WA reefs. Gaps in knowledge were also due to the difficulty in identifying species and issues with methodology. We briefly discuss some of these issues and suggest an approach to quantifying variation in reproductive output throughout a year.
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Hamilton, Neil, Mike Onus, Bruce Withnell, and Kay Withnell. "Recent sightings of the Night Parrot Pezoporus occidentalis from Matuwa (Lorna Glen) and Millrose Station in Western Australia." Australian Field Ornithology 34 (2017): 71–75. http://dx.doi.org/10.20938/afo34071075.
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The elusive and rare Night Parrot Pezoporus occidentalis is being continually searched for and sightings reported. It was thought possibly to be extinct until recent discoveries of two dead specimens in Queensland (1999, 2006), a confirmed sighting in the Pilbara in 2005, the first photograph of a live bird in Queensland in 2013, subsequent discoveries in western Queensland, and a photograph of a Night Parrot in flight from the interior of Western Australia in 2017. We describe our sightings of the Night Parrot from the arid region of Western Australia on 24 November and 5 December 2009. In addition, we briefly describe other possible sightings from the same location and adjoining Millrose pastoral station.
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JPT staff, _. "E&P Notes (March 2021)." Journal of Petroleum Technology 73, no. 03 (March 1, 2021): 14–17. http://dx.doi.org/10.2118/0321-0014-jpt.
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KrisEnergy Pumps Cambodia’s First Crude in 17 Years A Cambodian concession has commenced production after years of delays in a venture between Singapore’s KrisEnergy and the government. The crude comes from oil fields in Block A, comprising 3083 km2 of the Khmer basin in the oil-rich Gulf of Thailand, off the southwestern coast of Sihanoukville. The concession will progress in phases once new wells are commissioned and completed. Kelvin Tang, chief executive of KrisEnergy’s Cambodian operations, called the 29 December event “an important strategic milestone” for the company, while Prime Minister Hun Sen hailed the first extraction as “a new achievement for Cambodia’s economy” and “a huge gift for our nation.” Ironbark Australian Exploration Well Declared Dry; Co-Owner Stocks Plummet BP has come up dry at its Ironbark-1 exploration well, the anticipated multi-trillion-scf prospect off the west Australian Pilbara coast. The disappointing prospect was once seen as a potential gas supplier to the emptying North West Shelf (NWS) LNG plant, where BP is a co-owner, within 5 to 10 years. After 2 months of drilling to a total depth of 5618 m, “no significant hydrocarbon shows were encountered in any of the target sands,” according to co-owner New Zealand Oil and Gas (NZOG). Petrorecôncavo Buys Petrobras’ Onshore Bahian Stake for $30 Million Brazilian operator Petrobras on 23 December signed a contract with independent producer Petrorecôncavo to sell its entire stake in 12 onshore E&P fields, the Remanso Cluster, in the state of Bahia. The sale value for the fields was $30 million; $4 million was paid on signing, $21 million at the closing of the transaction, and $5 million will be paid 1 year after that. The Remanso Cluster comprises the onshore fields of Brejinho, Canabrava, Cassarongongo, Fazenda Belém, Gomo, Mata de São João, Norte Fazenda Caruaçu, Remanso, Rio dos Ovos, Rio Subaúma, São Pedro, and Sesmaria. Zion Spuds the Israeli Megiddo-Jezreel #2 Well On 6 January, Zion Oil and Gas officially spudded the MegiddoJezreel #2 on its 99,000acre MegiddoJezreel license area in Israel. “With unique operating conditions in the COVID19 environment, our crews have performed an amazing task,” Zion CEO Robert Dunn said. “Mobilizing a rig into a new country during a pandemic and rigging up is the most challenging part of the drilling operation,” Zion’s vice president of operations, Monty Kness, added. Exxon Declares a Dud at Second Guyana Well Exxon Mobil said on 15 January that its exploration well in the prolific Stabroek Block off Guyana’s coast did not find oil in its target area. Exxon, which operates the Stabroek Block in a consortium with Hess and China’s CNOOC, has made 18 discoveries in the area in 5 years, totaling more than 8 billion BOE, for a combined potential for producing up to 750,000 B/D of crude. The Hassa1 exploration well was the giant’s second setback to its drilling campaign in recent months. Heirs Holdings Buys 45% of Shell Nigeria’s OML 17 Field Shell Nigeria announced on 15 January it had completed a $533 million sale of its stakes in an onshore OML 17 oil field in Nigeria to African strategic investor Heirs Holdings, Nigeria’s largest publicly listed conglomerate. The deal is one of the largest oil and gas financings in Africa in more than a decade, with a financing component of $1.1 billion provided by a consortium of global and regional banks and investors. Heirs Holdings, in partnership with Transcorp, one of the largest power producers in Nigeria with 2000 MW of installed capacity, purchased 45% stake in the field. It acquired the stakes of Shell, Total, and Eni to further its expansion into the oil and gas industry. Apex Discovers Oil in Egypt’s Western Desert Privately held independent E&P firm Apex International Energy, backed in part by UK energy investment firm Blue Water Energy, on 18 January announced a discovery in the Southeast Meleiha Concession (SEM) in the western desert of Egypt. The discovery was made at the SEMZ-11X well located 10 km west of Zarif field, the nearest producing field. The well was drilled to a total depth of 5,700 ft and encountered 65 ft of oil pay in the Cretaceous sandstones of the Bahariya and Abu Roash G formations. Testing of the Bahariya resulted in a peak rate of 2,100 B/D with no water. Additional uphole pay exists in the Bahariya and Abu Roash G formations that can be added to the production stream in the future. Kosmos Announces Oil at Winterfell Well Dallas-based E&P independent Kosmos Energy announced on 19 January an oil discovery in deepwater US Gulf of Mexico. The Winterfell discovery well, the product of infrastructure-led exploration (ILX), was drilled to a total depth of approximately 23,000 ft and is located in approximately 5,300 ft of water. This subsalt Upper Miocene prospect in off-shore Louisiana encountered approximately 85 ft of net oil pay in two intervals. ILX exploration, which has featured prominently in upstream operators’ portfolios in recent years of relatively low oil prices, is exploration around producing hubs that can be hooked up to those facilities easily and cheaply. The development sidesteps the need for costly and time-consuming individual hub construction. Equinor Gets Permit To Drill North Sea Wildcat Well The Norwegian Petroleum Directorate has granted Equinor a drilling permit for wildcat well 31/11-1 S in the North Sea offshore Norway, 62 km south of the Troll field. The drilling program is the first exploration well to be drilled in production license 785 S, awarded on 6 February 2015 (APA 2014). Operator Equinor and Total E&P Norge are 50/50 partners in the license, which consists of parts of Blocks 26/2 and 31/11. Petrobras, ExxonMobil Hit Hydrocarbons at Urissanê Well, Offshore Brazil Brazilian state-owned Petrobras announced on 29 January it had discovered hydrocarbons in a well located in the Campos Basin presalt off Brazil’s coast of Campos dos Gotyacaze in the State of Rio de Janeiro. Well 1-BRSA-1377-RJS (informally called Urissanê) is located in Block C-M-411, at a depth of 2950 m approximately 200 km offshore. Petrobras, which operates the block in a 50/50 partnership with Exxon Mobil, said it would analyze the well data to better target exploratory activities and assess the potential of the discovery. BP Offloads 20% Share of Oman’s Block 61 To PTTEP Marking another significant step in its divestment program, BP will sell a 20% participating interest in Oman’s 3950 km2 Block 61 in central Oman to Thailand’s national PTT Exploration and Production (PTTEP) for $2.59 billion. BP will remain operator of the block, holding a 40% interest. The sale comprises $2.45 billion payable on completion and $140 million payable contingent on preagreed conditions. After the sale, BP will hold 40% interest in Block 61, while OQ holds 30%, PTTEP 20%, and Petronas 10%. Block 61 contains the largest tight gas development in the Middle East.
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Key, KHL, and RV Southcott. "Host Relations and Distribution of Australian Species of Trombella (Acarina, Trombellidae) Parasitizing Grasshoppers." Australian Journal of Zoology 34, no. 4 (1986): 647. http://dx.doi.org/10.1071/zo9860647.
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The geographical distribution and host relations of the five species of Trombella parasitising adult 'short- horned' grasshoppers in Australia are described on the basis of data derived from a screening of tens of thousands of grasshoppers in the Australian National Insection Collection and covering 133 localities and 335 individual hosts in 79 species. Most of the data refer to T. cucumifera Southcott, which occupies a large region across northern Australia, where it is sympatric with T. fusiformis Southcott, and extending south into New South Wales. T. rugosa Southcott and T. sternutor Southcott are sympatric in the south- west of Western Australia. T. calabyi Southcott is represented by a single specimen from the arid east-Pilbara area of Western Australia. Host species are listed for each species of mite. Eumastacidae and Tetrigidae appear not to be attacked, but within the other two Australian families (Pyrgomorphidae and Acrididae) representatives of all of the five Australian subfamilies serve as hosts. For T. cucumifera, attack rates of 20-67% of the captured samples of some species of those families were recorded at some localities. There is a suggestion that the most abundant of the geophilous grasshoppers present at any locality may be favoured and that the species of Trombella do not differ in their utilisation of the grasshopper species accessible to them. There is no evidence of sex bias in host selection. The most common number of mites found on a single host individual is one in the three mite species with adequate data; it ranges up to 11, but numbers above five are rare. All species are attached almost exclusively to the membrane between prosternum and mesosternum of the host, or the membranous insertion of coxa 111.
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Blain, Nicholas. "Federal and State Unions in Western Australia." Journal of Industrial Relations 27, no. 2 (June 1985): 207–32. http://dx.doi.org/10.1177/002218568502700205.
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Duffy, Norman F. "The Genesis of Arbitration in Western Australia." Journal of Industrial Relations 28, no. 4 (December 1986): 545–63. http://dx.doi.org/10.1177/002218568602800405.
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The use of compulsory arbitration for the determination of the conditions of employment has a long history in Australia. This paper covers the events leading up to the introduction of legislation for conciliation and for the compulsory arbitration of industrial disputes in Western Australia. After two bruising strikes and the experience of successful voluntary arbitration, the union movement came to the view that compulsory arbitration would be to their advantage. The development of political links between the unions and some members of the Legislative Assembly, coupled with certain fortuitous circumstances in the Parliament, resulted in arbitration legislation being passed in 1900—despite the dominance of the political scene by conservative forces and the opposition of the employers. Early experiences with the legislation showed that conciliation was not successful when arbitration was readily available and that the Act was not the answer to all the problems of the trade union movement.
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Preston, Alison, and Elisa Birch. "The Western Australian wage structure and gender wage gap: A post-mining boom analysis." Journal of Industrial Relations 60, no. 5 (October 31, 2018): 619–46. http://dx.doi.org/10.1177/0022185618791589.
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Whilst there is a large literature on the determinant of wages in Australia, relatively few studies have examined the determinants of wages at a state level. In this article, we present a study of the determinants of earnings in Western Australia, a state that experienced rapid growth during the mining boom of 2003–2013. We show that the relatively stronger wage growth in Western Australia since 2001 is the product of both compositional and price effects. We also report on the Western Australia and rest of Australia gender wage gaps. Our decomposition analysis of the mean gender wage gap shows that industry effects (as a result of gender segmentation across industry) account for a much larger share of the Western Australia gender wage gap than they do elsewhere in Australia, with the mining, construction and transport sectors driving the industry effects. Using quantile analysis we show that, relative to the rest of Australia, the Western Australia gender wage gaps are larger at both the bottom and the top of the wage distribution. At the median the Western Australia gender wage gap, at 2014–2016, is on par with that prevailing elsewhere in Australia, with women in both groups earning 10% less than their male counterparts, all else held equal.
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Sherington, Geoffrey, Anne Atkinson, John Lack, Jacqueline Templeton, and Katharine Betts. "Asian Immigrants to Western Australia: Bicentennial Dictionary of Western Australia, Vol. V." Labour History, no. 58 (1990): 113. http://dx.doi.org/10.2307/27508996.
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Plowman, David H., and Genevieve Calkin. "The Origins of Compulsory Arbitration in Western Australia." Journal of Industrial Relations 46, no. 1 (March 2004): 53–83. http://dx.doi.org/10.1111/j.0022-1856.2004.00126.x.
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Brocx, M., and V. Semeniuk. "The development of solar salt ponds along the Pilbara Coast, Western Australia – a coastline of global geoheritage significance used for industrial purposes." Geological Society, London, Special Publications 419, no. 1 (2015): 31–41. http://dx.doi.org/10.1144/sp419.18.
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Warren-Langford, P., D. R. Biggins, and M. Phillips. "Union Participation in Occupational Health and Safety in Western Australia." Journal of Industrial Relations 35, no. 4 (December 1993): 585–606. http://dx.doi.org/10.1177/002218569303500405.
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Fossette, Sabrina, Graham Loewenthal, Lauren R. Peel, Anna Vitenbergs, Melanie A. Hamel, Corrine Douglas, Anton D. Tucker, Florian Mayer, and Scott D. Whiting. "Using Aerial Photogrammetry to Assess Stock-Wide Marine Turtle Nesting Distribution, Abundance and Cumulative Exposure to Industrial Activity." Remote Sensing 13, no. 6 (March 15, 2021): 1116. http://dx.doi.org/10.3390/rs13061116.
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The lack of accurate distribution maps and reliable abundance estimates for marine species can limit the ability of managers to design scale-appropriate management measures for a stock or population. Here, we tested the utility of aerial photogrammetry for conducting large-scale surveys of nesting marine turtles at remote locations, with a focus on the flatback turtle (Natator depressus) in the Pilbara region of Western Australia. Aerial surveys were conducted between 29 November and 6 December 2016 to overlap with the peak nesting season for flatback turtles and collected imagery was used to examine marine turtle distribution, abundance, and cumulative exposure to industrial activity relative to overlap with protected areas. Two observers independently reviewed aerial georeferenced photographs of 644 beaches and recorded turtle tracks and other evidence of turtle nesting activity. A total of 375 beaches showed signs of nesting activity by either flatback, green (Chelonia mydas) or hawksbill (Eretmochelys imbricata) turtles. Most of these beaches (85.3%) were located on islands, and the rest (14.7%) on the mainland. Half (n = 174) of the active beaches showed evidence of fresh (0–36 h. old) flatback nesting activity, with track abundance varying from 1.0 to 222.0 tracks·night−1. Six rookeries accounted for 62% of the Pilbara flatback stock. Remarkably, 77% of identified flatback rookeries occurred within protected areas. However, one-third (34%) of those were also located within 5 km of a major industrial site, including eight of the highest abundance beaches (50–250 tracks·night−1). Several key rookeries were also identified as being relatively unexposed to industry-related pressures but currently unprotected, highlighting the need for a cumulative impact assessment to be completed for this flatback stock. Finally, our aerial tallies and multiple ground-survey flatback track tallies were highly correlated and together with low intra- and inter-observer errors suggested that reliable data can be collected via aerial photogrammetry for nesting marine turtles. Such large-scale digitized surveys can therefore be used to assess the cumulative exposure of marine turtles to pressures, and to reveal new conservation opportunities.
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McCrystal, Shae, and Belinda Smith. "Industrial Legislation in 2010." Journal of Industrial Relations 53, no. 3 (June 2011): 288–302. http://dx.doi.org/10.1177/0022185611402004.
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Two themes in legislative activity in 2010 were national uniformity and some movement in using law to promote equality, especially gender equality. The Fair Work Act 2009 (Cth) came into full effect with the commencement of the new safety net provisions and the referral to the Commonwealth of industrial relations powers over private-sector workforces in all states except Western Australia. Progress continued on the promised harmonization of Australian occupational health and safety laws with the release of a model Work Health and Safety Bill by Safe Work Australia, although developments in some states threaten to derail the process. An attempt to repeal most of the industry-specific regulation of the building and construction industry failed. The Federal Parliament passed legislation establishing a national paid parental leave scheme, and a number of changes to federal discrimination laws came into effect or were proposed, including the potential consolidation of federal discrimination legislation. This article provides an overview of these developments at federal level and concludes with a discussion of developments in the states including a brief overview of Victoria’s new equal opportunity legislation.
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Love, Peter E. D., Peter R. Davis, and Denis Worrall. "Occupational Licensing of Building Trades: Case of Western Australia." Journal of Professional Issues in Engineering Education and Practice 136, no. 4 (October 2010): 215–23. http://dx.doi.org/10.1061/(asce)ei.1943-5541.0000021.
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Reekie, Gail. "Industrial Action by Women Workers in Western Australia during World War II." Labour History, no. 49 (1985): 75. http://dx.doi.org/10.2307/27508752.
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Alexis Vassiley. "Establishing Trade Unionism in the Emerging Iron Ore Mining Industry in Western Australia's Pilbara Region, 1965–72." Labour History, no. 115 (2018): 105. http://dx.doi.org/10.5263/labourhistory.115.0105.
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Lang, Helen. "The Stockpile Thesis and Industrial Relations at Kambalda." Journal of Industrial Relations 28, no. 3 (September 1986): 353–66. http://dx.doi.org/10.1177/002218568602800303.
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Some recent work on industrial relations in the Australian minirtg industry has focused on a close relationship between the incidence of strikes and the stockpiling of the mineral mined. It is argued that when demand for a mineral falls and the stockpile grows, management can afford the disruption to production caused by strikes. Hence management will take action to provoke strikes by introducing changes in work practices it knows will be opposed by unionists. Not only are the unions more likely to be defeated, but the company concerned is also able to reduce the size of its stockpile of ore. A case-study of the nickel-mining centre of Kambalda in Western Australia suggests that the size of the stockpile isfar less relevant when management and unions have a consensual approach to industrial relations. The stockpile is a strategic variable rather than a cause of industrial disputes. Whether the stockpile is manipulated as part of management's strategy will depend on innumerable, interdependent factors, including the organization of social life in a mining town and whether effective co operative relations develop between managers and unions.
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Saunders, Kay, and Jenny Gregory. "On the Homefront: Western Australia and World War II." Labour History, no. 77 (1999): 241. http://dx.doi.org/10.2307/27516690.
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Sgrò, Silvana. "Health workforce policy and industrial relations in Australia: ministerial insights into challenges and opportunities for reform." Australian Health Review 38, no. 4 (2014): 471. http://dx.doi.org/10.1071/ah14027.
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Since the Productivity Commission released its research report Australia’s Health Workforce in 2005, there has been a significant increase in government funding and policy capacity aimed at health workforce reform and innovation in Australia. This research paper presents the results of semistructured interviews with three key stakeholders in health policy formation in Australia: (1) The Honourable Lindsay Tanner, former Federal Minister for Finance and therefore 100% shareholder of Medibank Private on behalf of the Commonwealth; (2) The Honourable Daniel Andrews, former Victorian Minister for Health and current Victorian Opposition Leader; and (3) The Honourable Jim McGinty, former Minister for Health and Attorney General of Western Australia and current inaugural Chair of Health Workforce Australia. The paper examines key issues they identified in relation to health workforce policy in Australia, particularly where it intersects with industrial relations, and conducts a comparative analysis between their responses and theoretical methodologies of policy formation as a means of informing a reform process. What is known about the topic? Australia is experiencing an increasing demand for ever-improving health services and outcomes from an increasingly health-literate public, coupled with significant workforce shortages across some key categories of healthcare professionals. Health costs are also increasing. As a result governments in all nine jurisdictions in Australia are seeking to rein in those costs without negatively impacting on quality, safety or continued improvements in health outcomes. They are simultaneously seeking to minimise any political controversy or negative electoral repercussions associated with health reform. What does this paper add? This paper further informs an understanding of how health workforce policy is formulated and implemented by presenting the results of interviews with two former Ministers for Health and the former Federal Finance Minister on health workforce policy reform in Australia. It analyses their responses and their decision-making processes against theoretical frameworks of health policy formation, including agenda setting, and the political reality of policy formation at a ministerial level. What are the implications for practitioners? This paper provides a unique and original analysis for practitioners of policy formation. It also illustrates and analyses ministerial insights into the current health workforce reform agenda being developed and implemented by the Council of Australian Governments and contributes to an evidence base of the reform process going forward.
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FISCHER, GERHARD. "‘Enemy Labour’: Industrial Unrest and the Internment of Yugoslav Workers in Western Australia during World War I." Australian Journal of Politics & History 34, no. 1 (April 7, 2008): 1–15. http://dx.doi.org/10.1111/j.1467-8497.1988.tb00790.x.
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Robbins, W. M., and Andrew Gill. "Convict Assignment in Western Australia: The Parkhurst 'Apprentices', 1842-1851." Labour History, no. 88 (2005): 245. http://dx.doi.org/10.2307/27516048.
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Wright, Christopher. "Book Reviews : A History of the Abeu in Western Australia, 1921-1981: Federation—Sweet and Sour." Journal of Industrial Relations 31, no. 2 (June 1989): 280–81. http://dx.doi.org/10.1177/002218568903100218.
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Stevens, Simon. "A Social Tyranny: The Truck System in Colonial Western Australia, 1829-99." Labour History, no. 80 (2001): 83. http://dx.doi.org/10.2307/27516771.
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González Zarandona, José Antonio. "Towards a Theory of Landscape Iconoclasm." Cambridge Archaeological Journal 25, no. 2 (April 23, 2015): 461–75. http://dx.doi.org/10.1017/s0959774314001024.
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‘Landscape: the land escapes (1) when we try to seize it with our maps, satellites, geographic information systems and Street Views, land is what evades our surveillance (2) land is the terrain of escape.’ (Cubitt 2012)‘Since the middle of the twentieth century, the claim that something is art does not imply what it might have meant at the end of the nineteenth century, when it was made out to be a hallmark of European high and bourgeois society.’ (Heyd 2012, 287)The destruction of Indigenous rock art sites in the Pilbara district in Western Australia has become a natural sight within the mining landscape of the area. Whilst much of the destruction is explained as acts of vandalism and as a result of the industrial activities that are propelling the Australian economy, I claim that a new theory of iconoclasm is needed to explain fully this disastrous example of heritage conservation. Henceforth, in order to explain the destruction of the Murujuga/Burrup Peninsula petroglyphs, the largest archaeological site in the world, this paper develops the theory of landscape iconoclasm. This theory states that the destruction of Indigenous landscapes can be compared to the destruction of religious images, by analysing the inherent symbolic functions of iconoclasm, together with those of heritage, the better to elucidate the state of affairs in the Murujuga/Burrup Peninsula. Furthermore, by drawing from Aboriginal mythology and art-historical and anthropological theories, the theory of landscape iconoclasm is able to explain the destruction of archaeological sites within a framework that falls outside prevalent discourses of heritage.
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O'Connor, Tamsin, and Andrew Gill. "Forced Labour for the West: Parkhurst Convicts 'Apprenticed' in Western Australia, 1842 - 1851." Labour History, no. 77 (1999): 239. http://dx.doi.org/10.2307/27516689.
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Oliver, Bobbie. "'Lives of Misery and Melancholy': The Rhetoric and Reality of Industrial Reform in Post-World War I Western Australia." Labour History, no. 73 (1997): 105. http://dx.doi.org/10.2307/27516505.
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Paisley, Fiona, and Penelope Hetherington. "Settlers, Servants and Slaves: Aboriginal and European Children in the Nineteenth-Century in Western Australia." Labour History, no. 85 (2003): 253. http://dx.doi.org/10.2307/27515946.
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Oliver, Bobbie. "“No Place for Tourists”: Deaths on Western Australian Construction Sites." Labour History: Volume 119, Issue 1 119, no. 1 (November 1, 2020): 115–42. http://dx.doi.org/10.3828/jlh.2020.21.
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The deaths of three young “backpackers” on Perth building sites is the starting point for this investigation of an industry that is ranked the third most dangerous in Western Australia. All were on a working holiday. They were unskilled, untrained and underpaid, revealing aspects of the construction industry since the beginning of the twenty-first century. The article suggests these fatalities are occurring, despite OHS reforms and mandatory training, because the decline of trade union rights and presence on work sites has led to inadequate policing and enforcement of safety measures. Deregulation and employers’ over-emphasis on productivity have resulted in an unskilled, casual workforce and a culture of blaming individual employees rather than management, which has created a climate of fear where those who draw attention to safety breaches risk losing their jobs. The article considers arguments for introducing industrial manslaughter legislation, but the evidence suggests that the most effective solutions are to restore union rights. This would encourage a culture in which workers have a voice, and pointing out safety breaches on sites could be rewarded, rather than penalised.
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McCorquodale, John. "The Myth of Mateship: Aborigines and Employment." Journal of Industrial Relations 27, no. 1 (March 1985): 3–16. http://dx.doi.org/10.1177/002218568502700101.
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Historically, Aborigines have suffered legislative restrictions and discrimination in every phase of employment, from the kind of work they could lawfully undertake, to wages, accommodation and workers compensation. Unions have offered little or no support to black workers, and employers have been aided by court decisions based on racist stereotypes. Legislation enshrined unconscionable employment practices by government and private employers alike. An examination of all relevant legislation for Western Australia and New South Wales from the earliest times reveals a perpetuation of economic injustice against Aboriginal workers. All major Concilia tion and Arbitration Commission decisions between 1922 and 1968 on Aborigines- as-workers are analysed and reveal judicial bias. More recent examples of exploita tion are cited in support of the thesis that 'blood' or 'colour' alone were the criteria by which discrimination at the workface was practised and maintained.
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Smart, Judith, Bobbie Oliver, Kay Saunders, Margaret Bevege, and Joan Beaumont. "War and Peace in Western Australia: The Social and Political Impact of the Great War 1914-1926." Labour History, no. 73 (1997): 258. http://dx.doi.org/10.2307/27516528.
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Fieldes, Diane, and Tom Bramble. "Post-Fordism: Historical Break or Utopian Fantasy?" Journal of Industrial Relations 34, no. 4 (December 1992): 562–79. http://dx.doi.org/10.1177/002218569203400404.
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Since the mid-1980s there has been substantial debate about changes in the nature of production systems in Europe and North America. A range of writers, operating within a paradigm of post-Fordism, contend that traditional Western manufacturing methods, based on mass markets, mass production and Taylorism, are being replaced by strategies premised on niche markets, small-batch production and the upgrading of workforce skills and autonomy. In Australia it has been argued, chiefly by Mathews, that such changes have important implications for the labour movement. In particular, the new circumstances require a move from a confrontationist to a consensual approach to industrial relations by the trade unions. These claims are challenged in this article, both because of the determinist framework that informs them and because of their inability to explain the complexity of the changes that are taking place in the areas they address. An interpretation of recent developments, which places competitive accumulation at its centre, is suggested as an alternative paradigm. The implication that a post-Fordist strategy will reinforce the strength and integrity of the trade union movement is also questioned in the light of the later experience of the Accord.
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Feder, Judy. "Collaboration and Optimization Processes Contribute to Ultra-ERD Offshore Well Success." Journal of Petroleum Technology 73, no. 05 (May 1, 2021): 61–62. http://dx.doi.org/10.2118/0521-0061-jpt.
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This article, written by JPT Technology Editor Judy Feder, contains highlights of paper SPE 202251, “Transforming the Mindset To Drill Ultra-ERD Wells With High Tortuosity,” by Barry Goodin, SPE, Duane Selman, and Andy Wroth, Vermilion Oil and Gas, et al., prepared for the 2020 SPE Asia Pacific Oil and Gas Conference and Exhibition, originally scheduled to be held in Perth, Australia, 20–22 October. The paper has not been peer reviewed. The complete paper describes the extensive integrated engineering collaboration and optimization process that allowed an operator to push the drilling and completion envelope to drill a pair of complex, ultra-extended-reach-drilling (ERD) wells in the mature Wandoo field in the Carnarvon Basin offshore Western Australia. The shallow reservoir depth, extreme ERD profile, and high tortuosity requirement for the wells posed significant challenges. These were overcome with extensive planning; integrated engineering designs; application of new technology; good-quality, real-time data interpretation; and strong execution support from both rig site and town. Introduction The Wandoo field, in 56 m of water off-shore Western Australia, was discovered in 1991 and subsequently developed and placed on production in 1993. The shallow unconsolidated sandstone reservoir consists of a heavily biodegraded oil column overlain by a gas cap and supported by a strong aquifer drive. Field infrastructure consists of a 15-well-slot manned production facility, Wandoo B, and a five-slot monopod, Wandoo A, which is tied back to Wandoo B by subsea in-field pipelines. In late 2018, the operator planned and executed a two-well drilling campaign consisting of two complex, ultra-ERD wells, Wandoo B15 and B16. Both wells were planned to be batch drilled for the top hole and intermediate hole sections, with the production hole sections to be drilled and completed sequentially. The primary objective for the B15 well was to recover unswept oil along the western flank of the field and track the well along the main Wandoo fault to the north to assess the structure and reserves from the northern tip of the field. The B16 well objective was to access unswept reserves through the center and down to the south of the field, essentially twinning the B11ST1 well, another ERD well drilled on an earlier campaign, to its eastern flank. To maximize recovery, both wells needed to be placed approximately 1 m below the top of the reservoir, except where overlain by the gas cap, in which case the wells were to be placed approximately 2 m below the gas/oil contact to avoid gas coning. Drilling Challenges and Solutions The first half of the complete paper presents a detailed discussion of the drilling challenges and solutions, illustrated with schematics, maps, charts, and graphs. Both Wells B15 and B16 were classified as ultra-ERD wells because the shallow true vertical depth (TVD) of the reservoir resulted in extreme stepout ratios and required highly complex well paths to access the remaining reserves. The complete paper lists various specific drilling- and systems-related challenges.
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Markey, Raymond, and Bobbie Oliver. "Unity is Strength: A History of the Australian Labor Party and the Trades and Labor Council in Western Australia, 1899-1999." Labour History, no. 88 (2005): 257. http://dx.doi.org/10.2307/27516056.
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Oliver, Bobbie. "'In the Thick of Every Battle for the Cause of Labor': The Voluntary Work of the Labor Women's Organisations in Western Australia, 1900-70." Labour History, no. 81 (2001): 93. http://dx.doi.org/10.2307/27516805.
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Uddin, Nasir. "Inter-organizational relational mechanism on firm performance." Industrial Management & Data Systems 117, no. 9 (October 16, 2017): 1934–53. http://dx.doi.org/10.1108/imds-03-2016-0093.
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Purpose The purpose of this paper is to explore how structural and economic issues of organising inter-firm relationships influence a supply chain (SC) performance, by using the insight of organisational theories and institutional economics. Design/methodology/approach The study is an exploratory field study in the Australian agri-food industries. Using a conceptual model and a set of semi-structured interview questions, data collection was done through in-depth interviews with eight agri-food firms from the agri-food SCs in Western Australia (WA). Findings The findings demonstrated the requirement of higher coordination and integration from the downstream industries to include upstream producers as the integral part of the SC. Research limitations/implications The study is based on eight in-depth interviews on cross-sectional food SCs in WA and generalises the result for the overall food industry in WA. Originality/value The study provides valuable information to the existing literature on industrial management and has important value to the users of agri-food SCs. It provides empirical evidence of the factors of SC performance for agri-food producers, processors and retailers, other stakeholders and government agencies for their planning and benchmarking.
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Oliver, Bobbie. "'Rats', 'Scabs', 'Soolers' and 'Sinn Feiners': A Re-Assessment of the Role of the Labour Movement in the Conscription Crisis in Western Australia, 1916-17." Labour History, no. 58 (1990): 48. http://dx.doi.org/10.2307/27508982.
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Carpenter, Chris. "New Monoethylene-Glycol Sensor Validated by Flow Loop Under Hydrate-Forming Conditions." Journal of Petroleum Technology 73, no. 08 (August 1, 2021): 49–50. http://dx.doi.org/10.2118/0821-0049-jpt.
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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 202375, “Validation of a Novel MEG Sensor Employing a Pilot-Scale Subsea Jumper,” by Asheesh Kumar, The University of Western Australia; Mauricio Di Lorenzo, SPE, CSIRO Energy; and Bruce W.E. Norris, SPE, The University of Western Australia, et al., prepared for the 2020 SPE Asia Pacific Oil and Gas Conference and Exhibition, originally scheduled to be held in Perth, Australia, 20–22 October. The paper has not been peer reviewed. Online pipeline-management systems provide real-time and look-ahead functionality for production networks. They are limited, however, by a dearth of data with which to inform their predictions. This represents a barrier to a true, high-fidelity digital twin. Greater integration with new sensor technologies is needed to bound model predictions and improve their reliability. In this work, the authors present a novel monoethylene-glycol (MEG) sensing system and validate it in a specially constructed flow loop. Introduction Subsea jumpers experience a high probability of hydrate blockages. The most common practice used to avoid hydrate formation in subsea wellhead jumpers essentially is based on the injection of thermodynamic hydrate inhibitors such as MEG and methanol at high flow rates to flush out and inhibit the water pooled in the low spots of the jumper spools. Such hydrate management operations in deep water require adequate planning to minimize unproductive time and may not be feasible in unplanned well shutdowns. To improve the models implemented in current sensing technologies and explore their potential for new functionalities to detect hydrate formation, measurements under realistic field conditions in a controlled environment are vital. In this work, a flow loop that replicates the geometry of industrial subsea jumpers was deployed to investigate the performance of a new MEG sensor for subsea applications under hydrate-forming conditions. Preliminary baseline experiments were performed at steady state and during gas-restart operations in the absence of any hydrates in the jumper flow loop. Experiments were performed at 64.4°F with nitrogen (N2) gas at 1,200 psig and superficial gas velocity ranges from 0.82 to 2.88 ft/s. The MEG-sensing system’s performance was investigated under hydrate-forming conditions with and without MEG (10–30 wt% in water) in the jumper test section. These experiments were performed at temperatures ranging from 25.2 to 35.6°F. Experimental Flow Loop The flow loop consists of a test section connected to independent gas and liquid injection equipment at the inlet and gas-separation facilities at the outlet, which allows for continuous recirculation of gas and a once-through pass of the liquid. The test section has a complex geometry, with three identical low points (LPs) and two high points. The horizontal length of each low and high points is 12 ft, 10 in., and 7 ft, 7 in., respectively, and total height is 13 ft, 2 in. The test section is equipped with 12 pressure and temperature sensors distributed at regular intervals, a MEG sensor at the second LP, a throttling valve downstream of the first high point to mimic a wellhead choke, and a viewing window at the outlet.
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Carpenter, Chris. "Technology Focus: Extended-Reach and Complex Wells (May 2021)." Journal of Petroleum Technology 73, no. 05 (May 1, 2021): 58. http://dx.doi.org/10.2118/0521-0058-jpt.
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In selecting papers for this feature, reviewer Stéphane Menand of Helmerich and Payne has identified a trio of papers that investigates new approaches toward familiar issues encountered when drilling complex well types. Whether considering the customization of drilling approaches in Middle Eastern carbonate reservoirs, implementing a collaborative work flow in tackling high-tortuosity wells offshore Western Australia, or researching the ability of a fibrous material to effect hole cleaning as opposed to polymeric sweeps, the authors of these papers understand that technical expertise may not be completely realized if it is not applied to problems in original ways. In carbonate reservoirs, the goal of drilling extended-reach wells is set against the geological makeup of such formations, the complexity of which adds significant uncertainty to geosteering and well placement. The authors of paper SPE 203335 develop a work flow that makes possible the customization of drilling scenarios through an emphasis on mechanical specific energy, as well as the use of an optimized borehole-assembly design. The work flow helped deliver what the authors write is the longest well in the Middle East offshore Abu Dhabi. In a similar vein, the authors of paper SPE 202251 describe a challenging scenario involving an ultraextended-reach well in a mature field offshore Western Australia. The project overcame shallow water depth and a high tortuosity requirement by implementing an integrated plan that used a reservoir-mapping-while-drilling service. The authors stress that this technology, coupled with active collaboration between specialists, town, and rig site, allowed the project to achieve the desired oil-column thickness with zero collision incidents. Highly deviated wells often face problems resulting from ineffective hole cleaning. Paper SPE 203147 studies the properties of a fibrous material when compared with the hole-cleaning performance of common polymeric pills. The authors write that the fibrous material proved effective, in part because of a unique characteristic in which a spiderweb-like network of fibers is created that does not allow cuttings to settle easily in complex wells. In addition, the material is environmentally friendly. All three papers approach well- established problems in the critical industry sector of extended-reach drilling with innovation and confidence. Enjoy the papers and be sure to search SPE’s OnePetro online library for more fresh approaches to the technical challenges posed by these well types. Recommended additional reading at OnePetro: www.onepetro.org. SPE 196410 - Analysis of Friction-Reduction System During Drilling Operation at a High-Inclination Well on Field X by Rizqiana Mudhoffar, Tanri Abeng University, et al. SPE 197257 - Successful Management of Collision Risk in an Extended-Reach Well by Manchukarn Naknaka, Mubadala Petroleum, et al. SPE 202730 - Challenges in Drilling and Completion of Extended-Reach-Drilling Wells With Landing Point Departure of More Than 10,000 ft in Light/Slim Casing Design by Nitheesh Kumar Unnikrishnan, Abu Dhabi National Oil Company, et al.
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Carpenter, Chris. "Reservoir Characterization, Scenario-Based Models Optimize Development Planning." Journal of Petroleum Technology 73, no. 07 (July 1, 2021): 48–49. http://dx.doi.org/10.2118/0721-0048-jpt.
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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 202273, “Reservoir Characterization and Scenario-Based Modeling To Optimize Development Planning of the Jurassic Plover Formation in the Ichthys Field, North West Shelf of Australia,” by Kazuyuki Yamamoto, SPE, Shuji Yamamoto, and Toby Jones, INPEX, et al., prepared for the 2020 SPE Asia Pacific Oil and Gas Conference and Exhibition, originally scheduled to be held in Perth, Australia, 20–22 October. The paper has not been peer reviewed. The Plover Formation is one of two reservoirs in the Ichthys field of the Australian North West Shelf. The objective of this study is to build multiple scenario-based models to optimize development planning in preparation for the upcoming production phase. The authors have integrated data and interpretations of thin sections, cores, well logs, and seismic data to create multiple geological concepts for the field and to identify key geological uncertainties. Introduction The Ichthys liquefied natural gas project is one of the world’s largest and involves the development of a gas-condensate field in the Browse Basin. The field is approximately 220 km offshore Western Australia and covers an area of approximately 800 km2 with an average water depth of approximately 250 m. The field is currently under preparation for the development of the Plover Formation. The authors conducted an integrated subsurface evaluation and built reservoir models with newly reprocessed 3D seismic data to optimize Plover development planning. Considering the geological uncertainty given the limited production data gathered before the production phase, the multiple deterministic approach was selected as the best option to optimize development planning. In this approach, it is important to capture all geological scenarios that may occur in the field and to build reservoir models in which the scenario concepts are explicitly integrated. A multidisciplinary team was organized to conduct this study. Geology of the Plover Formation The Plover Formation consists of sandstones, shales, igneous rocks, and a minor amount of coal. The depositional environment is fluvial to shallow marine. The average thickness of the formation is approximately 360 m. Based on the stratigraphic correlation anchored by mainly palynological biostratigraphic data, the formation has been subdivided into five stratigraphic members. The formation is overlain by the Ichthys Formation, which is composed mainly of argillaceous sandstone and shale deposited in a tidally influenced, lower-delta-to-shelf environment. Although the nine existing exploration wells broadly cover the entire field, the spacing between the wells is still large (8–10 km). Further-more, core coverage is low, especially in the reservoir sandstone intervals. Igneous rock, predominantly basaltic in composition and likely extrusive in origin, occurs more in the eastern part of the field. Igneous activity has complicated the distribution and connectivity of the reservoir sandstones in the Ichthys field. Key Geological Uncertainties Rock Type (RT). The results of petrographic analysis of rock samples from the Ichthys field and other surrounding fields indicate that the sandstones of the Plover Formation can be separated into multiple RTs: RT1 and RT2, with RT1 subdivided into RT1a and RT1b. Very little data exist from RT2 in the fluvial/distributary channel sandstones in the Ichthys field in comparison with other fields; this is considered to be the result of limited core. The assumption that RT2 exists in the field is critical to prepare for the possibility that a future well may be drilled that might have some nontrivial quantity of RT2.
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Carpenter, Chris. "Flow-Assurance-Management Strategy Considerations for a Deepwater Gas Field." Journal of Petroleum Technology 73, no. 05 (May 1, 2021): 49–50. http://dx.doi.org/10.2118/0521-0049-jpt.
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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 202254, “Flow-Assurance Challenges for China’s First Deepwater Gasfield Development in South China Sea,” by Lawrence Khin Leong Lau, Kun An, and Xian Di Tang, CNOOC, et al., prepared for the 2020 SPE Asia Pacific Oil and Gas Conference and Exhibition, originally scheduled to be held in Perth, Australia, 20–22 October. The paper has not been peer reviewed. The complete paper describes the key flow-assurance challenges for a deepwater gasfield development in the South China Sea and the considerations and steps taken to achieve an overall flow-assurance-management strategy. The discussion covers early-stage feasibility studies through the stage of project execution at the time of writing. In addition, flow-assurance analysis is highlighted as a key input for startup and commissioning guidelines as well as operating procedures. Project Background This gasfield development consists of a semisubmersible more than 100 km offshore in the South China Sea. The water depth is approximately 1500 m, with a minimum seabed temperature of less than 4°C. The design incorporates Eastern and Western production loops spanning more than 40 km of the subsea production system (SPS) in total. Line size for the Eastern and the Western production loops are selected according to the total of production wells located in respective areas. The entire production system, including topsides facilities, subsea flowlines, risers, and other key SPS elements such as subsea manifolds, is designed with potential future development tie-ins in mind. Long subsea tiebacks, coupled with typical deepwater characteristics, require a robust flow-assurance- management strategy. A dedicated flow-assurance team was assembled across sectors such as subsurface, drilling and completion (D&C); subsea umbilicals, risers, and flowlines (SURF); control and instrumentation; and topsides process engineering. During the feasibility-study stage, more than 10 deepwater subsea production wells were grouped by characteristics. Analysis was performed for the most-representative wells selected from each group during this development stage to determine the range of the operating envelope and to identify all related risks. As development progressed into the detailed engineering-design stage, a detailed flow-assurance-scope analysis was completed for each well to ensure full coverage. This analysis considered scenarios including well unloading, well testing, precommissioning, first gas, steady-state production, planned and unplanned shutdowns, and hot and cold restarts. Any risks identified were assigned mitigation strategies and then were incorporated into design philosophy and operating guidelines or were specifically detailed in operating procedures. Primary Flow-Assurance Challenges Region-Specific Flow-Assurance Challenges. Flow Assurance as an Independent and Integrated Discipline. The creation of a cross-disciplinary flow-assurance team differs significantly from previous management approaches in which flow-assurance scopes were embedded in different disciplines and managed separately by teams such as subsurface, D&C, SURF, and topsides. The team described in the paper had the goal of implementing flow-assurance design and strategy with a truly integrated approach to maximize efficiency, optimize costs, and minimize impact on the environment.
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Carpenter, Chris. "Inversion of Full Waveform Sonic Data Assists Calibration of Geomechanics Model." Journal of Petroleum Technology 73, no. 09 (September 1, 2021): 39–40. http://dx.doi.org/10.2118/0921-0039-jpt.
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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 202260, “Inversion of Advanced Full Waveform Sonic Data Provides Magnitudes of Minimum and Maximum Horizontal Stress for Calibrating the Geomechanics Model in a Gas Storage Reservoir,” by Zachariah J. Pallikathekathil, SPE, Xing Wang Yang, and Saeed Hafezy, Schlumberger, et al., prepared for the 2020 SPE Asia Pacific Oil and Gas Conference and Exhibition, originally scheduled to be held in Perth, Australia, 20–22 October. The paper has not been peer reviewed. In 1D geomechanics projects, calibration of stress is extremely important in the construction of a valid mechanical earth model (MEM). The effective minimum horizontal stress (Shmin) data usually are available from traditional measurements, but these have a few deficiencies. The complete paper presents a technique for deriving stresses in which the radial variation of acoustic velocity from an advanced dipole sonic logging tool is inverted to obtain stress. These derived stresses are then used to calibrate the 1D MEM for a gas storage field. Regional Geology The field is in the Otway Basin in Western Victoria. Gas is trapped in the Late Cretaceous Waarre formation at depths between 1155 and 1200 m subsea. The reservoir is sealed by the overlying marine Belfast mudstone, which is the common seal in the stratigraphy across the onshore Otway Basin. The reservoir has excellent reservoir quality and has proved ideal for gas storage. Challenge Posed by the 1D MEM Challenge Posed by the 1D MEM Well 1 was recently drilled in the basin. A 1D MEM - a numerical representation of the geomechanical properties and stress state of the earth at any depth - was planned to be constructed to obtain the current-day far-field principal stresses (Shmin), effective maximum horizontal stress (SHmax), and effective vertical stress (SV)] in the Belfast and Waarre formations. Understanding the stress field was important, especially in the caprock (Belfast) and in the reservoir (Waarre) so that the pressure limits for safe gas-storage operation could be defined better. However, for a variety of reasons, no conventional stress measurements were available to calibrate the modeled stress in the 1D MEM. Without any calibration of the stress, the geomechanics model would feature high uncertainty to be used to define the pressure operational limits for gas-storage operation. Fortunately, a new wireline sonic tool was recorded in the reservoir section and the overburden sections of the borehole in Well 1. A quick dispersion analysis of the waveforms showed that the Paaratte formation, above the Belfast formation, was acoustically stress-sensitive and that advanced processing could be performed to invert the acoustic information to stress values.
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Oruganti, Yagna. "Technology Focus: Data Analytics (October 2021)." Journal of Petroleum Technology 73, no. 10 (October 1, 2021): 60. http://dx.doi.org/10.2118/1021-0060-jpt.
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With a moderate- to low-oil-price environment being the new normal, improving process efficiency, thereby leading to hydrocarbon recovery at reduced costs, is becoming the need of the hour. The oil and gas industry generates vast amounts of data that, if properly leveraged, can generate insights that lead to recovering hydrocarbons with reduced costs, better safety records, lower costs associated with equipment downtime, and reduced environmental footprint. Data analytics and machine-learning techniques offer tremendous potential in leveraging the data. An analysis of papers in OnePetro from 2014 to 2020 illustrates the steep increase in the number of machine-learning-related papers year after year. The analysis also reveals reservoir characterization, formation evaluation, and drilling as domains that have seen the highest number of papers on the application of machine-learning techniques. Reservoir characterization in particular is a field that has seen an explosion of papers on machine learning, with the use of convolutional neural networks for fault detection, seismic imaging and inversion, and the use of classical machine-learning algorithms such as random forests for lithofacies classification. Formation evaluation is another area that has gained a lot of traction with applications such as the use of classical machine-learning techniques such as support vector regression to predict rock mechanical properties and the use of deep-learning techniques such as long short-term memory to predict synthetic logs in unconventional reservoirs. Drilling is another domain where a tremendous amount of work has been done with papers on optimizing drilling parameters using techniques such as genetic algorithms, using automated machine-learning frameworks for bit dull grade prediction, and application of natural language processing for stuck-pipe prevention and reduction of nonproductive time. As the application of machine learning toward solving various problems in the upstream oil and gas industry proliferates, explainable artificial intelligence or machine-learning interpretability becomes critical for data scientists and business decision-makers alike. Data scientists need the ability to explain machine-learning models to executives and stakeholders to verify hypotheses and build trust in the models. One of the three highlighted papers used Shapley additive explanations, which is a game-theory-based approach to explain machine-learning outputs, to provide a layer of interpretability to their machine-learning model for identification of identification of geomechanical facies along horizontal wells. A cautionary note: While there is significant promise in applying these techniques, there remain many challenges in capitalizing on the data—lack of common data models in the industry, data silos, data stored in on-premises resources, slow migration of data to the cloud, legacy databases and systems, lack of digitization of older/legacy reports, well logs, and lack of standardization in data-collection methodologies across different facilities and geomarkets, to name a few. I would like to invite readers to review the selection of papers to get an idea of various applications in the upstream oil and gas space where machine-learning methods have been leveraged. The highlighted papers cover the topics of fatigue dam-age of marine risers and well performance optimization and identification of frackable, brittle, and producible rock along horizontal wells using drilling data. Recommended additional reading at OnePetro: www.onepetro.org. SPE 201597 - Improved Robustness in Long-Term Pressure-Data Analysis Using Wavelets and Deep Learning by Dante Orta Alemán, Stanford University, et al. SPE 202379 - A Network Data Analytics Approach to Assessing Reservoir Uncertainty and Identification of Characteristic Reservoir Models by Eugene Tan, the University of Western Australia, et al. OTC 30936 - Data-Driven Performance Optimization in Section Milling by Shantanu Neema, Chevron, et al.
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JPT staff, _. "E&P Notes (August 2022)." Journal of Petroleum Technology 74, no. 08 (August 1, 2022): 12–15. http://dx.doi.org/10.2118/0822-0012-jpt.
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Valaris Adds Fresh Rig Contracts to Backlog Valaris has scooped a number of new contracts and contract extensions, adding an associated $466 million to its contract backlog. The company received a 540-day contract with Equinor offshore Brazil for use of drillship Valaris DS-17. The rig will be reactivated for this contract, which is expected to begin in mid-2023. The total contract value is around $327 million, including an upfront payment totaling $86 million for mobilization costs, a contribution toward reactivation costs, and capital upgrades. The remaining contract value relates to the operating day rate and additional services. Also in Brazil, Valaris received a contract extension with TotalEnergies EP Brasil offshore Brazil for the use of drillship Valaris DS-15. The option is in direct continuation of the current firm program. “We are particularly pleased to have been awarded another contract for one of our preservation stacked drillships, Valaris DS-17, and look forward to partnering with Equinor on their flagship Bacalhau project in Brazil,” said Valaris Chief Executive Anton Dibowitz. “We expect Brazil to be a significant growth market for high-specification floaters over the next several years, and we are well positioned to benefit by now adding a third rig to this strategic basin.” The contractor also was awarded a two-well contract extension with Woodside offshore Australia for semisubmersible Valaris DPS-1. The two-well extension has an estimated duration of 38 days and will be in direct continuation of the existing firm program for Woodside’s Enfield plug-and-abandonment (P&A) campaign. The P&A work covers 18 wells in total. Woodside also awarded Valaris a separate one-well extension for the rig. The work has an estimated duration of 60 days with Woodside’s Scarborough development campaign. Elsewhere, Shell awarded a 4-year contract for heavy-duty modern jackup Valaris 115 offshore Brunei. The $159-million contract is expected to begin in April 2023. The contract was also awarded various short-term deals for jackups with Shell in the UK, an undisclosed operator in the Gulf of Mexico (GOM), Cantium in the GOM, and GB Energy offshore Australia. Shell Joins Equinor in GOM Sparta Development Shell has agreed to purchase 51% of Equinor’s interest in the North Platte deepwater development project in the US Gulf of Mexico (GOM). Equinor will retain 49% interest in the project, and Shell will become the new operator of the field. The new partners also have agreed to rename North Platte to Sparta. Sparta straddles four blocks of the Garden Banks area, 275 km off the coast of Louisiana in approximately 1300 m of water depth. Front-end engineering and design has been matured for the project. Equinor and Shell will review the work that has been completed and update the development plan. Shell said that Sparta aligns with its strategy to pursue upstream investments that can remain competitive over time, both from a financial and environmental-intensity perspective. North Platte was discovered by Cobalt Energy and Total in 2012. The partners said the Wilcox-aged discovery would require 20K-psi technology to develop. Cobalt went bankrupt in 2017 and its stake in the asset was sold to Equinor and Total. In early 2022, TotalEnergies walked away from the project and its operatorship to focus on other projects, leaving Equinor with 100% interest. BP Awarded King Mariout Block in Egypt’s West Med BP has been awarded the King Mariout exploration block offshore Egypt following its participation last year in the limited bid round organized by the Egyptian Natural Gas Holding Company. The King Mariout Offshore area is located 20 km west of the Raven field in the Mediterranean Sea and covers 2600 km2 with water depths ranging between 500 and 2100 m. The block is within the West Nile Delta area, for which material gas discoveries could be developed using existing infrastructure. BP holds a 100% stake in the block. BP is a major player in Egypt investing more than $35 billion in the area over the past 60 years. LLOG Begins Production From Spruance in GOM LLOG has kicked off production from its operated Spruance Field located in Ewing Bank Blocks 877 and 921 in the US GOM. The two-well subsea development is producing, in combination, approximately 16,000 B/D of oil and 13 MMcf/D via a 14-mile subsea tieback to the EnVen-operated Lobster platform in nearby Block 873. The Spruance Field was initially discovered by LLOG and its partners in mid-2019 via a subsalt exploratory well, the Ewing Bank 877 #1, which was drilled in 1,570 ft to a total depth of 17,000 ft and logged around 150 net ft of oil pay in multiple high-quality Miocene sands. A second well, the Ewing Bank 921 #1, was drilled from the same surface location as the discovery well to a total depth of 16,600 ft in early October 2020. The well delineated the main field pays and logged additional oil pay in the exploratory portion of the well, finding a total of more than 200 net ft of oil. LLOG is the operator of the Spruance Field and owns a 22.64% working interest with partners Ridgewood Energy (23.89%), EnVen (13.5%), Beacon Asset Holdings (11.61%), Houston Energy (11.2%), Red Willow (11.15%), and CL&F (6%). Egypt Signs Agreement With Chevron To Drill First Exploration Well in East Med Chevron is planning to drill the first exploration well in its concession area in the Eastern Mediterranean this September. The well plans come as Egyptian Natural Gas Holding signed a memorandum of understanding with the US-based producer to cooperate in transporting, importing, and exporting natural gas from the area. Chevron expanded its presence in the area following its $5-billion acquisition of Noble Energy in 2020. The two companies will evaluate options for natural gas transmission from the East Mediterranean to Egypt to optimize its value through liquefaction before re-exporting and selling it, according to the memorandum. In addition, the two firms will perform research on low-carbon natural gas. APA Suriname Campaign Offers Mixed Results APA Corporation successfully flow tested its Krabdagu exploration well (KBD-1) on Block 58 offshore Suriname, while its Rasper exploration well on Block 53 offered disappointing results. Flow-test data collected in the two lower intervals, the Upper Campanian (32 m of net oil pay) and Lower Campanian (32 m of net oil pay), indicate oil-in-place resources of approximately 100 million bbl and 80 million bbl, respectively, connected to the KBD-1 well. Appraisal drilling will be necessary to confirm additional resource and development-well locations, according to APA. The exploration well encountered another high-quality interval in the Upper Campanian that was not in a location suitable for flow testing. This shallower Campanian zone will need to be flow tested in the appraisal stage from a better location. The APA-TotalEnergies joint venture is currently drilling the Dikkop exploration well in the central portion of Block 58 with drilling rig Maersk Valiant. Following completion of operations at Dikkop, the rig is expected to continue exploration and appraisal activities in the central portion of Block 58. APA Suriname and operator TotalEnergies each hold a 50% working interest in the block. Meanwhile, APA’s Rasper well in Block 53 off Suriname encountered water-bearing reservoirs in the Campanian and Santonian intervals. The Noble Gerry de Souza drillship has been mobilized to the next exploration prospect, Baja, in the southwestern corner of Block 53. Baja lies 11 km northeast of the recently announced Block 58 discovery at Krabdagu and will test Maastrichtian and Campanian targets. APA Suriname, the operator, holds a 45% working interest in the block, Petronas holds a 30% working interest, and CEPSA a 25% working interest. Novatek JV Wins North Yarudeyskoye License Novatek’s Yargeo joint venture has won the license to survey, explore, and develop production at the North Yarudeyskoye oil and gas condensate field over the next 27 years. The license area is in the Yamal-Nenets autonomous region in the Arctic, Russia’s principal gas-producing area. North Yarudeyskoye holds an estimated hydrocarbon resource potential of 93.5 million BOE. The greater Yarudeyskoye field began producing in 2015 and by 2017 was responsible for nearly a third of Novatek’s liquids production. The company, Russia’s largest private natural gas producer, noted that it had participated in the recent auction to explore and develop North Yarudeyskoye through Gazprom Bank’s Electronic Trading Platform and that the win was Novatek’s first on that platform. PDC Energy Gets Green Light for Kenosha, Broe Developments The Colorado Oil and Gas Conservation Commission has approved PDC Energy’s Kenosha and Broe developments’ permit applications. The Kenosha development, which encompasses 69 wells on three pads in rural Weld County, Colorado, further increases PDC’s permitted inventory by another rig year and solidifies drilling and completion activity well into 2024. The Broe permit encompasses 30 wells in rural Weld County. The Broe plan was initiated by Great Western Petroleum, which was acquired by PDC in May 2022 and represents PDC’s first development plan approval on Great Western acreage. Combined with the Kenosha plan approval, PDC added 99 new wells to its inventory in June and will soon have more than 675 permits and drilled and uncompleted wells. Both fields are in the greater Wattenberg area. The new permits add to an already-established multiyear inventory of projects in the DJ Basin. Kenosha is the second oil and gas development plan to be approved, and the company anticipates further approvals with its Guanella area plan and others. PDC’s operations in the Wattenberg field are focused in the horizontal Niobrara and Codell plays. The Wattenberg represents PDC Energy’s largest asset with more than 85% of its 2021 production and 90% of its year-end 2021 proved reserves.
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JPT staff, _. "E&P Notes (July 2022)." Journal of Petroleum Technology 74, no. 07 (July 1, 2022): 11–15. http://dx.doi.org/10.2118/0722-0011-jpt.
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Transocean Harsh-Environment Rig Scoops Contract Extension Equinor extended Transocean’s contract for use of the harsh-environment semisubmersible Transocean Spitsbergen. The additional nine wells plus two, one-well options extension is valued at $181 million and is expected to begin in October 2023. The work will keep the rig busy off Norway until April 2025. In the fall of next year, the rig is scheduled to start drilling a trio of production wells for the Haltenbanken Vest Unit, which is part of the Kristin South area in the Norwegian Sea. Transocean Spitsbergen has been working consistently for Equinor since 2019. Equinor Wildcat Comes Up Empty Equinor will plug and abandon its Cambozola exploration well in License PL1049 offshore Norway after failing to encounter commercial hydrocarbons. Exploration well 34/9-1S was targeting Lower Cretaceous turbidite sand lobes in the northern North Sea and had the potential to be a play opener, according to well partner Longboat Energy. The exploration will continue with the Oswig and Copernicus wells, both expected to spud this summer. The Cambozola well was drilled to a total vertical depth of 4393 m using Odjfell Drilling semisubmersible Deepsea Stavanger. Background gas readings were recorded throughout the overlying section, but the well failed to encounter effective reservoir. Equinor is analyzing the data collected to understand the observed bright seismic amplitude anomaly and any remaining Lower Cretaceous prospectivity in the area. Longboat had previously referred to Cambozola as a potential play opener and one of the largest gas prospects to be drilled in Norway in 2022. Gross unrisked mean prospective resources for the entire Cambozola prospect have been estimated at 159 million BOE. Western Gas’ Sasanof-1 Exploration Well Disappoints Western Gas failed to encounter hydrocarbons with its Sasanof-1 exploration well offshore Western Australia. The well was drilled to a total depth of 2390 m by semisubmersible Valaris MS-1, but no gas reservoirs were intersected. The well will be permanently plugged and abandoned. The Sasanof prospect was estimated to hold 7.2 Tcf gas and 176 million bbl of condensate. The prospect was seen as potential supply for the NW Shelf LNG project. Vaalco Adds Reserves at Etame off Gabon Vaalco Energy encountered multiple hydrocarbon-bearing sands with its South Tchibala 1HB-ST well drilled from the Avouma platform in the Etame field offshore Gabon. The well struck 18 m of hydrocarbons in the Dentale D1 sand, which is analogous to the Deep Dentale producing field in North Tchibala with similar porosity and permeability. Another 15 m of hydrocarbons was intersected in the Dentale D9. The well will be completed in the D1 sand and was scheduled to be online in June, while the D9 will be cased for future completion. The well also penetrated a thin section of Gamba sand which will not be economically feasible to complete. Current Etame production is fed through the recently extended FPSO Petroleo Nautipa. Success with the South Tchibala 1HB-ST potentially adds new future drilling locations in the Deep Dentale trend across the Etame block. Eni, TotalEnergies Begin Drilling Off Cyprus Partners Eni and TotalEnergies have begun drilling a natural gas wildcat dubbed Cronos-1 in Block 6 offshore Cyprus. The well, originally planned for 2020, was derailed by the COVID-19 pandemic. Vantage Drilling drillship Tungsten Explorer is on location and is conducting the drilling operations. In 2018, the partnership struck gas at the Calypso well in another part of Block 6. That well proved that the carbonate play present in Eni’s Zoar field off Egypt extended to the Cypress exclusive economic zone. Zoar was discovered in 2015 and is the biggest gas discovery to date in the Mediterranean Sea. Calypso-1 was drilled to a total depth of 3827 m and encountered an extended gas column in Miocene- and Cretaceous-aged sands. Eni operates Block 6 with a 50% participation interest. TotalEnergies holds the remaining 50% stake. ADNOC Makes Three Onshore Discoveries Abu Dhabi National Oil Company (ADNOC) has unveiled three new oil discoveries including one at Bu Hasa, Abu Dhabi’s biggest onshore field, with a crude oil production capacity of 650,000 B/D. The discovery in Bu Hasa includes 500 million bbl of oil from an exploration well in the field. The second oil find was in Abu Dhabi’s Onshore Block 3, operated by Occidental, and is estimated to be around 100 million bbl of oil in place. The onshore Al Dhafra Petroleum Concession yielded the third discovery—around 50 million bbl of light sweet Murban-quality crude. Ecopetrol, Oxy Prep Development Quartet Ecopetrol has an agreement in place to develop four deepwater blocks with a subsidiary of Occidental. The four blocks are located in deep waters some 150 km off Colombia’s northern Caribbean coast. Ecopetrol will take a 40% stake in the blocks while Occidental subsidiary Anadarko Colombia will hold the remaining 60% stake and will serve as the blocks’ operator. The deal remains subject to approval from Colombia’s Ministry of Mines and Energy. Equinor, ExxonMobil Plan Bacalhau Expansion off Brazil Equinor and partner ExxonMobil are considering adding a second drilling rig and a second floating production platform for the next phase of the Bacalhau development in the Santos basin, along with a 100-mile-long gas pipeline, according to Reuters. The companies want to boost future production from Bacalhau, Equinor’s largest project outside of Norway. A new appraisal well is planned in the north of the field next year “to better understand the reserves base for the Phase 2 development,” according to Equinor, and the partners are assessing awarding a contract for a second drilling rig. The partners sanctioned the $8-billion project a year ago. The field is situated across two licenses, BM-S-8 and Norte de Carcará. The resource is a high-quality carbonate reservoir containing light oil. The development will comprise 19 subsea wells tied back to an FPSO located at the field. The planned FPSO be one of the largest in Brazil with a production capacity of 220,000 B/D and 2 million bbl in storage capacity. The stabilized oil will be offloaded to shuttle tankers, and the gas from Phase 1 will be reinjected in the reservoir. First oil is expected in 2024. Equinor Transfers Krafla Operatorship to Aker BP Equinor and Aker BP have signed a memorandum of understanding (MoU) for transfer of the Krafla operatorship from Equinor to Aker BP, making Aker BP the operator of all discoveries in the NOAKA area: Krafla, Fulla, and North of Alvheim. Equinor and Aker BP are operators of one field development project each in the area and have agreed that one operator will be the best solution for further development. The MoU states that the owners of the relevant licenses will apply to the ministry for change of operator. A transfer of operatorship will be carried out when the investment decision has been approved by the license partners and the plan for development and operation has been submitted to the authorities. Equinor will still be a major license partner in the area and will retain its existing share of 50% in Krafla and 40% in the Fulla license. The companies will jointly submit the PDOs for NOA Fulla and Krafla as planned by the end of the year. Energean Strikes Gas at Athena off Israel UK-based Energean has discovered gas with its Athena probe in Block 12, 20 km from Tanin A in 1769 m of water. The probe was drilled in 51 days and encountered a gross hydrocarbon column of 156 m in the primary target. Preliminary analysis indicates that the Athena discovery contains recoverable gas volumes of 8 Bcm on a standalone basis. Energean will conduct analysis to refine the full resource potential (including volumes contained within thinner sands between the main reservoir units) and to confirm the liquids content of the discovery. The Athena well has been suspended as a future production well. Commercial hydrocarbons were not discovered in the deeper secondary target. Athena can be commercialized in the near term via tieback to the Energean Power FPSO, enhancing the profitability of the Karish-Tanin development. Alternatively, it could form part of a new development called the Olympus Area which consists of Block 12 and additional prospects on the Tanin lease. The discoveries and prospects in this area lie along the same geological trend; Athena was drilled on the same direct hydrocarbon indicator as Tanin. Energean is confident that the Athena discovery has de-risked the A, B, and C sands in the remaining prospects of the Olympus Area, estimated to be 50 Bcm of mean unrisked prospective resources. This estimate excludes the liquids component as well as any gas upside in the thinner sands between the main reservoir units. Drillship Stena IceMAX has moved to the Karish Main-04 appraisal well and will complete the Karish North development well.
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"Osmoflo contracted to deliver major RO plant for saline water treatment in Australia." Membrane Technology 2022, no. 4 (April 1, 2022). http://dx.doi.org/10.12968/s0958-2118(22)70046-8.
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In partnership with Aerison Pty Ltd, Water treatment company Osmoflo has been awarded a contract for a major water treatment system at the Roy Hill Mine – a mining, rail and port operation located approximately 340 km (211 miles) south-east of Port Hedland in the Pilbara region of Western Australia.