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Journal articles on the topic 'Offshore oil industry – England'

Author: Grafiati
Published: 10 March 2023
Last updated: 11 March 2023

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1

Collier, Graham. "Technology Focus: Offshore Facilities (September 2022)." Journal of Petroleum Technology 74, no. 09 (September 1, 2022): 75–76. http://dx.doi.org/10.2118/0922-0075-jpt.

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During the last great downturn in the oil and gas industry, I heard several glib comments along the lines of “the Stone Age didn’t end because we ran out of stones. … And now it’s the end for the oil industry.” At the time, I dismissed it as typical of our age, another short burst of one-line philosophy, just some attention-seeking doomsday prophecy that pops up far too frequently on our phones. So here we are in 2022, post COVID-19 (I hope), refreshed in thirst for oil, with commodity prices soaring, oil-producing company executives rubbing their hands with glee, and motorists complaining at the pump. All seems back to normal. But not so fast. The previous whisperings of the environmentalist movement have turned up in volume; change is now being shouted from street corners around the globe. While the oil and gas industry may be basking in the warmth of a new renaissance, there is a major shift toward carbon-free energy generation. Coastlines are being peppered with towering wind turbines, and the countryside is now farming more and more solar panels. Carbon capture and hydrogen generation are no longer science fiction fantasies and are now attracting interest, innovation, and investment. Does this all mean the glib comment about the “Stone Age” is about to come true? No. Not yet, anyway. At the turn end of the 19th century, coal was the major energy provider, but by the end of the 20th century, despite there being known huge reserves underground, coal mining had significantly declined in Europe and the Americas. Likewise with oil, at the start of the 21st century, oil and gas was the No. 1 energy provider, and the general consensus was that we would run out by mid-century. However, here we are, well into the third millennium, and oil and gas is still abundant, Saudi Arabia still sits on massive reserves as do some of its neighbors, and ExxonMobil appears to find a massive new oil field every time it drills a well off the Guyanese coast. Today, oil and gas are still important energy providers. They will remain with us throughout this century, but, like the coal industry, they will decline, not because we will run out, but because mankind will learn to harvest cleaner energy more favorable to the wellbeing of us all. In the meantime, I do hope that we are not so quick to rid ourselves of the impressive industrial engineering that is the legacy of a hundred years of oil and gas production. We find ourselves with a huge quantity of “idle iron” processing plants, refineries, offshore platforms, and a massive network of pipelines—idle, but not useless. Before the bulldozers and gas axes are released, there must be a drive for reuse of much of this infrastructure. It is comforting to see so much innovative thinking appearing in the Journal of Petroleum Technology advocating renewable energy and repurposing of aging oil and gas structures. It is worth noting that Stonehenge, built in Southern England more than 5,000 years ago, still functions as a remarkably accurate celestial calendar. I hope that you enjoy this month’s selection of technical papers. Recommended additional reading at OnePetro: www.onepetro.org. OTC 31494 - A Literature Review on Site Suitability and Structural Hydrodynamic Viability for Artificial‑Reef Purposes by Anas Khaled Alsheikh, UTP, et al. OTC 31986 - Alternatives to Conventional Offshore Fixed Wind Installation by Roy Robinson, Excipio Energy, et al. OTC 31655 - A Technical Limits Weight‑Control Tool for Integrity Management of Aging Offshore Structures by Sok Mooi Ng, Petronas, et al.
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2

Gunter, CDR Tim. "Potential Impacts from a Worst Case Discharge from an United States Offshore Wind Farm." International Oil Spill Conference Proceedings 2014, no. 1 (May 1, 2014): 869–77. http://dx.doi.org/10.7901/2169-3358-2014.1.869.

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ABSTRACT The main purpose of this research is to explore potential environmental impacts of a worst case discharge (WCD) from an offshore commercial wind farm electric service platform (ESP) in the Northeast United States. Wind farms in the continental United States are a growing industry as an energy alternative to traditional oil, coal, and natural gas energy sources. While many offshore wind farms already exist in Europe and around the world, the Cape Wind Project in New England received the first federally approved lease for an offshore wind energy production facility in the United States. While offshore wind energy is a green source of energy, wind driven energy has its own set of environmental risks, including the risks of an oil spill. A systematic review of scholarly journals, federal government websites and other academic resources was conducted to identify previous spills in the Northeast with the closest match in volume and location to the Cape Wind Project. The oil spills from the barge North Cape in 1996 near Point Judith, Rhode Island and from the barge Florida in Buzzards Bay, Massachusetts, in 1996, had the most similarities to a potential WCD spill from the Cape Wind Project. Both of these spills adversely impacted the environment, and provide useful information that can be used for the planning efforts surrounding a WCD event from the Cape Wind Project.
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3

Cumbers, Andy. "New Forms of Work and Employment in an `Old Industrial Region'? The Offshore Construction Industry in the North East of England." Work, Employment and Society 8, no. 4 (December 1994): 531–52. http://dx.doi.org/10.1177/095001709484003.

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This paper examines the nature of the new forms of work and employment brought to the North East of England by the development of offshore construction activities, serving the North Sea's oil and gas industries in the period since the early 1970s. In particular, it assesses the extent to which these activities differ from traditional forms of work and employment organisation within the region. The results of this analysis suggest the need to interpret contemporary patterns of restructuring, both in a particular local labour market context and more generally, as part of an on-going evolutionary process, rather than as a decisive break (or shift) from the past.
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4

Ponsonby, W., F. Mika, and G. Irons. "Offshore industry: medical emergency response in the offshore oil and gas industry." Occupational Medicine 59, no. 5 (July 16, 2009): 298–303. http://dx.doi.org/10.1093/occmed/kqp075.

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5

Ambrose, Philippa. "A cleaner UK offshore oil industry." Marine Pollution Bulletin 32, no. 7 (July 1996): 524. http://dx.doi.org/10.1016/0025-326x(96)84567-x.

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6

Mu-Zhen, Lu. "OIL SPILL PREVENTION AND TREATMENT IN OFFSHORE OIL INDUSTRY OF CHINA." International Oil Spill Conference Proceedings 1989, no. 1 (February 1, 1989): 235–38. http://dx.doi.org/10.7901/2169-3358-1989-1-235.

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ABSTRACT The China National Offshore Oil Corporation (CNOOC), established in October 1982, is the sole Chinese company dealing with offshore oil exploration, development, and production. It has four regional corporations, and four specialized corporations, as well as seventeen joint venture corporations. CNOOC has four representative offices outside China. Since the Sino-foreign cooperation for offshore oil exploration and development in China started, 360,000 line km of seismic survey have been shot, thirty-nine oil and gas bearing structures have been found, fifteen oil fields have been evaluated as having large hydrocarbon accumulations, nine oil fields have been developed and put into production, 179 exploratory wells have been drilled, and CNOOC has signed thirty-nine contracts with a total of forty-five foreign companies from twelve countries. There are five laws and regulations in the PRC affecting offshore oil development and marine environmental pollution. In accord with these laws and regulations, CNOOC has reviewed four environmental impact statements for offshore oil fields received from its regional corporations. CNOOC has made oil spill contingency plans for the Cheng-Bei offshore oil field in Bo-Hai, and the Wei 10-3 offshore oil field in the Gulf of Bei-Bu. Some oil spill combating equipment is owned by the Bo-Hai Oil Corporation and the Nan-Hai West Oil Corporation, selected on the basis of the crude oil characteristics.
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7

Raharjo, Agus Denny Unggul. "HUBUNGAN STRATEGIS PADA EVOLUSI TEKNOLOGI LEPAS PANTAI DI INDUSTRI MIGAS." INTAN Jurnal Penelitian Tambang 5, no. 1 (May 31, 2022): 1–6. http://dx.doi.org/10.56139/intan.v5i1.104.

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Offshore operation in oil and gas industry defined as any drilling and production operation located or operating on a body of water, at some distance from the shore relatively to what identified as onshore operation which is generally means in land operation. Offshore drilling and production operation was a relatively new industry compare to the history of oil industry itself. Technologies take major part in development of offshore project, technologies make what impossible become possible in offshore industry. Offshore drilling and production industry can be possible because of technology innovation. However the drive to explore offshore resources come from high demand on oil and gas as well as depleted resources in onshore resources. One suggested that there is strategic interaction among entities in oil industry, as for offshore operation the strategic interaction lead to evolution of offshore technology. The strategic interaction between two relatively same profiles oil related company will depend on the cost of technology. There is tendency in oil and gas industry, if one company successful in using a kind of technology the other companies will follow the pad. Technology takes a big part in offshore drilling and production industry. The strategic interaction in offshore industry related to the cost of technology.
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8

Hann, J. "PESA INDUSTRY REVIEW 2003." APPEA Journal 44, no. 2 (2004): 117. http://dx.doi.org/10.1071/aj03066.

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Five developments started production in 2003—these were ARC Energy’s HOVEA onshore oil development Perth Basin, OMV’s Patricia Baleen offshore/onshore gas development in East Gippsland, ENI’s Woollybutt and Apache’s Double Island offshore oil fields and Woodside completed the first phase of their NW Shelf expansion project (Fig. 1).
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9

Kaiser, P. "Microbial problems in the offshore oil industry." Annales de l'Institut Pasteur / Microbiologie 138, no. 4 (July 1987): 495–96. http://dx.doi.org/10.1016/0769-2609(87)90070-6.

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10

Bradshaw, Elizabeth A. "“Obviously, we’re all oil industry”: The criminogenic structure of the offshore oil industry." Theoretical Criminology 19, no. 3 (October 10, 2014): 376–95. http://dx.doi.org/10.1177/1362480614553521.

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11

Raffaelli, P. I. "Offshore medicine--Medical Care of Employees in the Offshore Oil Industry." Occupational and Environmental Medicine 44, no. 6 (June 1, 1987): 431. http://dx.doi.org/10.1136/oem.44.6.431.

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12

Karataeva, Elena. "Can the Caspian Sea Survive its Own Oil? Environmental Regulation of the Offshore Oil and Gas Industry in the Caspian Sea." International Journal of Marine and Coastal Law 29, no. 3 (September 10, 2014): 415–56. http://dx.doi.org/10.1163/15718085-12341326.

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This article critically examines the shortcomings of the offshore industry regulation in the Caspian Sea and proposes a framework to strengthen it. It considers the hydrocarbon industry and resources of the Caspian Sea region and analyses the extent and impacts of Caspian offshore oil and gas activities on its environment, reviews selected regional and global regulatory frameworks for the offshore oil and gas industry and their effectiveness, discusses existing shortcomings of the national and regional regulation of the Caspian offshore oil and gas industry, and provides suggestions on how it could be improved, drawing on the experience and regulatory formulations from other regions of the world.
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13

Woolfson, Charles, and Matthias Beck. "The British Offshore Oil Industry after Piper Alpha." NEW SOLUTIONS: A Journal of Environmental and Occupational Health Policy 10, no. 1-2 (August 2000): 11–65. http://dx.doi.org/10.2190/tcmb-yqa4-txu0-b1d4.

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14

Sarney, R. G. "Cables for the offshore oil and gas industry." Electronics and Power 31, no. 4 (1985): 304. http://dx.doi.org/10.1049/ep.1985.0190.

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15

Clark, David, Kathryn McCann, Ken Morrice, and Rex Taylor. "Work and Marriage in the Offshore Oil Industry." International Journal of Social Economics 12, no. 2 (February 1985): 36–47. http://dx.doi.org/10.1108/eb013988.

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16

Davies, Gareth. "Offshore kazakhstan—ultimate challenge for the oil industry." Marine Pollution Bulletin 34, no. 3 (March 1997): 145. http://dx.doi.org/10.1016/s0025-326x(97)84991-0.

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17

Cumbers, Andrew. "Development Prospects for the European Offshore Oil Industry." European Urban and Regional Studies 2, no. 4 (October 1995): 362–67. http://dx.doi.org/10.1177/096977649500200408.

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18

R, Priya, Vinothini G, and Corpus D. Cor Jesu. "HSE Systems in Offshore Oil and Gas Industry." Journal of Advanced Research in Dynamical and Control Systems 11, no. 0009-SPECIAL ISSUE (September 25, 2019): 1431–36. http://dx.doi.org/10.5373/jardcs/v11/20192761.

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19

LaBelle, Robert P., and James S. Lane. "Meeting the Challenge of Deepwater Spill Response." International Oil Spill Conference Proceedings 2001, no. 1 (March 1, 2001): 705–8. http://dx.doi.org/10.7901/2169-3358-2001-1-705.

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ABSTRACT Close to 25% of all oil and gas produced in the United States comes from offshore production. A new era for the Gulf of Mexico has begun with intense industry interest in deepwater (> 300 m) areas. Production from deepwater now represents about 46% of all U.S. offshore oil and 17% of U.S. offshore gas. Spill response plans and capabilities must be upgraded to meet the challenges of this new remote activity. This paper outlines a joint research effort underway between government and industry to address needed research on deep spill plume and trajectory behavior and surveillance. Major topics discussed include the application of results from a June 2000 deepwater experimental release of oil and gas offshore Norway, findings from several laboratory studies on plume characterization, and an upgraded numerical model for deep spill trajectories. There is much interest from the offshore industry as to how these research findings will be incorporated into federal review of oil spill response plans for deepwater projects.
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20

Wang, Haopeng, and Zhenzhi Zhao. "Study on Logistics Cost Optimization of Offshore Oil Service Industry Based on Offshore Oil Service Cost Model." Journal of Coastal Research 98, sp1 (December 27, 2019): 171. http://dx.doi.org/10.2112/si98-042.1.

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21

Johns, Rhodri, and Patrick Despland. "2013 PESA industry review: exploration." APPEA Journal 54, no. 1 (2014): 431. http://dx.doi.org/10.1071/aj13043.

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Exploration activity in Australia in 2013 occurred across a broad spectrum of conventional and unconventional plays. Competition for acreage was buoyant with large tracts of key onshore basins either licensed or under application. Offshore, there were new awards on the western Australian margin and in the Bight Basin off SA. Offshore 3D seismic acquisition was reduced from anomalously high levels in 2012. Onshore 2D seismic acquisition was at historic highs and onshore 3D was the most ever recorded. Overall drilling levels were maintained despite a decline offshore. Of 13 offshore wells drilled, six were discoveries. Sixty-nine exploration wells (excluding CSG wells) were drilled onshore. Fifty addressed conventional, and 19 were unconventional shale or basin-centered gas targets. Sixty of the 69 wells were drilled in the Cooper/Eromanga Basin where conventional oil and gas exploration yielded 11 oil and six gas discoveries. Drilling and fraccing campaigns in the Nappamerri Trough unconventional gas plays provided early encouraging results. 213 exploration and appraisal CSG wells were drilled in the CSG basins of Queensland and NSW. In Queensland a record total of 1,317 CSG wells were drilled in fiscal year 2012/2013. Shale gas exploration activity was increasingly focused on the Palaeozoic and Proterozoic Basins of Western, Central and Northern Australia with major oil and gas companies involved in joint ventures preparing for drilling in 2014. The results of these programmes will have an important bearing on the future direction of exploration in these plays.
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22

Kelemen, Stephen. "2015 PESA industry exploration review." APPEA Journal 56, no. 1 (2016): 505. http://dx.doi.org/10.1071/aj15036.

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Globally, 2015 had the lowest addition of new oil reserves in more than 60 years, reflecting both reduced activity and fewer oil opportunities, although significant gas discoveries were made. In Australia, the underlying theme for the year was one of adapting to low oil prices and learning to operate prudently with a lower price outlook. The cautious approach of 2014 persisted, with exploration activity at reduced levels. Offshore seismic recording maintained its recent high activity levels with a total of 45,563 km2 of mainly regional 3D seismic recorded, but onshore seismic recorded was at historically low levels. Nine exploration wells were spudded offshore with limited success (two gas and condensate discoveries at Auriga West–1 in the Browse Basin and Roc–1 in the Roebuck Basin). Onshore, however, the 38 non-CSG exploration wells drilled had a high success rate although discoveries were small. A highlight onshore was Origin Energy reporting encouraging results from the McArthur Basin for its Proterozoic mid-Velkerri Formation shales gas exploration program. Caution also extended to permit activity, where offshore relinquishments exceeded the number of permits granted, and onshore international companies withdrew from their unconventional farmin programs. For permits granted offshore, lower expectations of prospectivity resulted in only one well being committed in the primary term work program. Community pressure continued to play a significant role in the lack of CSG and other exploration drilling in NSW and onshore Victoria.
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23

Schneider, James A., and Marc Senders. "Foundation Design: A Comparison of Oil and Gas Platforms with Offshore Wind Turbines." Marine Technology Society Journal 44, no. 1 (January 1, 2010): 32–51. http://dx.doi.org/10.4031/mtsj.44.1.5.

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AbstractThe offshore oil and gas (O&G) industry has over 70 years of experience developing innovative structures and foundation concepts for engineering in the marine environment. The evolution of these structures has strongly been influenced by water depth as well as soil conditions in the area of initial developments. As the offshore wind industry expands from the glacial soil deposits of the North and Baltic Seas, experience from the O&G industry can be used to aid a smooth transition to new areas. This paper presents an introduction to issues that influence how design and construction experience from the O&G industry can be used to aid foundation design for offshore wind energy converters. A history of the evolution of foundation and substructure concepts in the Gulf of Mexico and North Sea is presented, followed by a discussion of soil behavior and the influence of regional geology on these developments. Mechanisms that influence the resistance of shallow and deep foundations for fixed and floating offshore structures are outlined so that areas of empiricism within offshore design codes can be identified and properly modified for application to offshore wind turbine foundations. It is concluded that there are distinct differences between offshore O&G and offshore wind turbine foundations, and application of continued research into foundation behavior is necessary for rational, reliable, and cost-effective design.
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24

Bybee, Karen. "Offshore-Connectivity Solutions for the Oil and Gas Industry." Journal of Petroleum Technology 60, no. 12 (December 1, 2008): 85–86. http://dx.doi.org/10.2118/1208-0085-jpt.

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25

Matthiessen, P. "Environmental Impact of the Offshore Oil and Gas Industry." Environmental Pollution 110, no. 2 (November 2000): 367. http://dx.doi.org/10.1016/s0269-7491(00)00082-8.

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26

Cassells, Eric. "Building a learning organization in the offshore oil industry." Long Range Planning 32, no. 2 (April 1999): 245–52. http://dx.doi.org/10.1016/s0024-6301(99)00023-0.

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27

Stenehjem, J. S., K. Kjaerheim, K. S. Rabanal, and T. K. Grimsrud. "Cancer incidence among 41 000 offshore oil industry workers." Occupational Medicine 64, no. 7 (July 30, 2014): 539–45. http://dx.doi.org/10.1093/occmed/kqu111.

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28

Ingram, Brad, and Steve Grabacki. "Offshore oil impacts on the bering sea fishing industry." Environmental Impact Assessment Review 7, no. 2 (June 1987): 109–24. http://dx.doi.org/10.1016/0195-9255(87)90031-x.

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29

Johansen, Inger Lise, and Marvin Rausand. "Barrier management in the offshore oil and gas industry." Journal of Loss Prevention in the Process Industries 34 (March 2015): 49–55. http://dx.doi.org/10.1016/j.jlp.2015.01.023.

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30

Saeterstad, Trond. "Process design needs in oil and gas offshore industry." Fluid Phase Equilibria 29 (October 1986): 77–92. http://dx.doi.org/10.1016/0378-3812(86)85013-0.

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31

Vandenbussche, Valentin, Emma Karlstrøm Thylander, and Daniel Millet. "Best Available Techniques Applied to the Offshore Oil and Gas Industry." International Oil Spill Conference Proceedings 2014, no. 1 (May 1, 2014): 388–99. http://dx.doi.org/10.7901/2169-3358-2014.1.388.

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ABSTRACT Best Available Techniques (BAT) is a principle originally defined in the EU directive on Integrated Pollution Prevention and Control (IPPC). The overall ambition of the directive is to reduce emissions and impacts on the environment as a whole. The purpose of a BAT assessment is to identify the technique with the best environmental performance among all available techniques for a certain industrial application. Such assessment should also take into account technical and economic constraints. A wide variety of industries fall under the scope of the IPPC requirement for BAT in Europe. The BAT approach is more and more applied in countries outside of EU, and adopted by private organisations as a best practice. In the offshore Oil & Gas industry in Norway, for instance, the BAT approach is now applied to many systems, such as power generation, produced water management, VOC recovery, or, more recently, leak detection and remote sensing. The particularity of the site-specific constraints as well as a lifecycle perspective, typical of the offshore Oil & Gas industry, makes the application of the BAT approach challenging for this sector. Best Available Techniques for offshore applications are therefore site-specific, and require a case by case assessment. In addition, in countries such as Norway, there is no guideline or directive describing how to perform a BAT assessment, which hence needs interpretation and adjustment for each individual application. DNV has developed a methodology for BAT assessments specifically for the offshore industry. This methodology is based on a ranking of the environmental performance as well as technical feasibility, reliability and costs of available industrial concepts. The approach is applicable to various stages of offshore Oil & Gas projects. This paper will describe the BAT methodology for the offshore Oil & Gas industry, and give relevant examples of its application to various systems commonly found on offshore facilities. Challenges and future opportunities will also be presented and discussed.
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Huynh, Tin Trung, and Vinh Trong Bui. "Application of quantitative risk assessment on offshore oil & gas industry." Science and Technology Development Journal 17, no. 3 (September 30, 2014): 62–68. http://dx.doi.org/10.32508/stdj.v17i3.1476.

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Production of Oil & Gas in offshore involves some of the most ambitious engineering projects of the modern world, is a prime source of revenue for many countries. It is also involved risks of major accidents which have been demonstrated by disaster on the UK production platform Piper Alpha. Major accidents represent the ultimate, most disastrous way in which an offshore engineering project can go wrong. Accidents cause death, suffering, environmental pollution and disruption of business. To ensure all risks identified and controlled, risk management approaches need applying. This paper discusses the application of quantitative risk assessment approaches and its importance throughout the entire offshore installation.
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Jas, Eric, Allison Selman, and Valerie Linton. "Out of sight out of mind – subsea pipeline decommissioning." APPEA Journal 57, no. 1 (2017): 79. http://dx.doi.org/10.1071/aj16215.

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Existing legislation, regulation and documentation dealing with decommissioning of offshore oil and gas infrastructure has traditionally been derived from experience gained in the North Sea and the Gulf of Mexico. The Australian operating environments are very different and, consequently, there is no Australian industry-wide engineering standard dedicated to the decommissioning of offshore pipelines. Decommissioning of Australian offshore pipelines is currently handled on a case-by-case basis. The efficiency and effectiveness of any given decommissioning project is variable, and highly dependent upon the experience of the pipeline operator. Given the maturity stage of the Australian offshore oil and gas industry, it is foreseen that in the coming years many operators will approach the task of decommissioning offshore pipelines for the first time. In 2014 the Energy Pipelines Cooperative Research Centre (EPCRC) formed an offshore users group, comprising pipeline experts from several offshore oil and gas operators and engineering consultancies that are members of the Australian Pipelines and Gas Association’s Research and Standards Committee (APGA RSC). This group is developing an engineering guideline for the decommissioning of offshore pipelines. It is being developed in close communication with the Australian Petroleum Production and Exploration Association (APPEA), which has formed a decommissioning committee in relation to offshore facilities. This ensures the guideline is being developed by and with input from a broad spectrum of the Australian offshore oil and gas industry, with the aim of capturing best practice in the Australian context.
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Hassanov, Anar, Namig Gandilov, Daniel Jayson, Tariel Huseynov, Ilkin Kangarli, Aghalar Ibrahimov, and Peter Mark Taylor. "Government and Industry Cooperation in Practice: Azerbaijan's Experience." International Oil Spill Conference Proceedings 2011, no. 1 (March 1, 2011): abs103. http://dx.doi.org/10.7901/2169-3358-2011-1-103.

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ABSTRACT In recent times, Azerbaijan has seen the development of a significant modern offshore industry. The oil and shipping industries in Azerbaijan bring economic benefits but also give rise to the need for robust oil spill prevention and preparedness measures. Azerbaijan signed the International Convention on Oil Pollution Preparedness, Response and Cooperation (OPRC) in 2004 and continues to develop and refine its national system of oil spill response. This paper discusses how the Azerbaijan government and key players in the oil industry have successfully worked together to achieve alignment in prevention, protection and response to major incidents. The implementation of the OPRC Convention is the responsibility of the Ministry of Emergency Situations (MES) of the Republic of Azerbaijan. Within the national response system a national oil spill contingency plan has been developed. The main offshore developments in the Caspian since the 1990s have been led by BP, as operator of a number of Production Sharing Agreements. BP has implemented comprehensive oil spill response plans and is working in partnership with MES to integrate this planning into the national framework. The oil spill management systems adopted by BP and the government are compatible and commensurate with guidance published by the International Maritime Organization in 2011. These aligned management systems allow for an effective Joint Command and coordination of resources in the case of a major incident. The key to building effective oil spill preparedness are a willing dialogue, integrated command structure, joint training and exercising and upgrade of hardware and information systems' software. The cooperation between government and BP relating to offshore risks strengthens the national capacity to deal with spills risks other than from offshore platforms, including the anticipated increase of oil shipments across the Caspian Sea. Furthermore, these efforts have been supported by international organizations and the regional industry initiative, OSPRI, of which BP is a member. The experience of Azerbaijan provides a model demonstrating how partnership between government and industry can achieve synergy and it confirms the importance of signing and implementing the OPRC Convention.
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Moller, Anders. "Efficient Offshore Wind Turbine Foundations." Wind Engineering 29, no. 5 (September 2005): 463–69. http://dx.doi.org/10.1260/030952405775992580.

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In the oil and gas industry, the foundations of offshore platforms have, for decades, used the grouted technique. This technology has now been transferred into the offshore wind turbine industry. This paper gives details of the use of the technology in some of the first offshore windfarms in Europe and considers future design possibilities.
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Maggi, Patricia, Claudia Do Rosario Vaz Morgado, and João Carlos Nóbrega De Almeida. "Offshore Oil Spill Incidents in Brazil." Applied Mechanics and Materials 295-298 (February 2013): 626–29. http://dx.doi.org/10.4028/www.scientific.net/amm.295-298.626.

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Brazil has performed an important role in the oil and gas industry mainly because its offshore E&P activities. The volume of oil produced in offshore fields had increased 88% in the last decade. Although the offshore exploration had begun in the 70’s of the last year, only in the year 2000 was promulgated a law enforcing the companies to notify any accidental release to the environment. Besides the Brazilian Navy and the National Petroleum Agency, the Brazilian Federal Environmental Agency - IBAMA is entitled to receive these notifications. Although IBAMA receives the oil spill communications since 2001, only in 2010 the Agency began to include this information in a database. This paper discusses the offshore oil spill data received between 2010 and 2011.
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Huang, Xin, and Nan Jun Lai. "WTO Accession Brings Opportunities, Challenges to CNOOC and Corresponding Countermeasures." Advanced Materials Research 433-440 (January 2012): 1492–96. http://dx.doi.org/10.4028/www.scientific.net/amr.433-440.1492.

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China join in WTO means that China petroleum industry will be integrated into economic globalization also means that China petroleum industry will have a direct impact by market competition. As being Chinese’s largest offshore oil and gas producer, China National Offshore Oil Corporation must take active measures to deal with the opportunities and challenges brought by joining the World Trade Organization.
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38

Hudec, Al, and Van Penick. "British Columbia Offshore Oil and Gas Law." Alberta Law Review 41, no. 1 (July 1, 2003): 101. http://dx.doi.org/10.29173/alr496.

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This article addresses the current debate over lifting a thirty-five year moratorium on offshore resource development in British Columbia. It describes the three primary offshore basins and the history of the various moratoriums, as well as the current legal backdrop under which development could occur. The authors review unique jurisdictional, Aboriginal and environmental considerations relating to the west coast, and conclude that the east coast regulatory regime provides a useful regulatory template for the west coast, appropriately updated for technological changes in the offshore industry and changes in regulatory philosophies since the 1980s.
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39

Wright, Chris. "Routine Deaths: Fatal Accidents in the Oil Industry." Sociological Review 34, no. 2 (May 1986): 265–89. http://dx.doi.org/10.1111/j.1467-954x.1986.tb02702.x.

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This paper is a study in the relatively neglected field of the Sociology of Accidents and is concerned with fatalities in the UK Offshore Oil Industry. The purpose of the paper is to demonstrate the social and organizational causes of these accidents. Common sense and expert opinion both present industrial accidents as products of extra organizational abnormality but evidence from this research locates the causes of accidents in work organization and dependence on bureaucratic rationality. In particular it is shown that the hazardous situations in which the accidents occurred were themselves largely the products of two aspects of the formal organization of work, the ‘speed-up’ and the practice of ‘sub-contracting’. It is demonstrated that the common sense equation of the ‘normal’ and the ‘routine’ inhibited recognition of the organization causes of these accidents. Finally it is argued that, since there is little support for the view that the accident were produced by unique working conditions in the offshore industry, it is therefore likely that the causes of accidents in this industry will be found to exist in other industries.
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40

Bronson, Michael, Thomas Chappie, Larry Dietrick, Ronald Hocking, and James McHale. "Planning Oil Spill Response Tactics for Offshore Production Islands." International Oil Spill Conference Proceedings 1999, no. 1 (March 1, 1999): 1163–66. http://dx.doi.org/10.7901/2169-3358-1999-1-1163.

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ABSTRACT In anticipation of the Beaufort Sea's first two offshore production islands, Alaska's North Slope oil producers recently expanded their oil spill recovery tactical plans and equipment. To seek regulatory approval for offshore oil production, industry responders joined agency regulators and made plans to clean up as much as 225,000 barrels of oil from potential blowouts over 15 days. Response technicians are configuring new and existing skimmers, vessels, and barges on the North Slope to implement those planning standards. This paper outlines the oil spill tactical plans and equipment that Alaska's North Slope oil industry recently assembled in seeking regulatory approval for the first offshore production islands in the Arctic. The operators of North America's largest oil fields are beginning the first production from oil wells separated from roads and most spill response vessels. For example, the new Badami production pad lies on the Arctic coast more than 25 miles from the Prudhoe Bay facilities, across river courses and roadless tundra. Eight miles of ice-infested sea will separate the proposed Northstar and Liberty production islands from response vessel berths. The new fields regularly experience waves, cold, and ice invasions that constrain oil recovery efforts. Yet regulatory approval to begin oil production requires that the industry have plans and equipment to clean up all the oil that may enter open water, even from the largest spills, within 72 hours.
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41

Denton, A. A. "Safety Offshore—Loss Prevention in a Pioneering Industry." Proceedings of the Institution of Mechanical Engineers, Part E: Journal of Process Mechanical Engineering 207, no. 2 (August 1993): 79–97. http://dx.doi.org/10.1243/pime_proc_1993_207_212_02.

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The President recalls his early days in a coal mining community which kindled his interest in mechanical engineering, and tells of his subsequent introduction into the nascent offshore oil and gas industry in the early 1960s. His career has been closely linked to the development of devices to drill for and produce oil in harsh environments in all quarters of the globe. Many of the novel ideas that emanated from a pioneering industry were subjected to the author's evaluation and certification, and the more interesting of these are described, together with pointers for future offshore developments. The Piper Alpha accident in the North Sea resulted in the Cullen Inquiry, to which the author presented the evidence of the Institution. Subsequent to this he has examined operating procedures of many offshore organizations and submits his evaluation of the Cullen recommendation and the prospect for safer operations in the future. Finally the President looks at unification and related matters, and offers views on the way forward for the Institution.
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42

Brooks, Deidre. "2012 PESA industry review—exploration." APPEA Journal 53, no. 1 (2013): 141. http://dx.doi.org/10.1071/aj12012.

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The Australian exploration landscape experienced an escalation of unconventional activity in 2012. Drilling targeting shale oil and gas, basin-centred tight gas, and coal gas is on the increase compared to previous years. Drilling for onshore oil and large offshore gas continued to be a staple activity for the year although, in general, offshore, the number of wells drilled is continuing to decline, in line with previous years. A number of very large 3D seismic surveys were acquired in 2012 and this is hoped to provide many future drilling targets. Within Australia, 19 new offshore conventional petroleum exploration permits were awarded within the Commonwealth jurisdiction (compared to 24 in 2011), of which 15 are located in WA, two in Victoria, one in NT, and one in the Territory of Ashmore and Cartier Islands (NT). Onshore exploration tenures awarded in 2012 included four in WA, 14 in NT, six in Queensland, and nine conventional and six geothermal in SA. At least 25 3D and six 2D seismic surveys were acquired offshore in 2012, including some very large 3D marine surveys, the largest covering an area of 12,417 km2. Onshore seismic activity was highest in Queensland and SA where 33 and 11 surveys were acquired, respectively. Offshore, 21 conventional petroleum exploration wells were drilled during the year, which resulted in 11 announced discoveries. Two exploration wells, which were spudded late in 2011, were announced as discoveries early in 2012. Five wells, which were spudded in 2012, were still drilling at year end. This equates to a better than 50% technical success rate for offshore exploration drilling for all well results known at year end. All but two of these wells were located in WA waters, the others being located in NT and Victoria. Australia-wide onshore drilling was more active than in 2011 and, as is reflected in the seismic activity, the most wells (1,048) were drilled in Queensland (dominated by CSG drilling), followed by SA (77).
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43

FLIN, RHONA, GEORGINA SLAVEN, and KEITH STEWART. "Emergency Decision Making in the Offshore Oil and Gas Industry." Human Factors: The Journal of the Human Factors and Ergonomics Society 38, no. 2 (June 1996): 262–77. http://dx.doi.org/10.1177/001872089606380207.

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44

Stenehjem, Jo S., Kristina Kjaerheim, Kjersti S. Rabanal, and Tom K. Grimsrud. "Cancer incidence among 41 000 Norwegian offshore oil industry workers." ISEE Conference Abstracts 2013, no. 1 (September 19, 2013): 5185. http://dx.doi.org/10.1289/isee.2013.p-3-16-08.

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45

Managi, Shunsuke, James J. Opaluch, Di Jin, and Thomas A. Grigalunas. "Alternative technology indexes in the offshore oil and gas industry." Applied Economics Letters 13, no. 10 (August 15, 2006): 659–63. http://dx.doi.org/10.1080/13504850500401866.

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46

Englin, J. E., and M. S. Klan. "Offshore Oil and Environmental Risk: Federal Offerings vs. Industry Bids." Energy Exploration & Exploitation 6, no. 4-5 (September 1988): 378–91. http://dx.doi.org/10.1177/014459878800600411.

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This paper examines the role of environmental risk in the Interior Department's Outer Continental Shelf (OCS) acreage offering decision process and the oil industry's bidding decision. Following a brief discussion of the OCS leasing process, a conceptual model for understanding the decisions proposed. The associated equations are econometrically estimated for both Interior und the oil industry using data from the 1979 North Atlantic Georges Bank Sale. By estimating decision equations as a function of environmental risk, cost of extraction, and expected hydrocarbon potential, the trade off between these parameters is revealed. Two important results are obtained. First is that in the Norht Atlantic study case, the acreage of interest to industry was largely a subset of the acreage Interior was willing to offer. This implies that industry was generally more conservative with respect to environmental risk than Interior. Second, the industry trade off between expected hydrocarbons and risk of a potential oil spill reaching shore was considerable. Over $1 million worth of additional expected hydrocarbons was needed to induce a bid if the risk of a spill hitting shore increased about 7%
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47

Warhurst, Alyson. "Technology transfer and the development of China's offshore oil industry." World Development 19, no. 8 (August 1991): 1055–73. http://dx.doi.org/10.1016/0305-750x(91)90125-2.

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48

Ross, J. A. S., J. I. Macdiarmid, L. M. Osman, S. J. Watt, D. J. Godden, and A. Lawson. "Health status of professional divers and offshore oil industry workers." Occupational Medicine 57, no. 4 (April 16, 2007): 254–61. http://dx.doi.org/10.1093/occmed/kqm005.

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49

Rowan-Robinson, Jeremy. "Environmental Regulation of the UK Offshore Oil and Gas Industry." Journal of Energy & Natural Resources Law 18, no. 3 (August 2000): 267–83. http://dx.doi.org/10.1080/02646811.2000.11433205.

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50

Mackie, Liz. "Health and safety in the offshore oil and gas industry." Library and Information Research 20, no. 65 (October 26, 2013): 25–27. http://dx.doi.org/10.29173/lirg399.

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Since the 'Piper Alpha' disaster in 1988 the system of regulating occupational health and safety in the offshore oil and gas industry has been the subject of radical reorganization. During vacation employment in the Safety and Environment Department of a North Sea oil producer during 1993 the difficulties that can arise in identifying a particular regulation or in obtaining a specific document were experienced at first hand. Standard bibliographic tools do not identify sources of health and safety information specific to the industry and it was felt that further guidance would be beneficial.
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