2013 PESA production and development review

2014 ◽  
Vol 54 (1) ◽  
pp. 451
Author(s):  
Geoff O'Brien ◽  
Monica Campi ◽  
Graeme Bethune
Keyword(s):  
Oil And Gas ◽  
Oil Production ◽  
Gas Production ◽  
Oil And Gas Development ◽  
Oil And Gas Production ◽  
North West ◽  
The North ◽  
Western Flank ◽  
Under Construction ◽  
Gas Fields

The boom in Australian oil and gas development continued in 2013, with record overall investment of $60 billion. This investment resulted from spending on the seven LNG projects under development, together with that on numerous other oil and gas developments. These projects are expected to collectively contribute up to 665 million barrels of oil equivalent (MMboe) to Australia’s oil and gas production, which totaled 513.8 MMboe in 2013. LNG, presently Australia’s seventh largest export, is likely to soon rival the nation’s largest export, iron ore. By the end of 2013, three of the LNG projects under construction—Gorgon, Queensland Curtis LNG (QCLNG) and Gladstone LNG (GLNG)—were more than 70% complete; first LNG will be before the end of 2014 for QCLNG and in 2015 for Gorgon, GLNG and Australia Pacific LNG (APLNG). The other three LNG projects—Wheatstone, Prelude and Ichthys—are close behind. These new LNG projects follow Pluto, Australia’s third LNG project, which commenced production in 2012. A full year of production from Pluto drove increased gas production in 2013. Woodside also completed the North Rankin redevelopment and continued development of the Greater Western Flank, both of which will extend the life of the North West Shelf (NWS) project. A number of other projects also commenced production. In the Carnarvon Basin, oil production began at Santos’s Fletcher-Finucane Field, and at BHP Billiton’s Macedon project, domestic gas production started. In the Timor Sea, PTTEP’s Montara Field began production of oil. In Victoria, the ExxonMobil Kipper-Turrum-Tuna project came online, with the production of gas from Tuna and oil from Turrum. Production of gas from Origin Energy’s Geographe Field (as part of the Otway Gas Project) commenced in mid-2013. Onshore oil production grew in 2013, with the Cooper-Eromanga Basin now producing more oil than any other onshore Australian basin. A major effort is underway to increase production from the western flank oil trend and to develop both the conventional and unconventional gas fields in the Cooper Basin. Spending on the development of new projects probably peaked in 2013 and there is growing concern about a dearth of future projects, with expansion of existing LNG projects and development of new projects being pushed back due to a combination of increased costs and growing international competition. There are also ongoing industry concerns about impediments to onshore gas exploration and development generally.

scholarly journals Late Cretaceous basin development of the southern Danish Central Graben

1969 ◽  
Vol 20 ◽  
pp. 15-18
Author(s):  
Finn Jakobsen ◽  
Claus Andersen
Keyword(s):  
Late Cretaceous ◽  
Oil And Gas ◽  
Seismic Inversion ◽  
Gas Production ◽  
Structural Development ◽  
Oil Accumulation ◽  
Oil And Gas Production ◽  
North West ◽  
The North ◽  
Basin Development

The Danish oil and gas production mainly comes from fields with chalk reservoirs of Late Cretaceous (Maastrichtian) and early Paleocene (Danian) ages located in the southern part of the Danish Central Graben in the North Sea. The area is mature with respect to exploration with most chalk fields located in structural traps known since the 1970s. However, the discovery by Mærsk Oil and Gas A/S of the large nonstructurally and dynamically trapped oil accumulation of the Halfdan Field in 1999 north-west of the Dan Field (e.g. Albrechtsen et al. 2001) triggered renewed exploration interest. This led to acquisition of new high quality 3-D seismic data that considerably enhanced imaging of different depositional features within the Chalk Group. Parallel to the endeavours by the operator to locate additional non-structural traps in porous chalk, the Geological Survey of Denmark and Greenland took advantage of the new data to unravel basin development by combining 3-D seismic interpretation of a large number of seismic markers, well log correlations and 2-D seismic inversion for prediction of the distribution of porous intervals in the Chalk Group. Part of this study is presented by Abramovitz et al. (in press). In the present paper we focus on aspects of the general structural development during the Late Cretaceous as illustrated by semi-regional time-isochore maps. The Chalk Group has been divided into two seismically mappable units (a Cenomanian–Campanian lower Chalk Unit and a Maastrichtian–Danian upper Chalk Unit) separated by a distinct basin-wide unconformity.

WESTERN AUSTRALIA—A TECHNOLOGY BASE FOR THE OIL AND GAS INDUSTRY

2001 ◽  
Vol 41 (1) ◽  
pp. 777
Author(s):  
B.F Ronalds
Keyword(s):  
Oil And Gas ◽  
Local Environment ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
North West ◽  
The North ◽  
International Industry ◽  
Analytical Tools

Oil and gas production is characterised by a truly international industry, and yet a unique local environment. Solutions developed elsewhere cannot always be imported directly for Australian use. For this reason alone, a strong local technology base is of value to the Australian oil and gas industry. Other benefits include the ability to provide high quality education and training for people entering, and already in, the industry.A case study is described where the Western Australian technology base is facilitating solutions to a specific challenge faced on the North West Shelf (NWS); namely, that the criteria for reliable development and operation of its offshore infrastructure for oil and gas production are more severe than other petroleum provinces, requiring new analytical tools to be developed.

scholarly journals PROBLEMS OF RUSSIAN STEPPE LANDSCAPES CAUSED BY OIL AND GAS PRODUCTION

2021 ◽  
Author(s):  
Ksenya V. Myachina ◽  
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Development ◽  
Oil And Gas Production ◽  
Oil And Gas Fields ◽  
Production Development ◽  
Type Of Land Use ◽  
Minor Significance ◽  
Gas Fields ◽  
The Impact

The depth and scale of man-made transformations of steppe landscapes in the course of oil and gas production remain underestimated. The sites provided for the development of oil and gas fields are not allocated to a separate category of the Russian Land Fund . Often there is a mismanagement of subsoil companies to the plots provided to them, provoked by the loyal attitude of the Supervisory authorities. Approved projects of oil and gas development often demonstrate minor significance of section on assessing the impact on the environment. Optimization of this type of land use becomes necessary at this stage of oil and gas production development.

scholarly journals NATURAL AND ANTHROPOGENIC DYNAMICS OF PERMAFROST SOILS IN THE AREAS OF OIL AND GAS PRODUCTION IN YAMALO-NENETS AUTONOMOUS OKRUG

2015 ◽  
pp. 99-104 ◽  
Author(s):  
N. L. Mamaeva ◽  
S. A. Petrov
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Permafrost Rocks ◽  
Oil And Gas Fields ◽  
Permafrost Soils ◽  
Extreme North ◽  
Gas Fields ◽  
Cryogenic Processes ◽  
Nenets Autonomous

A research and comparison of natural and damaged (due to the active development of oil and gas fields) permafrost soils in the Jamalo-Nenets Autonomous Okrug were carried out. The analysis was run of correlation between an average monthly temperature of air, an average monthly sum of precipitation, the weight humidity and the thickness of the seasonal thawed layer. The conclusions were drawn about a poor resistance of landscapes on the permafrost rocks to the anthropogenic interventions, which in its turn is accompanied by the cryogenic processes and unfavorable influences on the Extreme North biosphere.

Development of semi-submersible production vessels and its application to Australian waters

2008 ◽  
Vol 48 (1) ◽  
pp. 241
Author(s):  
Hilde Engelsen ◽  
Henrik Hannus
Keyword(s):  
North Sea ◽  
Environmental Conditions ◽  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
The North ◽  
Hull Design ◽  
Steel Catenary Risers ◽  
Drilling Rigs ◽  
In The Beginning

Semi-submersible platforms have a long history in the North Sea. In the beginning they were used mainly as mobile offshore drilling units, but in the last two decades the permanently moored semi-submersible production vessels have become widely used both as gas processing units and combination oil and gas production vessels. The design of production semi-submersibles evolved from that of drilling rigs, but there have since been significant improvements to the design of the hull and the topside configuration in relation to operational requirements and construction processes. The design methods have also been successfully adapted to areas with different environmental conditions, in combination with steel catenary risers and polyester mooring systems. On recent designs, simplifications of the hull systems are being implemented, which ease operation and enhance the passive safety. Finally, the semi-submersible production vessel’s application to Australian waters is discussed with focus on topside layout, hull design and mooring system design. Environmental conditions offshore northwest Australia are compared to North Sea and Gulf of Mexico conditions, along with vessel class and regulatory requirements.

scholarly journals Utah

2020 ◽  
Vol 6 (3) ◽  
Author(s):  
Mark Burghardt ◽  
Gage Hart Zobell
Keyword(s):  
Crude Oil ◽  
Oil And Gas ◽  
Oil Production ◽  
Oil And Gas Industry ◽  
Legal Framework ◽  
Gas Production ◽  
Mandatory Reporting ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
Crude Oil Production

Oil and gas production continues to be an important sector of Utah’s economy. Following a 25% loss in production between 2014 and 2015, Utah’s production continues to slowly rebound. Crude oil production in 2019 appears to be slightly ahead of 2018 production. Monthly production averages slightly over three million barrels, placing Utah among the top ten states in crude oil production. Along with the continuing increase in production, the state’s legal framework governing oil and gas continues to develop. This Article examines recent changes in Utah statutes and regulations along with new case law developments involving the oil and gas industry. In particular, this Article discusses a recent federal bankruptcy decision involving midstream agreements, the revision to a Utah statute that now requires mandatory reporting of unclaimed mineral interests, and recent revisions to Utah’s oil and gas regulations.

scholarly journals The expansion of innovative activity on rise of oil production enterprises in Azerbaijan

2021 ◽  
pp. 1-7
Author(s):  
A. G. Huseynov ◽  
◽  
E. A. Huseynov ◽  
Keyword(s):  
Oil And Gas ◽  
Production Condition ◽  
Oil Production ◽  
Gas Production ◽  
Innovative Activity ◽  
Gas Well ◽  
Oil And Gas Production ◽  
Article Analysis ◽  
The Republic ◽  
Innovative Techniques

The article analysis the oil and gas production condition in the Republic on basis of statistical data of many years as well as the level of investment provision. The article estimates the structure of expenses on innovative techniques, the condition of exploitation of oil and gas boreholes, the implementation of geological and technological actions, the ways of exploitation methods as well as the methods of ledge effects and influence on extra oil production. It also shows up the reserves and ways of their rational usage. Keywords: innovative activity; geological and technological actions; oil and gas; well.

PESA production and development review 2009

2010 ◽  
Vol 50 (1) ◽  
pp. 121
Author(s):  
Geoff Humphreys
Keyword(s):  
Large Scale ◽  
Investment Decision ◽  
Oil Production ◽  
Gas Production ◽  
Hydrocarbon Production ◽  
North West ◽  
The North ◽  
Near Term ◽  
Total Capacity ◽  
Skills Shortages

Australian hydrocarbon production reached record levels in 2009 due to strong growth in production of LNG from the North West Shelf Venture. Domestic gas production also reached record levels. Coal seam gas production continued to grow, with the continuing development of existing fields and the development of the Kenya and Talinga projects in Queensland. Two new conventional gas projects also came into production: Blacktip in the Timor Sea and Longtom in the Gippsland Basin. However oil production was below that in the previous year, reflecting natural field decline and the absence of large scale projects reaching production. The project sanction highlight of the year was the final investment decision on the $43 billion Gorgon LNG project. This project will comprise three LNG trains with total capacity of 15 million tonnes per annum plus a domestic gas plant. The first gas from this project is planned for 2014. Eight other potential LNG projects are in various stages of front end engineering and design, most targeting final investment decisions in 2010 or 2011. The pipeline of committed and potential LNG projects has a combined value estimated to be well over $100 billion. These projects have the potential to significantly increase Australian LNG production over the next five to ten years. In the near term the start-up of the Van Gogh, Pyrenees and Turrum oil projects are expected to provide some respite from the decline in Australian oil production. Cost estimates for new projects are again escalating and skills shortages in all parts of the project delivery chain threaten the ability to deliver all of the projects under consideration.

2012 PESA production and development review

2013 ◽  
Vol 53 (1) ◽  
pp. 165
Author(s):  
Jeff Jurinak ◽  
Bruce Anderson
Keyword(s):  
Shale Gas ◽  
Gas Production ◽  
Policy Debate ◽  
Development Environment ◽  
Hydrocarbon Production ◽  
North West ◽  
The North ◽  
Schedule Delay ◽  
The Us ◽  
Under Construction

2012 was a pivotal year for Australian petroleum development and production, during a dynamic time in our region, and globally. Australian activity headlines are LNG, the continuing pace and scale of the development of major projects, and record national petroleum production. LNG development in Australia is proceeding apace, with seven sanctioned projects under construction in WA and Queensland. The scale of the major projects underway is being felt with competition for skills, materials and services driving cost inflationary pressures and, coupled with other factors—such as an historically high Australian dollar—has resulted in several announced budget increases and schedule slippages. In addition, the regulatory framework is evolving, as regulators adapt to new industry trends and technologies. Proponents of future developments and expansions will be seeking to sanction in a tougher, but potentially better-informed development environment. Overall, national hydrocarbon production increased to a record high in 2012, attributable to a number of factors, but not least of which was the commissioning and successful start of commercial production of the Woodside-operated Pluto LNG development from the Pluto and Xena fields in the Carnarvon basin. Pluto was the first commissioned project since 2006, and may be viewed as the first of a number of developments that will be coming on-stream in the next few years, and will elevate Australia’s position in the ranking of world LNG production. Adding production from Pluto has allowed Woodside to take the lead position as the highest petroleum producer from BHP Billiton during 2012. Activity is not limited to LNG. Other highlights for 2012 included the opening of the Devil Creek project on the North West Shelf, WA’s third domestic gas hub, with the potential to supply around 20% of the state’s needs. Cost increase and schedule delay is not limited to LNG either, with Yolla mid-life enhancement and the Kipper offshore development facing cost and schedule pressure. In the broader global sphere, the highlight of 2012 is the extraordinary rise of unconventional oil in the US to the point of speculation about future US self-sufficiency. This parallels the rise of US unconventional gas in recent years, with gas supplies exceeding existing domestic demand and driving down the previously high domestic prices. Presently, only one US LNG project is approved for export; however, with an ongoing policy debate in the US about significant gas export verses retention to spur domestic growth, and favourable location of potential US access to the Asian market, the outcome is important for future competition to Australia’s cost-challenged LNG industry. Among this the announcement by Santos of the connection of the first shale gas well in Australia to sales delivery—albeit as an appraisal well—is a notable occurrence as a potential forerunner of shale gas production in Australia.

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