Prognosis of Oil Fringes in Gas Fields of the North-West Siberia: ABSTRACT

The narrow-leafed lupin (Lupinus angustifolius L.) is a valuable legumes crop used as forage and green manure which is adapted to wide spectrum of soil-and climatic conditions; the crop has short domestication history. The protein content in its seeds and in dry matter of green mass varies from 30.0 to 37.0% and from 16.0 to 22.0 % respectively and depends on ecotype and soil-and-climatic conditions. This lupin specie can accumulate to 300 kg/ha symbiotic nitrogen in biomass and assimilates phosphorus and potassium of heavy available soil layers. It is very technological suitable for common used machinery systems. The State List of breeding achievements of Russia recommends the following regions for lupin cultivation: the North, the North-West, the Central, the Volga-Vyatka, the Middle-Volga, the Central Chernozem, the Ural, the West Siberia and the East Siberia. The tests were carried out in 2017-2020 in the All-Russian Lupin Scientific Research Institute which is located in the South-West of the Central region. Ten varieties and breeding lines bred in the Institute are tested. The samples differ by early ripeness and anthracnose tolerance. The average experimental variety grain yield was 2.38 t/ha. The vars. Uzkolistny 53-02, USN 53-236, Bryanskiy kormovoy and SBS 56-15 have the highest yield and adaptivity (103-113 %). The index of year conditions was revealed; 2017 with the index 0.56 was the most favorable for implementation of grain productivity of the tested narrow-leafed lupin varieties. In the ecological varieties testing the soil-and-climatic conditions of Shatilovskaya experimental station (Orel region) were the most favorable for implementation of variety grain productivity (4.0-4.5 t/ha). Grain yield was 3.0-4.0 t/ha in ecological locations which differ in soil-and-climatic conditions: there are Kaliningrad region, Mordovia Republic, Krasnoyarsk region etc.

Download Full-text

Early Production Life of Wheatstone Project Offshore Australia Yields Key Lessons

Journal of Petroleum Technology ◽

10.2118/0821-0051-jpt ◽

2021 ◽

Vol 73 (08) ◽

pp. 51-52

Author(s):

Chris Carpenter

Keyword(s):

Oil And Gas ◽

Asia Pacific ◽

North West ◽

The North ◽

Sand Control ◽

Single Well ◽

Early Production ◽

Northern Carnarvon Basin ◽

Shelf Region ◽

Gas Fields

This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 202246, “Wheatstone: What We Have Learned in Early Production Life,” by John Pescod, SPE, Paul Connell, SPE, and Zhi Xia, Chevron, 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. Wheatstone and Iago gas fields, part of the larger Wheatstone project, commenced production in June 2017. The foundation subsea system includes nine Wheatstone and Iago development wells tied back to a central Wheatstone platform (WP) for processing. Hydrocarbons then flow through an export pipeline to an onshore processing facility that includes two liquefied-natural-gas (LNG) trains and a domestic gas facility. The complete paper highlights some of the key learnings in well and reservoir surveillance analysis and optimization (SA&O) developed using data from early production. Asset Overview Chevron Australia’s Wheatstone project is in the North West Shelf region offshore Australia (Fig. 1). Two gas fields, Wheatstone and Iago (along with a field operated by a different company), currently tie into the WP in the Northern Carnarvon Basin. These two gas fields are in water depths between 150 and 400 m. The platform processes gas and condensate through dehydration and compression facilities before export by a 220-km, 44-in., trunkline to two 4.45-million-tonnes/year LNG trains and a 200 tera-joule/day domestic gas plant. A Wheatstone/Iago subsea system consisting of two main corridors delivers production from north and south of the Wheatstone and Iago fields to the WP. Currently, the subsea system consists of nine subsea foundation development wells, three subsea production manifolds, two subsea 24-in. production flowlines, and two subsea 14-in. utility lines. The nine foundation development wells feed the subsea manifolds at rates of up to 250 MMscf/D. These wells have openhole gravel-pack completions for active sand control and permanent downhole gauges situated approximately 1000-m true vertical depth above the top porosity of multi-Darcy reservoir intervals for pressure and temperature monitoring. All wells deviate between 45 and 60° through the reservoir with stepout lengths of up to 2.5 km. The two subsea 24-in. production flowlines carry production fluids from the subsea manifolds to two separation trains on the WP. Each platform inlet production separator can handle up to 800 MMscf/D. The two 14-in. utility flowlines installed to the subsea manifolds allow routing of a single well to the platform multiuse header, which can direct flow into the multiuse separator (MUS) or other production separators at a rate of 250 MMscf/D.

Download Full-text

2010 environmental update

The APPEA Journal ◽

10.1071/aj10012 ◽

2011 ◽

Vol 51 (1) ◽

pp. 179

Author(s):

Alastair Sharp-Paul ◽

Alexandra Hare ◽

Alice Turnbull ◽

Tara Halliday

Keyword(s):

Oil And Gas ◽

Oil And Gas Industry ◽

Environmental Research ◽

Gas Industry ◽

North West ◽

The North ◽

The Usa ◽

Policy And Suggestion ◽

High Level ◽

Gas Fields

Focusing on Australian projects, this paper provides a summary of the key environmental challenges and developments that arose in 2010 and the industry’s response. The paper considers: developments in legislation and the regulatory environment relating to environmental approvals and management; major project approvals and their environmental requirements and implications; key environmental incidents; and reviews new environmental research and management initiatives that were introduced by the industry. A number of states have introduced changes to the way legislation and regulations are interpreted through changes to guidelines and administrative procedures. There has been a general increase in the standard and level of information that regulators expect proponents to provide and while generally these expectations are documented in guidelines and other documents, in some instances there has been a perceived ‘moving of the goal posts’ without clear guidance on what is expected and how the information will be considered once provided. There has been a number of major projects either commencing or gaining environmental approval in 2010. This includes major projects: in Western Australia, on the North West Shelf and in the Timor Sea/Browse Basin; onshore in Queensland in the coal-seam gas fields and continued exploration and development both onshore and offshore around Australia. One of the most significant approvals in 2010 was the Prelude LNG Project–the first approval in Australia of floating LNG technology. Major environmental incidents in 2009 (Montara in Australia and Macondo in the USA) continued to have repercussions in 2010 with the draft government response to the Report of the Montara Commission of Inquiry released in November. These incidents have put the oil and gas industry under the spotlight and this paper looks at some of the statistics on the frequency and severity of environmental incidents, albeit at a high level. Finally, the industry has continued to implement a number of environmentally related initiatives both in response to government policy and suggestion and independently through groups such as the APPEA environment committee.

Download Full-text

HARRIET GAS GATHERING PROJECT, BARROW SUB-BASIN

The APPEA Journal ◽

10.1071/aj91006 ◽

1992 ◽

Vol 32 (1) ◽

pp. 56

Author(s):

Adrian Williams ◽

Dave Macey

Keyword(s):

Offshore Platforms ◽

Gas Field ◽

North West ◽

Associated Gas ◽

The North ◽

Wet Gas ◽

Start Up ◽

New Development ◽

Transmission Pipeline ◽

Gas Fields

Since start-up of Harriet oil production in early 1986, the TL/1 joint venturers have attempted to find a use for the oil-associated gas as well as other gas from neighbouring small gas fields. Initially, supplies from the North West Shelf Project were well in excess of local demand and acted as a damper on new development projects. With time, however, gas reserves in the Harriet area were augmented through new discoveries and the State's demand grew steadily until, in mid 1990, a new project could be justified. In December 1990, an agreement was reached with the State Energy Commission of Western Australia (SECWA) for the supply of 140 PJ (123 BCF) of gas over a ten year period, with an option for a further 65 PJ (57 BCF). First gas supplies are planned for June 1992.The project is based on the supply of Harriet solution gas as well as free gas from the Campbell, Sinbad and Rosette fields. Bambra is a potential future addition but is not required initially for the contract.The project involves small offshore platforms at Campbell and Sinbad, a wet gas pipeline from these platforms to Varanus Island, a facility on the Island to dry the gas and boost the pressure, and a transmission line to SECWA's system, approximately 100 km distant.The transmission pipeline has considerable reserve capacity over the initial contract flowrate of 30 to 60 TJ/day (26 to 52 MMCFGD) and provides a basis for further small gas projects utilising either flare gas from new oil developments or new gas field developments.

Download Full-text

AUSTRALIA'S PETROLEUM PROSPECTS: CHANGING PERCEPTIONS SINCE THE BEGINNING OF THE CENTURY

The APPEA Journal ◽

10.1071/aj87016 ◽

1988 ◽

Vol 28 (1) ◽

pp. 190

Author(s):

C.S. Robertson

Keyword(s):

Considerable Change ◽

Probabilistic Methods ◽

Petroleum Potential ◽

North West ◽

The North ◽

Continental Plate ◽

Most Significant Change ◽

Current Assessment ◽

Gas Fields

Perceptions of Australia's petroleum prospectivity, both by the general public and by professional explorationists, have changed considerably over the years. By the 1920s there had already been a considerable change from the optimism of the early part of the century, engendered largely by gas and condensate indications in water bores drilled in the Roma area, to a comparatively pessimistic view due to the failure of numerous small drilling ventures, and to the published opinions of some overseas experts.The public then remained generally apathetic or pessimistic about Australia's petroleum future until the Rough Range discovery in 1953 finally dispelled the myth that Australia was barren of producible oil. Rough Range proved to be the first of a series of discoveries which significantly upgraded industry and public perceptions of Australia's petroleum potential.Other particularly significant discoveries were the Moonie oilfield in 1961, the Gidgealpa and Barracouta gas fields in 1963 and 1964, the giant King-fish and Halibut oilfields in 1967, gas/condensate and oilfields on the North West Shelf in 1971, the Strzelecki and Fortescue oilfields in 1978, and the Jabiru oilfield in 1983. Exploration of the Exmouth Plateau from the early 1970s onwards initially caused a significant increase in estimates of Australia's petroleum potential, followed by downward revisions in the early 1980s because of the failure of the Plateau to live up to expectations.Perceptions of the prospects of some individual basins have also changed dramatically with time. Notable examples are the onshore Carnarvon Basin, the Georgina Basin and the Eromanga Basin.The most significant change in methods of assessing Australia's prospectivity was the introduction of quantitative, probabilistic methods in the 1970s. BMR's current assessment is that we can expect to find an additional 2 400 million barrels of oil, 23 trillion cubic feet of gas, and 550 million barrels of condensate on the Australian continental plate (average estimates).

Download Full-text

New cryptogamic records. 8

Novosti sistematiki nizshikh rastenii ◽

10.31111/nsnr/2021.55.2.495 ◽

2021 ◽

Vol 55 (2) ◽

pp. 495-516

Author(s):

V. M. Kotkova ◽

O. M. Afonina ◽

T. Dejidmaa ◽

G. Ya. Doroshina ◽

O. V. Erokhina ◽

...

Keyword(s):

West Siberia ◽

Botanical Garden ◽

Leningrad Region ◽

Taimyr Peninsula ◽

North West ◽

The North ◽

Experimental Botany ◽

The Republic ◽

North Ossetia ◽

Nenets Autonomous

First records of silica-scaled chrysophyte alga for the Leningrad Region and North-West of European Russia, fungi for the Pskov and Novosibirsk regions, and the Republic of Tuva, myxomycetes for the Republic of Belarus, lichens for the Yamal-Nenets Autonomous Area and West Siberia, liverworts for the Kurgan Region, mosses for the Republic of North Ossetia – Alania, the Taimyr Peninsula, the Chukotka Autonomous Area, and the Kamchatka Territory from the North Koryakia are presented. The data on their localities, habitats, distribution, and specimens are provided. The specimens are kept in the Herbarium of the Komarov Botanical Institute RAS (LE), the Herbarium of M. G. Popov at the Central Siberian Botanical Garden RAS (NSK), or the Herbarium of the Kuprevich Institute of Experimental Botany NAS of Belarus (MSK-F).

Download Full-text

Burial practices of the population from the Konda River Basin in the Mesolithic and Neolithic Periods

Samara Journal of Science ◽

10.17816/snv202091202 ◽

2020 ◽

Vol 9 (1) ◽

pp. 131-141

Author(s):

Tatyana Yuryevna Klementyeva ◽

Andrey Albertovich Pogodin

Keyword(s):

River Basin ◽

West Siberia ◽

Stone Age ◽

Conifer Forest ◽

Burial Practices ◽

North West ◽

The North ◽

The Dead ◽

Special Respect ◽

Mesolithic Burials

The paper is dedicated to burial practices of the Stone Age population that inhabited the territory of the North-West Siberia. The source base is represented by 14 complexes. The burial grounds and solitary graves are located on high slopes in the terrace conifer forest areas along the tributaries of the Konda River. The Mesolithic burials date back to the period starting from the 9th-8th millennium BC through the end of the 7th millennium BC, while the Neolithic can be traced starting from the 7th-6th millennium BC to the middle of the 4th millennium BC. The taiga hunters traditionally buried their deceased relatives in the ground. The burials tend to be clustered into linear groupings within the cemetery area. Solitary graves are found on the territory of apparently abandoned settlements near the foundation pits of houses or inside them. Two forms of burial were practiced: inhumation and cremation followed by the burial of burnt remains. Generally, the dead were buried in the extended position, i.e., lying flat with arms and legs straight. The bodies were covered with red ocher, wrapped or swaddled, and put into graves. A special type of Mesolithic burials was vertical burials, i.e., the dead were placed into a vertical shaft like pits. The cremated remains were buried in ocher graves. The burned bones were placed in the center of each pit. Solitary burials prevailed. Less common were paired and multi-tire graves. Children were buried in the same way as adults, the age range of the dead varied from 5-7 to 60 years. The deceased were buried together with stone tools, jewelry, fragments of dishes, funeral and memorial food. The burial things were prepared following a special ritual - the blades of stone adzes were sharpened, the pottery was broken. There are signs of special respect to the skulls of the dead. The traditional burial practices of the taiga population from the Konda River Basin remained the same throughout the Stone Age.

Download Full-text

2013 PESA production and development review

The APPEA Journal ◽

10.1071/aj13044 ◽

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.

Download Full-text

INTEGRATED MULTI-DISCIPLINARY ANALYSIS OF THE RANKIN TREND GAS RESERVOIRS NORTH WEST SHELF, AUSTRALIA

The APPEA Journal ◽

10.1071/aj06003 ◽

2007 ◽

Vol 47 (1) ◽

pp. 55 ◽

Cited By ~ 2

Author(s):

R.J. Seggie ◽

S.C. Lang ◽

N.M. Marshall ◽

C.J. Cubitt ◽

D. Alsop ◽

...

Keyword(s):

Regional Scale ◽

Seismic Survey ◽

Gas Reservoirs ◽

North West ◽

Sequence Stratigraphic ◽

The North ◽

Stratigraphic Framework ◽

Hydrodynamic Data ◽

Gas Fields ◽

Stacking Patterns

An integrated geological study of the Rankin Trend of the North West Shelf, Australia, was undertaken to underpin the ongoing development of the giant gas fields it contains. The study applied an improved understanding ofthe regional stratigraphy in conjunction with interpretation of the regional-scale Demeter 3D seismic survey and focussed on existing fields, undeveloped discoveries, and exploration prospects. The study included a redescription of 1,500 m of core, a new facies-based petrological analysis, a revision of the well-based stratigraphy and palaeogeographic mapping, and a seismic stratigraphic analysis. Reservoir production and hydrodynamic data were also integrated. The stratigraphic framework was improved by implementing a broad range of depositional and facies analogues and a system-wide sequence stratigraphic approach to understanding lateral and vertical stacking patterns of the reservoir succession. Visualisation and modelling technologies were also employed to more adequately describe genetic reservoir packages.Specific outcomes include: improved correlation of reservoir sequences, application of appropriate subsurface depositional analogues to field descriptions, updated palaeogeographic maps and recognition of palaeosols as stratigraphic marker horizons—resulting in a more consistent regional interpretation framework. This forms the basis for seismic stratigraphic interpretation away from well control.The new regional geological model has enabled the linkage of exploration, development and production understanding across the North West Shelf assets as well as management of geological uncertainties.

Download Full-text

ASSESSMENT OF GAS HYDRATE RESOURCES IN THE EAST-MESSOYAKHA FIELD

Oil and Gas Studies ◽

10.31660/0445-0108-2015-4-40-44 ◽

2015 ◽

pp. 40-44

Author(s):

A. V. Podnebesnykh ◽

Yu. V. Maryanovich ◽

S. V. Kuznetsov ◽

V. P. Ovchinnikov

Keyword(s):

Gas Hydrates ◽

Gas Hydrate ◽

West Siberia ◽

Fuel Production ◽

Real Potential ◽

The North ◽

Gas Fields

On the example of one of the fields in the North of West Siberia the issues of assessment of gas hydrate resources are considered. Gas hydrates are one of the most perspective types of fuel and in the nearest future can come to replace the major gas fields in the territory of West Siberia. In this work an attempt was made to define the search characteristics allowing the identification of gas hydrates deposits and estimation of a real potential of this type of fuel production.

Download Full-text