Optimised Chemical Management for Ichthys Offshore Gas Production

2021 ◽  
Author(s):  
Marc Lehmann ◽  
Steven Brunt ◽  
John Wyper ◽  
Barry Jewson ◽  
Gaganjot Lamba ◽  
...  
Keyword(s):  
Supply Chain ◽  
Gas Production ◽  
Regeneration System ◽  
North West ◽  
Safe Delivery ◽  
Hydrocarbon Processing ◽  
Central Processing ◽  
Chemical Management ◽  
Bulk Chemicals ◽  
Processing Facility

Abstract The Ichthys Field is located approximately 220 km north-west of the coast of mainland Western Australia and 820 km south-west of Darwin. Gas from the Ichthys Field undergoes processing on an offshore central processing facility (CPF) to dehydrate the gas and remove a Rich MEG phase and condensate. The dry gas is compressed and sent to Darwin via a gas export pipeline while the condensate and MEG are pumped to an interlinked floating production, storage, and offtake facility (FPSO) with hydrocarbon processing capabilities. The FPSO also features the world's largest offshore MEG regeneration system. An integrated chemical supply chain has been developed to deliver bulk chemicals from the vendor chemical supply base in Darwin to the offshore facilities. Delivery is facilitated by specially designed platform supply vessels (PSV) that carry bulk chemicals in dedicated storage tanks and transferred to the offshore facilities using bulk transfer hoses. This paper details aspects of the chemical supply chain and describes best practices that have been developed to manage the safe delivery of bulk chemicals from the chemical supplier to the operator.

Designing the world's largest semi-submersible central processing facility

2012 ◽  
Vol 52 (2) ◽  
pp. 685
Author(s):  
Claude Cahuzac
Keyword(s):  
Weather Conditions ◽  
Processing Unit ◽  
Gas Field ◽  
North West ◽  
Central Processing ◽  
Gas Processing ◽  
Design Considerations ◽  
Processing Facility ◽  
Production Wells ◽  
Sheer Size

What are the key design considerations driving the successful delivery of the world’s largest semi-submersible Central Processing Facility (CPF), to be installed at the Ichthys gas field in the Browse Basin, 200 km offshore North West Australia? Extreme cyclonic weather conditions, separating condensate from the gas stream, accommodating 150 personnel, and the sheer size of the gas processing unit at 110,000 tonnes, have created unprecedented challenges for the Ichthys design team. This extended abstract explores the design and planned construction of this massive piece of equipment. The CPF, measuring 110 m x 110 m, will be anchored to the seabed in about 250 m of water using 28 mooring chains. During the 40-year life of the project, the unit will collect gas from a network of up to 50 subsea production wells drilled into reservoirs 4,000–4,500 m beneath the seabed. From the CPF, condensate will be sent to a Floating Production Storage Offtake (FPSO) vessel moored nearby. The gas will be compressed and sent by an 885-km subsea pipeline to Darwin for processing into LNG, LPG and residual condensate. INPEX with its Ichthys joint venturer, Total, will be shipping 8.4 million tonnes of LNG and 1.6 million tonnes of LPG a year, as well as 100,000 barrels of condensate a day at peak. Successful delivery of the Ichthys Project will ensure INPEX achieves its goal of becoming the operator of a major LNG facility, while helping reach its target of producing 800,000 boe/d by 2020.

scholarly journals A Techno-economic Evaluation of Adding Silica Nanoparticles to Enhance the Demulsification Process in a Crude Oil Central Processing Facility

2021 ◽  
Author(s):  
Shireen Hassan ◽  
Babiker Abdalla ◽  
Mustafa Mustafa
Keyword(s):  
Economic Evaluation ◽  
Crude Oil ◽  
Silica Nanoparticles ◽  
Production Cost ◽  
Net Present Value ◽  
Central Processing ◽  
Oil Processing ◽  
Software Model ◽  
Processing Facility ◽  
Demulsification Process

In this study, a techno-economic evaluation of the use of silica nanoparticles to enhance the demulsification process, in crude oil, has been investigated. A software model has been developed in MS Excel of the central processing facility (CPF). A sensitivity analysis of key parameters on production cost and Net Present Value (NPV) has been carried out for different flowsheet selection options. Comparison of flowsheets on an equal plant capacity basis results in a 19% reduction in the production cost whereas comparison on a fixed annual crude oil processing basis results in a reduction in production cost of only 3.7%.

Distribution and estimates of Australia's identified energy commodity resources

2021 ◽  
Vol 61 (2) ◽  
pp. 325
Author(s):  
Barry E. Bradshaw ◽  
Meredith L. Orr ◽  
Tom Bernecker
Keyword(s):  
Natural Gas ◽  
Carbon Capture ◽  
Coal Gasification ◽  
Carbon Capture And Storage ◽  
Energy Resource ◽  
Gas Production ◽  
Renewable Energy Resources ◽  
North West ◽  
The North ◽  
Energy Provider

Australia is endowed with abundant, high-quality energy commodity resources, which provide reliable energy for domestic use and underpin our status as a major global energy provider. Australia has the world’s largest economic uranium resources, the third largest coal resources and substantial conventional and unconventional natural gas resources. Since 2015, Australia’s gas production has grown rapidly. This growth has been driven by a series of new liquefied natural gas (LNG) projects on the North West Shelf, together with established coal seam gas projects in Queensland. Results from Geoscience Australia’s 2021 edition of Australia’s energy commodity resources assessment highlight Australia’s endowment with abundant and widely distributed energy commodity resources. Knowledge of Australia’s existing and untapped energy resource potential provides industry and policy makers with a trusted source of data to compare and understand the value of these key energy commodities to domestic and world markets. A key component of Australia’s low emissions future will be the development of a hydrogen industry, with hydrogen being produced either through electrolysis of water using renewable energy resources (‘green’ hydrogen), or manufactured from natural gas or coal gasification, with carbon capture and storage of the co-produced carbon dioxide (‘blue’ hydrogen). Australia’s endowment with abundant natural gas resources will be a key enabler for our transition to a low emissions future through providing economically competitive feedstock for ‘blue’ hydrogen.

Impact of the Finance Act 2020 on Gas Utilization Projects

2021 ◽  
Author(s):  
Kaase Gbakon
Keyword(s):  
Oil And Gas ◽  
Oil And Gas Industry ◽  
Qualitative Assessment ◽  
Central Processing ◽  
Gas Processing ◽  
Gas Utilization ◽  
Processing Facility ◽  
Financing Costs ◽  
Investor Returns ◽  
The Impact

Abstract The newly passed Finance Act 2020 (FA2020) in Nigeria is reviewed especially as it relates to the oil and gas industry. The review is partly executed by modeling the specific provisions of the Act that impact gas utilization projects. The effect of the provisions on investor returns as well as the extent to which government objectives are met is ascertained – the government objectives being to prevent tax leakage via excessive financing costs, as well as encourage gas development and utilization. A qualitative assessment of the FA2020 is first conducted to examine its provisions applicable to the oil and gas sector. Furthermore, a spreadsheet Discounted Cash Flow (DCF) economic model of a gas central processing facility is built. A hypothetical $800Million (CapEx), 300mmscfd gas processing facility, which is 70% debt financed is modeled by incorporating the provisions of the FA2020. The metrics of the project (both investor and government) are then compared under the scenarios of with and without the FA2020. Key results indicate that the economic returns to investor in the gas processing facility are still largely preserved at a healthy level, even as government take improves by $102Million due to the FA2020. Specifically, without the FA2020, investor returns an IRR of 21.11% while due to the FA2020, investor IRR declines to 19.79%. Sensitivity analysis serves to illustrate one of the aims of the FA2020, which is to prevent tax loss from high cost of financing. Lengthening the tenor of loans reduces the fraction of the financing costs that is tax deductible. The modeling result shows that, ceteris paribus, for one (1) year increase in loan tenor, the amount of financing cost that is tax deductible reduces by 5%. Another important outcome is that for every $1 of government receipts preserved/enhanced by the FA, the investor NPV declines by 38cents This impact assessment of the FA2020 on gas utilization projects is conducted against the backdrop of several government pronouncements and policy positions to encourage domestic gas development. Financing plays an important role in delivering gas projects, consequently the evaluation of the impact of the FA2020 becomes imperative. This is to allow an examination of the effect of the Act on the ability to meet the strategic objective of powering the economy via gas while fulfilling Nigeria’s climate change commitments by deeper adoption of gas as a transition fuel.

Use of the gas production technique to investigate the supplementation of nitrogen-deficient foods

1998 ◽  
Vol 22 ◽  
pp. 202-204
Author(s):  
C. D. Wood ◽  
N. S. Prathalingam ◽  
A. M. Murray ◽  
R. W. Matthewman
Keyword(s):  
Nutritive Value ◽  
Developed Countries ◽  
Gas Production ◽  
Protein Supplementation ◽  
Free Medium ◽  
Production Technique ◽  
Protein Supplements ◽  
North West ◽  
Rich Media

A major focus for improving the diets in many less developed countries (LDCS) is the provision of rumen fermentable nitrogen (N) using protein supplements to complement N-deficient foods. However, in vitro digestibility methods usually use N-rich environments for the degradation of single foods. This conventional approach may give data which do not reflect the nutritive value of the N-deficient diets often on offer in LDCS, neither is it appropriate for using in vitro gas production to study protein supplementation. Our earlier study indicated that, by using a N-free medium, the gas production technique responded to added ammonium sulphate and urea. The ADAS standardized methodology, which used 10 ml of inoculum instead of the 5 ml used in the earlier study, was found not to be very responsive to N supplementation. The ADAS methodology was therefore investigated in order to develop a modified protocol for fermenting foods in an N-limited environment. The study involved using inocula diluted to different extents in N-free medium for fermenting N-deficient substrates in N-free and N-rich media. The modified protocol was then used for investigating the interactions between N-rich and N-deficient foods from north-west India.

JOHN BROOKES GAS FIELD DEVELOPMENT

2005 ◽  
Vol 45 (1) ◽  
pp. 13
Author(s):  
A.J. McDiarmid ◽  
P.T. Bingaman ◽  
S.T. Bingham ◽  
B. Kirk-Burnnand ◽  
D.P. Gilbert ◽  
...  
Keyword(s):  
Low Cost ◽  
Time Frame ◽  
Gas Production ◽  
Gas Field ◽  
Initial Development ◽  
North West ◽  
Field Development ◽  
The North ◽  
Production Wells ◽  
Development Approach

The John Brookes gas field was discovered by the drilling of John Brookes–1 in October 1998 and appraisal drilling was completed in 2003. The field is located about 40 km northwest of Barrow Island on the North West Shelf, offshore West Australia. The John Brookes structure is a large (>90 km2) anticline with >100 m closure mapped at the base of the regional seal. Recoverable sales gas in the John Brookes reservoir is about 1 Tcf.Joint venture approval to fast track the development was gained in January 2004 with a target of first gas production in June 2005. The short development time frame required parallel workflows and use of a flexible/low cost development approach proven by Apache in the area.The John Brookes development is sized for off-take rates up to 240 TJ/d of sales gas with the development costing A$229 million. The initial development will consist of three production wells tied into an unmanned, minimal facility wellhead platform. The platform will be connected to the existing East Spar gas processing facilities on Varanus Island by an 18-inch multi-phase trunkline. Increasing the output of the existing East Spar facility and installation of a new gas sweetening facility are required. From Varanus Island, the gas will be exported to the mainland by existing sales gas pipelines. Condensate will be exported from Varanus Island by tanker.

DRIVERS FOR THE DEVELOPMENT OF AN INTEGRATED SUPPLY BASE AND OFFSHORE SUPPLY CHAIN, NORTH WEST SHELF, AUSTRALIA

2004 ◽  
Vol 44 (1) ◽  
pp. 593
Author(s):  
E.D. Graham
Keyword(s):  
Supply Chain ◽  
Critical Mass ◽  
Cost Effective ◽  
Integrated Services ◽  
Economic Benefits ◽  
Security Issue ◽  
North West ◽  
The North ◽  
User Facility ◽  
Integrated Service

Since the commencement of the major developments on the North West Shelf, the offshore resource industry, during both its construction and operational phases, has faced considerable logistical impediments to cost-effective solutions for the offshore supply chain. These impediments have included distance, scant resources, lack of infrastructure both on and offshore and lack of critical mass.Throughout the world, offshore projects have greatly benefitted from the availability of integrated services to cater for the transport of equipment from the point of manufacture or distribution to the offshore location.Within the Australian context the privately controlled Esso Barry Beach and Dampier Woodside facilities are examples of integrated services, but both differ considerably from a public multi-user facility. The model used in the Timor Sea of one vessel or vessels for the use of several operators is another example.The NorthWest Shelf has now reached the critical mass and it became apparent several years ago that the area needed an integrated supply base available to multiple operators. It would need to include a heavy loadout wharf, laydown areas, slipway and engineering facilities and office space to service forthcoming projects, as well as planning and cooperation amongst all players to maximise efficiency and use of scant resources as drivers for economic benefits to offshore operators in the region.Furthermore the fallout from the events of 11 September 2001 and continuing threats of terrorism has meant the security of marine assets has become an important part of each operator’s everyday life. The introduction of new legislation relating to this security issue is planned for mid 2004.In 2000 and 2001 Mermaid Marine Australia Limited undertook a major expansion of its Dampier supply base, and established a world-class facility to meet the growing demands of the region.This complex has for the first time provided the northwest of Australia, particularly the North West Shelf, Carnarvon Basin and the onshore developments on the Burrup Peninsula, with a facility for offloading and loadout of heavy shipments and fabrication and slipway facilities, coupled with the advantages of a large supply base. This facility can also be expanded to meet growth and the emerging requirements related to security.This paper describes the drivers for change commencing with the earliest supply chains and following through to the integrated service now availabe. These drivers meet the requirements of the offshore operators in the region as well as showing the benefits anticipated from this integrated service. The paper also outlines in detail the requirements of the International Maritime Organisation for worldwide changes to port and offshore security.

Production and development across Australia 2016

2017 ◽  
Vol 57 (2) ◽  
pp. 363
Author(s):  
Frankie Cullen
Keyword(s):  
Coalbed Methane ◽  
East Coast ◽  
Price Volatility ◽  
Volatile Oil ◽  
Gas Production ◽  
North West ◽  
The North ◽  
Start Up ◽  
Reduction Strategies ◽  
Gas Supply

In 2016, sustained depressed and volatile oil prices led companies to continue cost reduction strategies. Proposed developments have seen delays and reductions in scope as a result. Australian oil production declined by around 10%. However, new and continued liquefied natural gas (LNG) production bolstered both Australian and global gas supply. Australia was the strongest contributor to global LNG growth in 2016, showing the biggest year-on-year increase. In the first half of 2016, 20% of global LNG came from Australia, second only to Qatar with 29% of the market share. Australia remains on track to become the world’s largest LNG producer in the next 3–5 years. 2016 saw the start-up of Gorgon LNG in March, the first of Chevron’s two North West Shelf LNG projects and the third of several producing, developing and proposed LNG projects within the North Carnarvon Basin – already Australia’s most prolific producing basin. On the east coast, development of the coalbed methane (CBM) to LNG projects continued with an additional train brought onstream at each of the Origin/ConocoPhillips-operated APLNG Project and Santos’ GLNG Project. This further increased production in the Bowen–Surat Basins and drove discussions around the ability of east coast gas to meet both the demands of the LNG projects and ensure continued domestic gas reliability. Additional gas may be required for both, opening opportunities for production from other basins. Gas production continues to drive the Australian industry, with substantial inputs from LNG and unconventional operations. The next phase, in all sectors, will be key to Australia’s future in the global energy market. Will it be able to overcome the expected challenges of global oversupply, continued price volatility and domestic reliability concerns to fulfil its potential?

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