The Halladale–Speculant fields: the first nearshore gas fields to be developed from mainland Australia

2018 ◽  
Vol 58 (1) ◽  
pp. 255
Author(s):  
Andrew Constantine ◽  
Glenn Morgan ◽  
Robin O'Leary ◽  
Simon Smith
Keyword(s):  
Cost Effective ◽  
Lattice Energy ◽  
Vertical Wells ◽  
Gas Field ◽  
Development Costs ◽  
Exploration And Production ◽  
Drilling Technology ◽  
Access Problems ◽  
Seismic Acquisition ◽  
Gas Fields

Extended-reach drilling (ERD) is becoming an increasingly common technique used to explore for hydrocarbons and develop fields in areas where simple vertical wells cannot be drilled due to access problems, stakeholder concerns, environmental issues, poor reservoir quality and/or cost. While these types of wells are generally more expensive and technically challenging to drill than vertical wells, they can be very cost-effective, and if a discovery is made, considerably quicker to monetise when future development costs are also taken into consideration, particularly in offshore environments. In 2014–2015, the conventional Exploration and Production division of Origin Energy (now Lattice Energy) drilled three onshore-to-offshore ERD wells and a geological sidetrack in the Otway Basin with horizontal offsets of 1929, 2576, 4239 and 5152 m targeting an undeveloped gas field (Halladale) and exploration prospect (Speculant) located in Victorian state waters near Port Campbell. The three wells (Halladale-2, Speculant-1 and Speculant-2) and sidetrack (Speculant-2ST1) were drilled during a single drilling campaign from the same pad to reduce mobilisation, drilling and development costs. Halladale-2 was designed to develop the Halladale Field, while Speculant-1, -2 and -2ST1 were designed to evaluate the Speculant Prospect. Both Speculant wells and the sidetrack encountered significant gas columns with Speculant-1 and Speculant-2ST1 subsequently completed as producers after being successfully flow tested. A 33 km onshore pipeline was then constructed to transport the gas from Halladale and Speculant back to the Otway Gas Plant (OGP) for processing and sale. The arrival of first gas at the OGP from the Halladale and Speculant gas fields on 26 August 2016 marked a significant milestone for Origin Energy in terms of accelerated project delivery. It also represented the end of a 15-year journey for Halladale from exploration to discovery to development. The drilling campaign also set several records in the process with: (1) Speculant being the first offshore field to be discovered from mainland Australia; (2) Halladale and Speculant being the first offshore fields to produce gas back to mainland Australia from onshore wells; (3) Halladale-2, Speculant-1 and Speculant-2 being the three longest onshore-to-offshore wells drilled to date in Australia (in horizontal departure terms); and (4) Halladale-2 being the longest well (in mMDRT terms) drilled to date in the Otway Basin. Speculant is a good example of how transition zone (TZ) seismic and ERD technology can be used successfully to explore and develop resources in areas previously considered too difficult by using more conventional seismic acquisition and drilling technology.

Natural gas separation at CO2CRC's Otway National Research Facility

2019 ◽  
Vol 59 (2) ◽  
pp. 803
Author(s):  
Abdul Qader ◽  
Jai Kant Pandit
Keyword(s):  
Natural Gas ◽  
Gas Separation ◽  
Cost Effective ◽  
Commercial Application ◽  
Research Facility ◽  
Gas Field ◽  
South Wales ◽  
Effective Manner ◽  
Gas Fields ◽  
The University

CO2CRC, in collaboration with the University of Melbourne and the University of New South Wales, is testing two novel CO2 capture technologies designed for both on-shore and off-shore natural gas applications in a state-of-the-art experimental capture rig at CO2CRC’s Otway National Research Facility. The goal is to develop robust and compact technology for high pressure natural gas separation over a range of adjusted high CO2 concentrations mimicking various gas field conditions. These technologies would facilitate developing new gas fields to recover methane in a cost-effective manner which is currently uneconomical with conventional technologies. In the first stage of testing, commercially available materials (adsorbents and membranes) were used for benchmarking. Results from both adsorbent and membrane technologies are encouraging with respect to recovery and purity of CO2 and methane with the prospect of commercial application.

THE DEVELOPMENT OF THE GREATER GORGON GAS FIELDS

2003 ◽  
Vol 43 (2) ◽  
pp. 167
Author(s):  
P.M. Oen
Keyword(s):  
Gas Field ◽  
Gas Processing ◽  
National Importance ◽  
Commercial Viability ◽  
Development Costs ◽  
World Class ◽  
State Taxes ◽  
Carbon Dioxide Co2 ◽  
Gas Fields ◽  
Western Australian

The vast reservoirs of untapped natural gas found in the Greater Gorgon area off Western Australia’s Pilbara coast contain in excess of 11 billion cubic metres (40 trillion cubic feet) of gas, representing some 25% of Australia’s total known gas resources. Developing this world-class resource is a matter of national importance as it would secure Australia’s position as a leading gas producer and provide a huge new source of wealth for both Australia and Western Australia.The key to unlocking the Greater Gorgon reserves is the development of the Gorgon field—one of the largest single gas fields ever discovered in Australia. Establishment of gas processing infrastructure on Barrow Island—which lies between the gas field and the mainland—would provide a catalyst for the future development of other Greater Gorgon area fields. Gas would be processed at that facility and transported through a gas pipeline to shore, enabling large new competitive supplies of gas to be delivered to the mainland.While the development of Gorgon gas would bring significant benefits—A$11 billion investment, A$17 billion in Commonwealth and State taxes and royalties and an annual increase in the nation’s export income of A$2.5 billion—the Gorgon gas field presents some unique challenges. With little associated liquid hydrocarbons, development costs must be kept to a minimum to maintain commercial viability. In addition, Gorgon gas contains a relatively high content of carbon dioxide (CO2) which results in substantial treatment cost and relatively large potential greenhouse gas emissions.Barrow Island—both an internationally important nature reserve and Australia’s largest operating onshore oilfield—has emerged as the development location that would enable gas from the Gorgon gas fields to be competitive in today’s market. The Western Australian Government has said the Gorgon venture (ChevronTexaco, Shell and ExxonMobil) must demonstrate at a strategic level that the proposed Gorgon gas development on Barrow Island can generate economic and social benefits, provide net conservation benefits and mitigate potential on-site impacts.

THE EXPLORATION AND APPRAISAL HISTORY OF THE KATNOOK AND LADBROKE GROVE GAS FIELDS, ONSHORE OTWAY BASIN, SOUTH AUSTRALIA

1992 ◽  
Vol 32 (1) ◽  
pp. 67 ◽  
Author(s):  
K. A. Parker
Keyword(s):  
South Australia ◽  
Subsequent Development ◽  
Hydrocarbon Exploration ◽  
Gas Field ◽  
Water Contact ◽  
Field Development ◽  
Gas Accumulation ◽  
Seismic Acquisition ◽  
History Of ◽  
Gas Fields

The discoveries of the Katnook Field and, later, the Ladbroke Grove Field were significant milestones for hydrocarbon exploration in the southeast of South Australia as well as for the Otway Basin in general. The initial 1987 discovery at Katnook-1 of a relatively shallow gas accumulation in the basal part of the Eumeralla Formation was eclipsed in late 1988 at the Katnook-2 appraisal stage where deeper and more significant gas reserves were discovered in the Pretty Hill Sandstone.Technological improvement, in seismic acquisition, in particular, use of longer offset configurations and higher fold, and in filtering and correction techniques at the processing stage, are discussed in relation to improved geologic understanding. These aspects ultimately led to drilling success in both exploration and appraisal.At the deep Katnook discovery stage several significant problem areas remained unresolved. These related to uncertainties in vertical distribution of gas pay, level of a gas-water contact, and unreliable reserve estimates the result of the inability of conventional log analysis techniques to distinguish gas-bearing from water-bearing sands. Both in the evaluation of Katnook-2 and at the Katnook-3 appraisal stage, expensive cased-hole testing programs were undertaken to determine the size, extent and producibility of the gas accumulation. A key development between drilling Katnook-2 and Katnook-3 was the discovery of carbon dioxide-rich gas at Ladbroke Grove during 1989 in an adjacent structure to the south.The Katnook Field was the first commercial gas field development in the southeast, South Australian part of the Otway Basin, with gas sales commencing in March 1991, within a year of completing field appraisal. The discoveries, and subsequent development, have led to a renewed focus on the Otway Basin as a prospective hydrocarbon province.

Experimental Research on Erosion of P110 Tubing during Perforating

2014 ◽  
Vol 1073-1076 ◽  
pp. 2244-2247
Author(s):  
Hu Sun ◽  
Zhi Jun Ning ◽  
Zu Wen Wang ◽  
Zhen Li ◽  
Zhi Guo Wang
Keyword(s):  
Weight Loss ◽  
Erosion Rate ◽  
Large Scale ◽  
Guar Gum ◽  
Electrochemical Corrosion ◽  
Low Velocity ◽  
Gas Field ◽  
Weight Loss Method ◽  
Loss Method ◽  
Gas Fields

Erosion is a main failure of tubings and downhole tools in Changqing gas field. It is necessary to evaluate the erosion rate for the safety of tubing and strings. In this paper, the erosion of P110 steel, in the 0.2%wt guar gum fracturing fluid which contains sands, is investigated by weight loss method in the self-made jet experiment device. It is indicated that the erosion rate increases with the increment of slurry velocity exponentially. When the slurry velocity is in low velocity area, the electrochemical corrosion of dissolved oxygen dominates in erosion mechanism; when slurry velocity increases into middle velocity area, the weight loss is controlled by the synergism of corrosion-erosion; and when the slurry velocity increases into high velocity area, the weight loss rate is dominantly depended on erosion of particles. The results can provide guidelines for large-scale fracturing work of Changqing gas fields.

Petroleum Accessibility and Drilling Technology: An Analysis of U.S. Development Costs from 1959 to 1978

1986 ◽  
Vol 62 (1) ◽  
pp. 14 ◽  
Author(s):  
Richard B. Norgaard ◽  
Gwo Jiun Leu
Keyword(s):  
Development Costs ◽  
Drilling Technology

Pseudo Dry Gas Technology: Pathway to Decarbonisation of Energy Consumption for Remote Offshore Gas Fields

2021 ◽  
Author(s):  
Tran Nguyet Ngo ◽  
Lee Thomas ◽  
Kavitha Raghavendra ◽  
Terry Wood
Keyword(s):  
Energy Consumption ◽  
Energy Transition ◽  
High Energy ◽  
Innovative Technology ◽  
Flow Loop ◽  
Gas Field ◽  
Power Requirement ◽  
Order Of Magnitude ◽  
Gas Fields ◽  
Technology Pathway

Abstract Transporting large volumes of gas over long distances from further and deeper waters remains a significant challenge in making remote offshore gas field developments technologically and economically viable. The conventional development options include subsea compression, floating topside with topside compression and pipeline tie-back to shore, or floating liquefied natural gas vessels. However, these options are CAPEX and OPEX intensive and require high energy consumption. Demand for a lower emission solution is increasingly seen as the growing trend of global energy transition. Pseudo Dry Gas (PDG) technology is being developed by Intecsea, Worley Group and The Oil & Gas Technology Centre (Aberdeen) and tested in collaboration with Cranfield University. This is applied to develop stranded or remote gas reserves by removing fluids at the earliest point of accumulation at multiple locations, resulting in near dry gas performance. This technology aims to solve liquid management issues and subsequently allows for energy efficient transportation of the subsea gas enabling dramatic reductions in emissions. The PDG prototype tested using the Flow Loop facilities at Cranfield University has demonstrated the concept’s feasibility. Due to a greater amount of gas recovered with a much lower power requirement, the CO2 emissions per ton of gas produced via the PDG concept is by an order of magnitude lower than conventional methods. This study showed a reduction of 65% to 80% against standard and alternative near future development options. The paper considers innovative technology and a value proposition for the Pseudo Dry Gas concept based on a benchmarked study of a remote offshore gas field. The basin was located in 2000m of water depth, with a 200km long subsea tie-back. To date the longest tieback studied was 350km. It focused on energy consumption and carbon emission aspects. The conclusion is that decarbonisation of energy consumption is technically possible and can be deployed subsea to help meet this future challenge and push the envelope of subsea gas tie-backs.

scholarly journals The Development of a Low-Cost Method for Monitoring Methane Leakage from the Subsurface of Natural Gas Fields

Methane ◽  
2021 ◽  
Vol 1 (1) ◽  
pp. 24-37
Author(s):  
Muhammad Alfiza Farhan ◽  
Yuichi Sugai ◽  
Nuhindro Priagung Widodo ◽  
Syafrizal Syafrizal
Keyword(s):  
Activated Carbon ◽  
Natural Gas ◽  
Methane Concentration ◽  
Low Cost ◽  
Gas Field ◽  
Methane Leakage ◽  
Wide Scale ◽  
Adsorbed Methane ◽  
In The Beginning ◽  
Gas Fields

The leakage of methane from the subsurface on the coalfield or natural gas field invariably becomes an important issue nowadays. In notable addition, materials such as activated carbon, zeolites, and Porapak have been successfully identified as adsorbents. Those adsorbents could adsorb methane at atmospheric pressure and room temperature. Therefore, in this scholarly study, a new method using adsorbents to detect points of methane leakage that can cover a wide-scale area was developed. In the beginning, the most capable adsorbent should be determined by quantifying adsorbed methane amount. Furthermore, checking the possibility of adsorption in the column diffusion and desorption method of adsorbents is equally necessary. The most capable adsorbent was activated carbon (AC), which can adsorb 1.187 × 10−3 mg-CH4/g-AC. Hereinafter, activated carbon successfully can adsorb methane through column diffusion, which simulates the situation of on-site measurement. The specific amount of adsorbed methane when the initial concentrations of CH4 in a bag were 200 ppm, 100 ppm, and 50 ppm was found to be 0.818 × 10−3 mg-CH4/g-AC, 0.397 × 10−3 mg-CH4/g-AC, 0.161 × 10−3 mg-CH4/g-AC, respectively. Desorption of activated carbon analysis shows that methane concentration increases during an hour in the temperature bath under 80 °C. In conclusion, soil methane leakage points can be detected using activated carbon by identifying the observed methane concentration increase.

scholarly journals EXPLORATION AND PRODUCTION OF OIL AND GAS BASED ON THE GEOSOLITON MODELS AND TECHNOLOGIES

2016 ◽  
pp. 12-17
Author(s):  
R. M. Bembel ◽  
M. R. Bembel ◽  
D. M. Sahipov ◽  
I. A. Schetinin
Keyword(s):  
Oil And Gas ◽  
The Earth ◽  
Development Costs ◽  
Production Wells ◽  
Exploration And Production ◽  
Exploration And Development

It is proposed on the basis of special technologies use to ensure a multiple reduction of exploration and development costs at significant increasing the production volumes. This is achieved by optimizing the placement of exploration and production wells in the immediate vicinity of the centers of geosoliton degassing of the Earth.

scholarly journals All-Metal Terahertz Metamaterial Biosensor for Protein Detection

2021 ◽  
Author(s):  
Gangqi Wang ◽  
Fengjie Zhu ◽  
Tingting Lang ◽  
Jianjun Liu ◽  
Zhi Hong ◽  
...  
Keyword(s):  
Stainless Steel ◽  
Refractive Index ◽  
Bovine Serum Albumin ◽  
Figure Of Merit ◽  
Limit Of Detection ◽  
Protein Detection ◽  
Cost Effective ◽  
Detection Sensitivity ◽  
Drilling Technology ◽  
Simulation Results

Abstract In this paper, a terahertz (THz) biosensor based on all-metal metamaterial is theoretically investigated and experimentally verified. This THz metamaterial biosensor uses stainless steel materials that are manufactured via laser-drilling technology. The simulation results show that the maximum refractive index (RI) sensitivity and the figure of merit (FOM) of this metamaterial sensor are 294.95 GHz/RIU and 4.03, respectively. Then, bovine serum albumin (BSA) was chosen as the detection substance to assess this biosensor’s effectiveness. The experiment results show that the detection sensitivity is 72.81 GHz/(ng/mm2) and the limit of detection (LOD) is 0.035 mg/mL. This THz metamaterial biosensor is simple, cost-effective, easy to fabricate, and have great potential in various biosensing applications.

scholarly journals About this title - United Kingdom Oil and Gas Fields: 50th Anniversary Commemorative Volume

10.1144/m52 ◽  
2020 ◽  
Vol 52 (1) ◽  
pp. NP.1-NP
Keyword(s):  
Oil And Gas ◽  
50Th Anniversary ◽  
Reference Source ◽  
Geological Society ◽  
Oil And Gas Fields ◽  
Production History ◽  
Exploration And Production ◽  
History Of ◽  
The Uk ◽  
Gas Fields

Geological Society Memoir 52 records the extraordinary journey of more than 50 years that has led to the development of some 458 oil and gas fields on the UK Continental Shelf (UKCS). It contains papers on almost 150 onshore and offshore fields in all of the UK's main petroliferous basins. These papers range from look-backs on some of the first-developed gas fields in the Southern North Sea, to papers on fields that have only just been brought into production or may still remain undeveloped, and includes two candidate CO2 sequestration projects.These papers are intended to provide a consistent summary of the exploration, appraisal, development and production history of each field, leading to the current subsurface understanding which is described in greater detail. As such, the Memoir will be an enduring reference source for those exploring for, developing, producing hydrocarbons and sequestering CO2 on the UKCS in the coming decades. It encapsulates the petroleum industry's deep subsurface knowledge accrued over more than 50 years of exploration and production.

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