THE DEVELOPMENT OF THE TIRRAWARRA OIL AND GAS FIELD

1984 ◽  
Vol 24 (1) ◽  
pp. 278
Author(s):  
H. T. Pecanek ◽  
I. M. Paton
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Gas Injection ◽  
Oil Field ◽  
Oil Reservoir ◽  
Gas Reservoirs ◽  
Gas Field ◽  
Associated Gas ◽  
Oil And Gas Field ◽  
Cooper Basin

The Tirrawarra Oil and Gas Field, discovered in 1970 in the South Australian portion of the Cooper Basin, is the largest onshore Permian oil field in Australia. Development began in 1981 as part of the $1400 million Cooper Basin Liquids ProjectThe field is contained within a broad anticline bisected by a north-south sealing normal fault. This fault divides the Tirrawarra oil reservoir into the Western and Main oil fields. Thirty-four wells have been drilled, intersecting ten Patchawarra Formation sandstone gas reservoirs and the Tirrawarra Sandstone oil reservoir. Development drilling discovered three further sandstone gas reservoirs in the Toolachee Formation.The development plan was based on a seven-spot pattern to allow for enhanced oil recovery by miscible gas drive. The target rates were 5400 barrels of oil (860 kilolitres) per day with 13 million ft3 (0.37 million m3) per day of associated gas and 70 million ft3 (2 million m') per day of wet, non-associated gas. Evaluation of early production tests showed rapid decline. The 100 ft (30 m) thick, low-permeability Tirrawarra oil reservoir was interpreted as an ideal reservoir for fracture treatment and as a result all oil wells have been successfully stimulated, with significant improvement in well production rates.The oil is highly volatile but miscibility with carbon dioxide has been proven possible by laboratory tests, even though the reservoir temperature is 285°F (140°C). Pilot gas injection will assess the feasibility of a larger-scale field-wide pressure maintenance scheme using miscible gas. Riot gas injection wells will use Tirrawarra Field Patchawarra Formation separator gas to defer higher infrastructure costs associated with the alternative option of piping carbon dioxide from Moomba, the nearest source.

scholarly journals EOR and Reservoir preservation in Rag-e Sefied Oil and Gas Field: With Base of Reservoir Fluid Geochemistry

2021 ◽  
Author(s):  
Seyed Hossein Hashemi ◽  
Abas Niknam ◽  
Amir Karimian Torghabeh
Keyword(s):  
Oil And Gas ◽  
Inorganic Ions ◽  
Operating Conditions ◽  
Oil Field ◽  
Reservoir Rock ◽  
Formation Water ◽  
Gas Reservoirs ◽  
Accurate Analysis ◽  
Gas Field ◽  
Oil And Gas Field

Abstract Mineral ions are present in aqueous solutions in most industrial and operational processes, including oil operation. Accurate analysis and sampling of the formation water and its dissolved minerals during the operation of the oil industry can be a valuable solution for the efficient management of oil production from the reservoir. Therefore, in this study, evaluation of inorganic ions and their concentration in formation water for 6 well samples in the Rag-e Sefid Oil and Gas Field was considered. According to the results of this study, calcium, sodium and magnesium cations as well as sulfate, bicarbonate and chloride anions are soluble inorganic ions in the Rag Sefid Oil Field Formation. Also, in this study formation of inorganic sediment CaSO4, CaSO4.2H2O, CaCO3 and MgCO3 was studied. Based on the operating conditions of the Rag-e Sefid Oil and Gas field, the formation of calcium sulfate and calcium carbonate mineral deposits is significant. With base of geochemical analysis in reservoir rock samples and ions ratios these reservoir is good for preservation. The results thus provide more accurate predictions in terms of where to find gas reservoirs in the Zagros basin, and can lead to significantly better exploitation of these resources and also estimation of rate of sedimentation for EOR.

The Current Situation and Prospects of Development of Low Permeability Oil Reservoir

2013 ◽  
Vol 734-737 ◽  
pp. 1286-1289 ◽  
Author(s):  
Lin Cong ◽  
Wen Long Li ◽  
Jing Chao Lei ◽  
Ru Bin Li
Keyword(s):  
Research Methods ◽  
Oil And Gas ◽  
Low Permeability ◽  
Oil Reservoir ◽  
Oil Exploration ◽  
Gas Field ◽  
Oil And Gas Field ◽  
Low Permeability Reservoirs ◽  
Technical Measures ◽  
Exploration And Development

Internationally the research of low permeability oil reservoir is a difficult point in the exploration and development of oil and gas field. This thesis, based on the research methods of low permeability reservoirs at home and abroad, summaries several major problems encountered in the process of low permeability oil exploration and development under the current technical conditions as well as the corresponding, but more effective technical measures that need to be constantly improved. And that exploration and development of low permeability of the reservoir will be the main battle field for some time in the future of oil exploration and development.

scholarly journals Development of a prmA genes quantification technique and assessment of the technique’s application potential for oil and gas reservoir exploration

2018 ◽  
Vol 36 (5) ◽  
pp. 1172-1188 ◽  
Author(s):  
Zhuo Ning ◽  
Ze He ◽  
Sheng Zhang ◽  
Miying Yin ◽  
Yaci Liu ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Quantitative Polymerase Chain Reaction ◽  
Oil Field ◽  
Gas Reservoirs ◽  
Gas Reservoir ◽  
Gas Field ◽  
Detection Range ◽  
Gene Copies ◽  
Application Potential ◽  
Sensitivity Specificity

Propane-oxidizing bacteria in surface soils are often used to indicate the position of oil and gas reservoirs. As a potential replacement for the laborious traditional culture-dependent counting method, we applied real-time fluorescent quantitative polymerase chain reaction detection as a quick and accurate technology for quantification of propane-oxidizing bacteria. The propane monooxygenase gene was set as the target and the assay is based on SYBR Green I dye. The detection range was from 9.75 × 108 to 9.75 × 101 gene copies/µl, with the lowest detected concentration of 9.75 copies/µl. All coefficient of variation values of the threshold cycle in the reproducibility test were better than 1%. The technique showed good sensitivity, specificity, and reproducibility. We also quantified the propane-oxidizing bacteria in soils from three vertical 250 cm profiles collected from an oil field, a gas field, and a nonoil gas field using the established technique. The results indicated that the presence of propane monooxygenase A genes in soils can indicate an oil or gas reservoir. Therefore, this technique can satisfy the requirements for microbial exploration of oil and gas.

Long Pile Upending Lifting Study for Fixed Platform on Offshore Oil and Gas Field

2014 ◽  
Author(s):  
Yandong Zhou ◽  
Facheng Wang
Keyword(s):  
Deep Water ◽  
Oil And Gas ◽  
Cost Effective ◽  
Analysis Model ◽  
Gas Reservoirs ◽  
Gas Field ◽  
Water Developments ◽  
Oil And Gas Field ◽  
Offshore Oil And Gas ◽  
Offshore Oil

Fixed platform have been widely employed in the offshore oil and gas reservoirs development. Pile foundation reliability is critical for these platforms where drilling, production and other functions are integrated. The lifting operation for the long pile, being a key step in the jacket installation, has been considered for further developments. With deep water developments, the sizes and weights of long piles are reasonably bigger. The corresponding process and equipment employed are subsequently altered, which brings challenges to developing a cost-effective, easy-operable approach for lifting operation. In this paper, the technology for the offshore long pile upending lifting operation including pile feature, installation methodology, lifting rigging and analysis model, covering water depths ranging from shallow to near deep water zone (60–300 m water depth) has been suggested. In addition, the applicability of the adoptable novel approaches has been discussed considering the practical project experience.

THE KALLADEINA FORMATION – A WARBURTON BASIN CAMBRIAN CARBONATE PLAY

1990 ◽  
Vol 30 (1) ◽  
pp. 166 ◽  
Author(s):  
D.C. Roberts ◽  
P.G. Carroll ◽  
J. Sayers
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Source Rocks ◽  
Gas Oil ◽  
Gas Field ◽  
Oil And Gas Field ◽  
Shelf Sediments ◽  
Wrench Fault ◽  
Very High ◽  
Cooper Basin

The Warburton Basin is currently considered economic basement to the gas-oil productive Cooper Basin and the oil productive Eromanga Basin. Only 10 wells have penetrated more than 100 m of the Kalladeina Formation which is identified as the most prospective section within the Warburton Basin. The Kalladeina Formation consists of more than 1600 m of carbonate shelf sediments deposited during the early Cambrian to early Ordovician in a basin consisting of half grabens on the continental side of an active margin.Several intra-Kalladeina Formation seismic events in a 500 km2 region to the west of the Gidgealpa oil and gas field have been tied to wells with palaeontological control. Structure and isopach mapping illustrates large scale thrusts, wrench fault zones and subcrop edges for the Kalladeina Formation. Maps of unconformities and of formations above the Warburton Basin define source, seal and trap relationships.Good carbonate reservoirs have been identified in the Kalladeina Formation but the source potential of this succession appears to be restricted. The overlying Cooper Basin source rocks may have charged the underlying carbonates and this represents one of three play types identified in the area.All Warburton Basin plays are very high risk but potential reserves are also large.

LANDSCAPE MAP OF BYTKIVSKE OIL FIELD AND NEIGHBORING TERRITORIES OF THE CARPATHIAN REGION

2017 ◽  
Vol 31 (2) ◽  
pp. 49-55
Author(s):  
Yaroslav Adamenko ◽  
◽  
Mirela Coman ◽  
Oleh Adamenko ◽  
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Oil Field ◽  
Nature Protection ◽  
Gas Field ◽  
Oil And Gas Production ◽  
Main Research ◽  
Oil And Gas Field ◽  
Age Features ◽  
Landscape Map

Environmentally safe oil and gas production demands permanent control for the development of ecological situation which should be managed on the basis of existing nature protection requirements and corresponding instruction documents. Purpose of the research and formulation of the problem is to select landscape complexes at the hierarchical levels of locations and facies in the Bykiv oil and gas field to make landscape map with morphological genetic and age features of landscape structure as the basis of environmental assessment of oil and gas field impact on the natural geosystems. Presentation of the main research material with full justification of the received scientific results. Landscape analysis of the investigated area allowed to select, ground and make mapping the following landscape complexes: landscape localities, foothill landscape complexes. Characteristic feature of the Bytkiv oil and gas field and neighborhoods is their high-altitude stratification from middle and lowmountainous to foothills and lowlands. The genesis or origin of the area under study is various - from denudation relics of the top peneplenization surface of leveling much younger pedyplenization surface pediments on the transition from mountainous to foothill relief, to deeply portioned erosionally active steep slopes and stairstepping of the river terraces. Age boundaries of the created landscape structures were determined on the availability of adjoint sedimentary formations from the producents of bedrock destruction, resedimented eolivan, deluvial, proluvial and alluvial processes.

Lost Hills Solar Project: Powering an Oil and Gas Field with California Sunshine

2021 ◽  
pp. 1-9
Author(s):  
T. N. Demayo ◽  
N. K. Herbert ◽  
D. M. Hernandez ◽  
J. J. Hendricks ◽  
B. Velasquez ◽  
...  
Keyword(s):  
Renewable Energy ◽  
Energy Storage ◽  
Oil And Gas ◽  
Oil Field ◽  
Carbon Intensity ◽  
Solar Pv ◽  
Gas Field ◽  
Solar Plant ◽  
Oil And Gas Field ◽  
Solar Electricity

Summary This paper outlines one of the first efforts by a major oil and gas company to build a net-exporting, behind-the-meter solar photovoltaic (PV) plant to lower the operating costs and carbon intensity of a large, mature oil and gas field. The 29 MWAC (35 MWDC) Lost Hills solar plant in Lost Hills, California, USA, commissioned in April 2020, covers approximately 220 acres on land adjacent to the oil field and is designed to provide more than 1.4 TWh of solar energy over 20 years to the field’s oil and gas production and processing facilities. The upgrades to the electrical infrastructure in the field also include new technology to reduce the risk of sulfur hexafluoride emissions, another potent greenhouse gas (GHG). Before the solar project, the Lost Hills field was importing all its electricity from the grid. With the introduction of the Innovative Crude Program as part of California’s Low Carbon Fuel Standard (LCFS) and revisions to the California Public Utilities Commission Net Energy Metering program, Lost Hills was presented with a unique opportunity to reduce its imported electricity expenses and reduce its carbon intensity, while also generating LCFS credits. The solar plant was designed to power the field during the day and export excess power to the grid to help offset nighttime electricity purchases. It operates under a power purchase agreement (PPA) with the solar PV provider and, initially, will meet approximately 80% of the oil field’s energy needs. Future plans include incorporating 20 MWh of lithium-ion batteries, direct current (DC)–coupled with the solar inverters. This energy storage system will increase the amount of solar electricity fed directly into the field and reduce costs by controlling when the site uses stored solar electricity rather than electricity from the grid. The battery system will also increase the number of LCFS credits by 15% over credits generated by solar alone. Together, solar power and energy storage provide a robust renewable energy solution. This project will generate multiple cobenefits for the Lost Hills oil field by lowering the cost of power, reducing GHG emissions, generating state LCFS credits and federal Renewable Energy Certificates, and demonstrating a commitment to energy transition by investing in renewable technology. Conceivably, the Lost Hills solar project can be a model for similar future projects in other oil fields, not only in California, but across the globe.

OFFSHORE GIPPSLAND BASIN FIELDS

1971 ◽  
Vol 11 (1) ◽  
pp. 85 ◽  
Author(s):  
B. R. Griffith ◽  
E. A. Hodgson
Keyword(s):  
Lower Cretaceous ◽  
Oil And Gas ◽  
Oil Field ◽  
Gas Field ◽  
Field Development ◽  
Oil And Gas Field ◽  
Cumulative Production ◽  
Gippsland Basin ◽  
Offshore Field ◽  
Unconformity Surface

The offshore Gippsland Basin, underlies the continental shelf and slope between eastern Victoria and Tasmania.The basin is filled with up to 25,000' of sediment, varying in age from Lower Cretaceous to Recent. The Lower Cretaceous section is represented by at least 10,000' of nonmarine greywackes of the Strzelecki Group. The overlying sediments of Upper Cretaceous to Eocene age comprise the interbedded sandstones, siltstones, shales and coals of the Latrobe Group, with a cumulative thickness of about 15,000'. Offshore, the Latrobe Group is overlain unconformably by up to 1500' of calcareous mudstones of the Lakes Entrance Formation and up to 5000' of Gippsland Limestone carbonates. Pliocene to Recent carbonates, reaching a maximum thickness of about 1000', complete the sedimentary section of the basin.Australia's first commercial offshore field, the Barracouta oil and gas field, was discovered in the Gippsland Basin in February 1965. Further exploratory drilling over the following two and a half years led to the discovery of the Marlin gas field and the Kingfish and Halibut oil fields.The principal hydrocarbon accumulations are reservoired by sediments of the Latrobe Group within closed structural highs on the Latrobe unconformity surface. Seal is provided by the mudstones and marls of the Lakes Entrance Formation and Gippsland Limestone.A field development programme was initiated immediately after Barracouta had been confirmed as a commercial gas reservoir. By the end of 1967, the Barracouta 'A' platform had been erected. Construction and positioning of the Marlin, Halibut and the two Kingfish platforms followed.To date development drilling has been completed on the Barracouta and Halibut fields, while development of the Marlin field has been temporarily suspended following completion of four wells. Development of the Kingfish oil field which commenced in March 1970, is still in a relatively early stage.The Barracouta field has been producing gas and oil since March and October, 1969 respectively. The Marlin gas field was put on stream in November, 1969 and the Halibut oil field in March 1970. As yet no wells drilled in the Kingfish oil field have been completed for production.The four fields provide a major source of hydrocarbons for the Australian market. By the end of September, 1970 cumulative production of sales quality gas from the Barracouta and Marlin fields was almost 23 BCF. Cumulative production of stabilised oil from Barracouta was 2 million barrels and over 26 million barrels from Halibut.

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