THE JANSZ GAS FIELD, CARNARVON BASIN, AUSTRALIA

2003 ◽  
Vol 43 (1) ◽  
pp. 303 ◽  
Author(s):  
C.C. Jenkins ◽  
D.M. Maughan ◽  
J.H. Acton ◽  
A. Duckett ◽  
B.E. Korn ◽  
...  
Keyword(s):  
Column Height ◽  
Gas Reservoirs ◽  
Gas Reservoir ◽  
Gas Field ◽  
Amplitude Versus Offset ◽  
Gas Markets ◽  
Sandstone Reservoir ◽  
Western Limb ◽  
Amplitude Versus ◽  
Carnarvon Basin

The Jansz gas field is located in permit WA-268-P, 70 km northwest of the Gorgon gas field in the Carnarvon Basin. The Jansz–1 discovery well was drilled in April 2000 and intersected 29 m of net gas pay in an Oxfordian age shallow marine sandstone reservoir. The well drilled a stratigraphic trap on the western limb of the Kangaroo Syncline.The Io–1 well was drilled in January 2001 in the adjacent permit WA-267-P (18 km from Jansz–1) and intersected the same Oxfordian sandstone reservoir penetrated by Jansz–1, with a total of 44 m of net gas pay. The Tithonian and the Upper Triassic Brigadier Sandstone gas reservoirs at Geryon–1 (1999) and Callirhoe–1 (2001) in WA-267-P are in pressure communication with the Oxfordian gas reservoir at Jansz–1 and Io–1. Consequently, the three different age reservoirs comprise a single gas pool, with a common gas/water contact.The Jansz gas field has been delineated by four wells and 2D seismic. The gas sandstones have a prominent amplitude versus offset response, which defines the field limits. The Jansz gas field is confirmed by drilling to be an areally extensive (2,000 km2) gas accumulation with a gross column height of 400 m and an estimated 20 TCF (566 G.m3) recoverable sales gas, which represents 40% of the discovered gas resources in the deepwater Carnarvon Basin. The size of the Jansz gas field and its remoteness from existing pipeline gas markets suggests that an export LNG project will be the basis for its 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.

THE ROLE OF AMPLITUDE VERSUS OFFSET TECHNOLOGY IN PROMOTING OFFSHORE PETROLEUM EXPLORATION IN AUSTRALIA

2007 ◽  
Vol 47 (1) ◽  
pp. 163 ◽  
Author(s):  
P. E. Williamson ◽  
F. Kroh
Keyword(s):  
Petroleum Exploration ◽  
Gas Field ◽  
North West ◽  
Preliminary Results ◽  
Exmouth Plateau ◽  
The North ◽  
Amplitude Versus Offset ◽  
Cable Lines ◽  
The Cost ◽  
Amplitude Versus

Amplitude versus offset (AVO) technology has proved itself useful in petroleum exploration in various parts of the world, particularly for gas exploration. To determine if modern AVO compliant processing could identify potential anomalies for exploration of open acreage offshore Australia, Geoscience Australia reprocessed parts of four publicly available long cable lines. These lines cover two 2006 acreage release areas on the Exmouth Plateau and in the Browse Basin on the North West Shelf. An earlier study has also been done on two publicly available long cable lines from Geoscience Australia’s Bremer Basin study and cover areas from the 2005 frontier acreage release on the southern margin. The preliminary results from these three reprocessing efforts produced AVO anomalies and were made publicly available to assist companies interested in assessing the acreage. The results of the studies and associated data are available from Geoscience Australia at the cost of transfer.The AVO data from the Exmouth Plateau show AVO anomalies including one that appears to be at the Jurassic level of the reservoir in the Jansz/Io supergiant gas field in adjacent acreage to the north. The AVO data from the Caswell Sub-basin of the Browse Basin show an AVO anomaly at or near the stratigraphic zone of the Brecknock South–1 gas discovery to the north. The geological settings of strata possibly relating to two AVO anomalies in the undrilled Bremer Basin are in the Early Cretaceous section, where lacustrine sandstones are known to occur. The AVO anomalies from the three studies are kilometres in length along the seismic lines.These preliminary results from Geoscience Australiaand other AVO work that has been carried out by industry show promise that AVO compliant processing has value—particularly for gas exploration offshore Australia—and that publicly available long-cable data can be suitable for AVO analysis.

Porosity identification using amplitude variations with offset: Examples from South Sumatra

Geophysics ◽  
1989 ◽  
Vol 54 (8) ◽  
pp. 942-951 ◽  
Author(s):  
S. Chacko
Keyword(s):  
Oil And Gas ◽  
Angle Of Incidence ◽  
The South ◽  
Gas Reservoir ◽  
Amplitude Versus Offset ◽  
Variation Patterns ◽  
Reefal Facies ◽  
Highly Porous ◽  
Amplitude Versus ◽  
Good Agreement

Widespread deposition of platform and reefal carbonates of the Baturaja limestone formation occurred during the Miocene epoch in the South Sumatra basin. Although significant oil and gas deposits have been discovered in the porous facies, porosity within the Baturaja limestone has been observed to vary widely between tight platform facies and highly porous reefal facies, making predrill prediction of porosity an important exploration objective. I use amplitude‐versus‐offset seismic modeling to distinguish between porous and tight Baturaja limestone facies. Amplitude variations with offset for reflections from two Baturaja reefs in the South Sumatra basin were studied: one, a proven gas reservoir, the other, an interpreted reef that had not yet been drilled at the time of study. The seismic data were processed judiciously to preserve and enhance amplitude effects, which were then modeled using the Bortfeld approximation for reflection coefficients. A key assumption was that the [Formula: see text] ratio of limestone depends primarily on minerology rather than on porosity or pore‐fluid content. The modeling showed that porous and tight limestone facies have unique and different reflection-coefficient variation patterns with angle of incidence. Good agreement was found between observed data and the modeling results, indicating that the modeling of amplitude variations with offset can be used as a lithology discriminant. In the second case, a predrill prediction of porosity was confirmed by subsequent drilling.

scholarly journals Comparative Study on the Reservoir Characteristics and Development Technologies of Two Typical Karst Weathering-Crust Carbonate Gas Reservoirs in China

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-19
Author(s):  
Haijun Yan ◽  
Ailin Jia ◽  
Fankun Meng ◽  
Qinyu Xia ◽  
Wei Xu ◽  
...  
Keyword(s):  
Carbonate Reservoirs ◽  
Production Performance ◽  
Dynamic Monitoring ◽  
Weathering Crust ◽  
Gas Reservoirs ◽  
Gas Reservoir ◽  
Gas Field ◽  
Reservoir Characteristics ◽  
Reservoir Stimulation ◽  
Well Pattern

Carbonate reservoirs are the main reservoir types in China, which occupy the large ratio of reserves and production at present. The high-efficiency development of carbonate reservoirs is of great significance to assure the stability of national energy supply. The Lower Paleozoic reservoir in Jingbian gas field and the Sinian reservoir in Anyue gas field are two typical carbonate gas reservoirs, and their successful development experiences can provide significant references for other similar carbonate gas reservoirs. For Jingbian gas field, it is a lithological-stratigraphic reservoir developed in a westward monocline and multiple rows of nose-fold structures, and is a stable craton basin with simple palaeognomy distribution and stable connectivity, which has complex gas-water distribution. However, for Anyue gas field, it is a lithological-structural reservoir with multiple tectonic high points and multiple fault systems, and is biological dune beach facies under extensional setting with highly differentiated inside of the block in palaeognomy characteristics, which has limited connectivity and tectonic side water is in a local area. The difference of gas reservoir characteristics leads to the diverse development strategies. For these two gas reservoirs, although there are some similar aspects, such as the screen of enrichment areas, the application of irregular well pattern and reservoir stimulation techniques, the criteria of enrichment areas, the well types, and the means of reservoir stimulation are absolutely different. In addition, due to the differences of control reserves and production capacity for these two kinds of reservoirs, the mode of stable production is also different. The effective development of Jingbian gas field can give some references to the future exploitation on the Sinian gas reservoir. Firstly, the sedimentary characteristics should be studied comprehensively. Secondly, the distribution pattern and distribution characteristics of the palaeognomy should be found and determined. Thirdly, the distribution of fracture system in the reservoir should be depicted finely. Finally, dynamic monitoring on the production performance should be strengthened, and the management for this gas field should be improved further. The findings of this study can help for better understanding of the Karst weathering-crust carbonate gas reservoir formation characteristics and the optimal development technologies that should be taken in practice.

The inverse correlations between methane content and elastic parameters of coal-bed methane reservoirs

Geophysics ◽  
2013 ◽  
Vol 78 (4) ◽  
pp. D237-D248 ◽  
Author(s):  
Xin-Ping Chen ◽  
Quanming Huo ◽  
Jiandong Lin ◽  
Yang Wang ◽  
Fenjin Sun ◽  
...  
Keyword(s):  
Methane Content ◽  
Coal Bed ◽  
Coal Bed Methane ◽  
Biot Theory ◽  
Elastic Parameters ◽  
Gas Reservoirs ◽  
Coal Beds ◽  
Amplitude Versus Offset ◽  
Environmental Variations ◽  
Amplitude Versus

We investigated three coal-bed methane (CBM) reservoirs in which there exist, when we are careful about data quality and reduce environmental variations, inverse correlations between methane content and the elastic properties of the coal beds. Such inverse correlations may exist in general in high- and medium-rank CBM reservoirs. There is evidence that supports the generalization of such inverse correlations and factors that distort them. These distorting factors may prevent identification of such inverse correlations in certain CBM prospects; however, they cannot negate the underlying inverse correlations. Such inverse correlations may play a role in CBM amplitude versus offset (AVO) similar to the role played by Gassmann-Biot theory ( Gassmann, 1951 ; Biot, 1956 , 1962 ) in AVO technology for conventional gas reservoirs. This may lay the first brick for a theoretical basis of CBM AVO.

scholarly journals The Researches on Reasonable Well Spacing of Gas Wells in Deep and low Permeability Gas Reservoirs

2018 ◽  
Vol 38 ◽  
pp. 01038
Author(s):  
Yu Bei Bei ◽  
Li Hui ◽  
Li Dong Lin
Keyword(s):  
Pressure Gradient ◽  
Low Permeability ◽  
Well Testing ◽  
Gas Wells ◽  
Gas Reservoirs ◽  
Gas Reservoir ◽  
Gas Field ◽  
Well Spacing ◽  
Start Up ◽  
Starting Pressure Gradient

This Gs64 gas reservoir is a condensate gas reservoir which is relatively integrated with low porosity and low permeability found in Dagang Oilfield in recent years. The condensate content is as high as 610g/m3. At present, there are few reports about the well spacing of similar gas reservoirs at home and abroad. Therefore, determining the reasonable well spacing of the gas reservoir is important for ensuring the optimal development effect and economic benefit of the gas field development. This paper discusses the reasonable well spacing of the deep and low permeability gas reservoir from the aspects of percolation mechanics, gas reservoir engineering and numerical simulation. considering there exist the start-up pressure gradient in percolation process of low permeability gas reservoir, this paper combined with productivity equation under starting pressure gradient, established the formula of gas well spacing with the formation pressure and start-up pressure gradient. The calculation formula of starting pressure gradient and well spacing of gas wells. Adopting various methods to calculate values of gas reservoir spacing are close to well testing' radius, so the calculation method is reliable, which is very important for the determination of reasonable well spacing in low permeability gas reservoirs.

A New Method to Predict Favorable Gas-Rich Area in Tight Sandstone Gas Reservoir in Daniudi Area

2013 ◽  
Vol 295-298 ◽  
pp. 3328-3332
Author(s):  
Hai Ying Han ◽  
Zhi Zhang Wang ◽  
Xin Xiao Sun ◽  
Wei Jun Wang
Keyword(s):  
Ordos Basin ◽  
Gas Reservoirs ◽  
Tight Sandstone ◽  
Gas Reservoir ◽  
Gas Field ◽  
High Productivity ◽  
Integrated Method ◽  
Geological Information ◽  
Sedimentary Microfacies ◽  
Developing Area

Daniudi gas field is a tight sandstone gas field in the northeast of Ordos Basin. How to use the successful experience in developing area to predict favorable gas-rich area in other areas in this gas field is very important to the next exploration and development in this field. This paper proposes a multi-information integrated method to predict favorable gas-rich area. Firstly describe sedimentary microfacies by integrating seismic, logging and geological information; and then summarize and analyze the seismic reflection patterns of medium-high productivity wells; finally determine the favorable gas-rich area with the distribution of storage coefficient based on the previous analysis. The welltest of newly drilled wells shows that the coincidence rate of favorable gas-rich area predicted by this method could be up to 90%,and this method could be extended to use in the other tight sandstone gas reservoirs.

The Characteristics of Tight Gas Reservoirs Microscopic Pore Structure - To Sulige Gas Field as an Example

2015 ◽  
Vol 1092-1093 ◽  
pp. 1485-1489 ◽  
Author(s):  
Jun Sheng ◽  
Wei Sun ◽  
Ji Lei Qin ◽  
Shi Guo Liu ◽  
Ai Ju Li ◽  
...  
Keyword(s):  
Pore Structure ◽  
Physical Characteristics ◽  
Tight Gas ◽  
Gas Reservoirs ◽  
Tight Sandstone ◽  
Gas Field ◽  
Tight Gas Reservoirs ◽  
Constant Rate ◽  
Sandstone Reservoir ◽  
The Impact

The research is based on conventional microscope experiments, the characteristics of microscopic pore structure of tight sandstone reservoir were analyzed via the constant-rate mercury experiment. This paper selected samples of tight sandstone are from the Southeast area of Erdos basin Sulige gas field. The results showed that the dissolution pore and the intergranular pore were mainly reservoir pore structure types; the bundle throat and the lamellar throat were mainly types of throat in the study area. The mainly configure relations of the pore and throat in this area were big pore - fine / fine throat. Finally, according to constant-rate mercury results, analyzed the impact of pore and throats for percolation capacity respectively, came to the conclusions that the tight sandstone gas reservoirs percolation capability in study area is mainly affected by the throat, and the development degree of the throat determines the final physical characteristics of the reservoir.

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