DETERMINATION OF RESERVOIR DISTRIBUTION OVER THE BLACKBACK/TERAKIHI OIL FIELD, GIPPSLAND BASIN, AUSTRALIA

1993 ◽  
Vol 33 (1) ◽  
pp. 1
Author(s):  
M.D. Gross
Keyword(s):  
Oil And Gas ◽  
Group Structure ◽  
High Amplitude ◽  
Oil Field ◽  
Seismic Survey ◽  
Seismic Attribute ◽  
Oil Accumulation ◽  
Well Control ◽  
High Impedance ◽  
Gippsland Basin

The Blackback/Terakihi oil accumulation is located within the Gippsland Basin permit Vic-P24 on the edge of the present-day continental shelf in water depths ranging from 300 to more than 600 m. Accurate structural mapping, depth conversion and delineation of the reservoir units remain as major uncertainties associated with this oil and gas accumulation. To date three wells, Hapuku-1, Blackback-1 and Terakihi-1 have been drilled on the structure and a 3D seismic survey interpreted.The top of the Latrobe Group structure is a complex erosional remnant somewhat laterally offset from a deep-seated northeast to southwest trending, faulted anticline. Most of the hydrocarbons intersected to date have been encountered within the top of the Latrobe Group closure. All three wells drilled to date have intersected oil at the top of the Latrobe Group in three markedly different reservoir units. These reservoirs range in age from Late Cretaceous to Eocene, with porosity ranging from less than 12 per cent to 26 per cent and permeability from less than 1 md to greater than 3000 md.Given the extreme variation in reservoir quality and the field's location in relatively deep water, delineating the distribution of reservoir units using all available data remains crucial.The generation of seismic attribute maps such as dip, dip azimuth and horizon amplitude slices, calibrated on existing well penetrations has played a major role in delineating a complex reservoir distribution at the top of the Latrobe Group. The calibration of high amplitude seismic events with a high impedance channel infill unit of Eocene age was supported by modelling using SIERRAR modelling software.The integration of existing well control, seismic stratigraphy and fault geometry together with seismic attribute mapping and modelling has resulted in a more tightly constrained estimate of the field reserves.

CarbonNet progress towards a declaration of identified storage formation at the Pelican site with a new high-resolution 3D seismic dataset

2020 ◽  
Vol 60 (2) ◽  
pp. 718
Author(s):  
Nick Hoffman
Keyword(s):  
High Resolution ◽  
Greenhouse Gas ◽  
Oil And Gas ◽  
Co2 Storage ◽  
Gas Storage ◽  
Frequency Resolution ◽  
Seismic Survey ◽  
3D Seismic ◽  
Long Term Storage ◽  
Gippsland Basin

The CarbonNet project is making the first ever application for a ‘declaration of an identified greenhouse gas storage formation’ (similar to a petroleum location) under the Offshore Petroleum and Greenhouse Gas Storage Act. Unlike a petroleum location, however, there is no ‘discovery’ involved in the application. Instead, a detailed technical assessment is required of the geological suitability for successful long-term storage of CO2. The key challenges to achieving a successful application relate to addressing ‘fundamental suitability determinants’ under the act and regulations. At Pelican (Gippsland Basin), a new high-resolution 3D seismic survey and over 10 nearby petroleum wells (and over 1500 basinal wells) supplement a crestal well drilled in 1967 that proved the seal and reservoir stratigraphy. The GCN18A 3D marine seismic survey has the highest spatial and frequency resolution to date in the Gippsland Basin. The survey was acquired in water depths from 15 to 35 m with a conventional eight-streamer seismic vessel, aided by LiDAR bathymetry. The 12.5 m bin size and pre-stack depth migration with multiple tomographic velocity iterations have produced an unprecedented high-quality image of the Latrobe Group reservoirs and sealing units. The 3D seismic data provides excellent structural definition of the Pelican Anticline, and the overlying Golden Beach-1A gas pool is excellent. Depositional detail of reservoir-seal pairs within the Latrobe Group has been resolved, allowing a confident assessment of petroleum gas in place and CO2 storage opportunities. The CarbonNet project is progressing with a low-risk storage concept at intra-formational level, as proven by trapped pools at nearby oil and gas fields. Laterally extensive intra-formational shales provide seals across the entire structure, providing pressure and fluid separation between the overlying shallow hydrocarbon gas pool and the deeper CO2 storage opportunity. CarbonNet is assessing this storage opportunity and progressing towards a ‘declaration of an identified greenhouse gas storage formation’.

THE YELLOWTAIL OIL DISCOVERY

1983 ◽  
Vol 23 (1) ◽  
pp. 170
Author(s):  
A. R. Limbert ◽  
P. N. Glenton ◽  
J. Volaric
Keyword(s):  
Oil Recovery ◽  
Seismic Data ◽  
Joint Venture ◽  
Seismic Survey ◽  
3D Seismic ◽  
Well Control ◽  
Reservoir Volume ◽  
3D Data ◽  
Small Feature ◽  
Gippsland Basin

The Esso/Hematite Yellowtall oil discovery is located about 80 km offshore in the Gippsland Basin. It is a small accumulation situated between the Mackerel and Kingfish oilfields. The oil is contained in Paleocene Latrobe Group sandstones, and sealed by the calcareous shales and siltstones of the Oligocene to Miocene Lakes Entrance Formation. Structural movement and erosion have combined to produce a low relief closure on the unconformity surface at the top of the Latrobe Group.The discovery well, Yellowtail-1, was the culmination of an exploration programme initiated during the early 1970's. The early work involved the recording and interpretation of conventional seismic data and resulted in the drilling of Opah- 1 in 1977. Opah-1 failed to intersect reservoir- quality sediments within the interpreted limits of closure although oil indications were encountered in a non-net interval immediately below the top of the Latrobe Group. In 1980 the South Mackerel 3D seismic survey was recorded. The interpretation of these 3D data in conjunction with the existing well control resulted in the drilling of Yellowtail-1 and subsequently led to the drilling of Yellowtail-2.In spite of the intensive exploration to which this small feature has been subjected, the potential for its development remains uncertain. Technical factors which affect the viability of a Yellowtail development are:The low relief of the closure makes the reservoir volume highly sensitive to depth conversion of the seismic data.The complicated velocity field makes precise depth conversion difficult.The thin oil column reduces oil recovery efficiency.The detailed pattern of erosion at the top of the Latrobe Group may be beyond the resolution capability of 3D seismic data.The 3D seismic data may not be capable of defining the distribution of the non-net intervals within the trap.The large anticlinal closures and topographic highs in the Gippsland Basin have been drilled, and the prospects that remain are generally small or high risk. Such exploration demands higher technology in the exploration stage and more wells to define the discoveries, and has no guarantee of success. The Yellowtail discovery is an illustration of one such prospect that the Esso/Hematite joint venture is evaluating.

Seismic detection of overpressuring and fracturing: An example from the Qaidam Basin, People’s Republic of China

Geophysics ◽  
1993 ◽  
Vol 58 (10) ◽  
pp. 1532-1543 ◽  
Author(s):  
Robert J. Paul
Keyword(s):  
Oil And Gas ◽  
Qaidam Basin ◽  
High Amplitude ◽  
Seismic Survey ◽  
Low Velocity ◽  
Velocity Anomaly ◽  
Deep Well ◽  
Significant Difference ◽  
Seismic Amplitudes ◽  
Definition Of

Shallow hydrocarbon reserves were discovered in 1959 in the Nan Yi Shan structure located near the western corner of the Qaidam Basin. The first successful deep well encountered an overpressured zone at 3000 m that resulted in a well blowout. To improve the structural definition of the field and delineate the overpressured layer a 3-D seismic survey was conducted. A region of anomalous seismic time sag associated with fracturing and small quantities of oil and gas was identified on the northwest plunging nose of the Nan Yi Shan anticline. The distribution of stacking (NMO) velocities in this region was regarded as abnormal; stacking velocities derived on the steeply dipping flanks adjacent to the sag anomaly were found to be slower than those on the shallower crest. Ray‐trace modeling of a buried low‐velocity anomaly provided a possible geometric solution to explain both the time variant nature of the sag and the unusual stacking velocity signature associated with it. A significant difference in seismic and sonic traveltimes was also observed for wells that penetrated the sag region and was attributed to localized fracturing. In a deeper interval, seismic amplitudes were used to identify gas‐saturated fracture porosity and to describe the spatial limits of overpressuring within a thin‐bed reservoir. Wells drilled through high‐amplitude anomalies encountered overpressuring, those drilled in a region of moderate seismic amplitude tested significant quantities of gas, and wells located outside the region of good coherent signal encountered poor or no hydrocarbon shows. These results demonstrate that with good quality seismic data and sufficient lateral and vertical resolution, thin fractured hydrocarbon‐bearing reservoirs can be delineated and overpressure zones identified.

Reservoir Prediction of Zhong 2 Block in Junggar Basin, NW China

2013 ◽  
Vol 868 ◽  
pp. 138-141
Author(s):  
Yong Yuan ◽  
Jin Liang Zhang ◽  
Ning Ning Meng
Keyword(s):  
Oil And Gas ◽  
Junggar Basin ◽  
Research Area ◽  
Seismic Inversion ◽  
Synthetic Seismograms ◽  
Extraction Technology ◽  
Reservoir Prediction ◽  
Seismic Attribute ◽  
Oil Accumulation ◽  
Multiple Attribute

Reservoir plane features of Zhong 2 block in Junggar Basin is analyzed with multiattribute analysis. Through the production of fine synthetic seismograms, the research area is analyzed by seismic attribute. On the basis of the calibration of synthetic seismograms and interpretation of horizon, accurate corresponding relation between the seismic reflection and geological horizon is established. By means of multiple attribute extraction technology, relatively independent attributes related to oil and gas are selected, and afterwards the analysis of the petrophysical characteristics and the optimization of the seismic attribute are achieved. Finally, through the seismic attributes analysis technology and the horizon slice technology, and seismic inversion is conducted, the favorable areas of oil accumulation are predicted.

scholarly journals OIL SPILL PREVENTION AND TREATMENT IN OFFSHORE OIL INDUSTRY OF CHINA

1989 ◽  
Vol 1989 (1) ◽  
pp. 235-238
Author(s):  
Lu Mu-Zhen
Keyword(s):  
Oil Spill ◽  
Joint Venture ◽  
Oil And Gas ◽  
Oil Field ◽  
Oil Fields ◽  
Seismic Survey ◽  
Oil Exploration ◽  
Foreign Companies ◽  
Offshore Oil ◽  
Laws And Regulations

ABSTRACT The China National Offshore Oil Corporation (CNOOC), established in October 1982, is the sole Chinese company dealing with offshore oil exploration, development, and production. It has four regional corporations, and four specialized corporations, as well as seventeen joint venture corporations. CNOOC has four representative offices outside China. Since the Sino-foreign cooperation for offshore oil exploration and development in China started, 360,000 line km of seismic survey have been shot, thirty-nine oil and gas bearing structures have been found, fifteen oil fields have been evaluated as having large hydrocarbon accumulations, nine oil fields have been developed and put into production, 179 exploratory wells have been drilled, and CNOOC has signed thirty-nine contracts with a total of forty-five foreign companies from twelve countries. There are five laws and regulations in the PRC affecting offshore oil development and marine environmental pollution. In accord with these laws and regulations, CNOOC has reviewed four environmental impact statements for offshore oil fields received from its regional corporations. CNOOC has made oil spill contingency plans for the Cheng-Bei offshore oil field in Bo-Hai, and the Wei 10-3 offshore oil field in the Gulf of Bei-Bu. Some oil spill combating equipment is owned by the Bo-Hai Oil Corporation and the Nan-Hai West Oil Corporation, selected on the basis of the crude oil characteristics.

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.

The Cognition Decide the Exploration- The Exploration Study on Buried Hill Reservoir in the Liaohe Basin

2012 ◽  
Vol 616-618 ◽  
pp. 166-169
Author(s):  
Zong Zhan Xue ◽  
Deng Fa He ◽  
Xiao Heng Wang
Keyword(s):  
Source Rock ◽  
Metamorphic Rock ◽  
Oil And Gas ◽  
Technology Development ◽  
Oil Field ◽  
Oil Accumulation ◽  
Cave System ◽  
Liaohe Basin ◽  
Buried Hill ◽  
Liaohe Depression

In recent years the buried hill exploration was a main power for increasing reserve& production in the Liaohe oil field. By the research and analysis on the buried hill reservoir exploration in the Liaohe oil field in the paper, It point out that the previously mistake cognition was broken through in the buried hill reservoir exploration with the seismic, logging etc. technology development. The achievement list as: 1. The conclusion is drawn about the depth of the buried hill reservoir determined by the depth of the source rock which clarified the mistake about the buried hill reservoir formed only in the shallow formation. 2. The inner of the buried hill reservoir of the metamorphic rock is a fissure-cave system formed by the various and layered rocks which served as an oil accumulation place which broke through the cognition on no pore in the deep inner of the buried hill reservoir. 3.The reservoir-formed pattern is built on the study of the controlled factor in the buried hill reservoir which denied the barrier of the basalt layer for oil and gas translation over the buried hill reservoir .In this paper by the summary of the cognition breakthrough and achievement, it shows the next exploration direction in buried hill reservoir in the Liaohe depression.

ROBE RIVER — AN ONSHORE SHALLOW OIL ACCUMULATION

1978 ◽  
Vol 18 (1) ◽  
pp. 3
Author(s):  
B. M. Thomas
Keyword(s):  
Structural Control ◽  
Oil And Gas ◽  
Seismic Survey ◽  
Large Area ◽  
Oil Accumulation ◽  
Late Tertiary ◽  
Present Distribution ◽  
Artesian Aquifer ◽  
Artesian Water ◽  
Made In

Aeromagnetic depth-to-basement estimates made in 1966 led to the concept of the "Robe River Embayment", a structural depression related to a block of Palaeozoic sediments which has been douwnfaulted into the Precambrian in the northeastern corner of the onshore Carnarvon Basin. During a subsequent seismic survey (1966-67), a deep shothole blew out at 77 m. About 20 litres of heavy brown crude oil were recovered, followed by a strong artesian water flow. The search for a shallow oil accumulation followed with a programme of nine coreholes in 1967-68. Shows of oil and gas were encountered in seven of the wells, but producibility was not established. Further drilling in 1969 (one well), 1972 (five wells) and 1974 (two wells) has better defined the area of hydrocarbon occurrence, but no significant tests have resulted despite promising shows in many of the wells.Robe River oil is of low gravity (14.5 to 20° API), highly aromatic, and biodegraded. It is found at depths ranging from 65 to 165 m mainly within the low-permeability Mardie Greensand. The greensand is underlain by the highly permeable Yarraloola Conglomerate which is an artesian aquifer and has probably acted as the main conduit for oil migration out of the Barrow Sub-basin. There is no evidence of major structural control on the Robe River oil shows which occur sporadically over a large area. Whilst permeability barriers within the Mardie Greensand probably influence the present distribution of hydrocarbons, there is also evidence that the hydraulics of the Yarraloola Conglomerate have been important in the localization of this accumulation. Water salinity studies suggest that the influx of meteoric water from the Yarraloola Conglomerate outcrop has resulted in a hydrodynamic trap for oil as it migrated updip from the Barrow Sub-basin. During the late Tertiary a much larger accumulation may have existed within the Yarraloola Conglomerate and the Mardie Greensand. The northwesterly flow of water has now ceased and the oil has dispersed, except where it is trapped within the relatively impermeable Mardie Greensand.

Seismic reservoir characterization of Bentheimer sandstone, Emlichheim oil field, Lower Saxony, Germany

2020 ◽  
Vol 8 (4) ◽  
pp. SQ47-SQ71 ◽  
Author(s):  
Uwe Strecker ◽  
Steffen Hagedorn ◽  
Matthias Zeug ◽  
Paul Veeken ◽  
Wulf Weist ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Reservoir Characterization ◽  
Noise Suppression ◽  
Oil Field ◽  
Inversion Method ◽  
Lower Saxony ◽  
Seismic Attribute ◽  
Velocity Anisotropy ◽  
Northwest Germany ◽  
Seismic Reservoir

Even in mature oil and gas provinces, unexpected subsurface complexity may challenge budgeted seismic reservoir characterization workflows to become adapted to a higher degree of customization during data preconditioning. In the process of providing a trend cube of sandstone porosity and automatic fault extraction to populate the property distribution and structural framework of a static model over the mature Emlichheim oil field, northwest Germany, many unforeseen data quality issues are encountered that necessitate rigorous well log and seismic data conditioning prior to analysis and interpretation. Specifically, insufficient noise suppression, ambiguous wireline log responses, missing curve log data, noncompliant amplitude-versus-angle gathers, and inadequate compensation of velocity anisotropy need to be addressed. These topics pose serious challenges to automatic fault extraction, seismic attribute analysis, machine learning, artificial neural network technology, the selected inversion method, Bayesian lithology prediction, and fuzzy math to transform elastic impedances into reservoir porosity. Application of multiple inversion methods generates the individual components of new earth models (sand geobodies, alternative elasticity-to-porosity transforms, etc.) that are used for advanced porosity modeling. This new information allows to update the existing static models of a mature oil field.

scholarly journals Drill Bit Deformations in Rotary Drilling Systems under Large-Amplitude Stick-Slip Vibrations

2020 ◽  
Vol 10 (18) ◽  
pp. 6523 ◽  
Author(s):  
Idir Kessai ◽  
Samir Benammar ◽  
Mohamed Zinelabidine Doghmane ◽  
Kong Fah Tee
Keyword(s):  
Industrial Development ◽  
Oil And Gas ◽  
Oil And Gas Industry ◽  
High Amplitude ◽  
Oil Field ◽  
Drill Bit ◽  
Rotary Drilling ◽  
Stick Slip ◽  
Highly Nonlinear ◽  
Rock Bit

In oil and gas industry, rotary drilling systems are used for energy exploration and productions. These types of systems are composed of two main parts: mechanical and electrical parts. The electrical part is represented by rotating motor called top drive; however, the mechanical part of the system is composed of tool string with many pipes, at the bottom end of these pipes the bit is attached to cut the rock during their contact. Since the bit is in a direct contact with rock characteristic variations, it can be under risk for heavy damage. The latter is principally caused by the fact that the rock–bit interaction term is highly nonlinear and unpredictable. In literature, many mathematical models have been proposed for rock–bit interaction, but they do not reflect the dynamic of the bit under vibrations since torsional and axial vibrations are strongly coupled and synchronized with it. In industrial development, the design of drill bit has faced many improvements in order to overcome these vibrations and mitigate unpredictable phenomena. Even though, the practical use of these drill bits confirmed that there are still many failures and damages for the new designs; moreover, bits’ virtual life become shorter than before. The objective of this study is to analyze the drill bit deformations caused by the stick-slip vibration phenomenon which is characterized by high-frequency high-amplitude in rotary drilling systems. The obtained results were validated through a case study of MWD (measurement while drilling) data of well located in a Southern Algerian oil field.

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