Technology, investment and people: a process for extending the life of the Central Fields Complex, Gippsland Basin

The greater Central Fields complex of the Gippsland Basin, comprised of the Halibut, Fortescue and Mackerel fields, has produced 1.7 billion barrels of oil from four platforms in 37 years of production. After the initial development drilling phases from Halibut (1969–70), Mackerel (1977–80), Fortescue (1983–86) and Cobia (1983–85) platforms and five in-fill drilling campaigns (1992–2003) it is still possible to target unswept highly productive multi-darcy reservoirs along with bypassed zones in lower quality sands. During 2007, a six well program was completed from the Halibut platform using an upgraded workover rig that added significant volumes with combined initial rates of more than 16,000 barrels of oil per day. In addition, despite being conductor limited, the program tested strategic concepts and demonstrated significant remaining potential in a variety of reservoir qualities and depositional environments. The outstanding success of the 2007 program was based on an up-to-date geologic framework, key technical advances, ongoing investment commitment and multi-discipline integration across workplace functions. Advancements in 3D seismic data quality and analyses, reservoir surveillance, innovative slot recovery and data integration all played a role in the success of the program. Building on the success elements of the 2007 program, a higher capacity rig has been mobilised and upgraded to apply new drilling technologies to access the remaining potential and help mitigate basin decline.

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Preconditioning point-source/point-receiver high-density 3D seismic data for lacustrine shale characterization in a loess mountain area

Interpretation ◽

10.1190/int-2016-0107.1 ◽

2017 ◽

Vol 5 (2) ◽

pp. SF177-SF188 ◽

Cited By ~ 3

Author(s):

Wei Wang ◽

Xiangzeng Wang ◽

Hongliu Zeng ◽

Quansheng Liang

Keyword(s):

Data Quality ◽

Seismic Data ◽

Ordos Basin ◽

Seismic Inversion ◽

High Density ◽

Seismic Survey ◽

3D Seismic ◽

Noise Characteristics ◽

Lacustrine Shale ◽

3D Seismic Data

In the study area, southeast of Ordos Basin in China, thick lacustrine shale/mudstone strata have been developed in the Triassic Yanchang Formation. Aiming to study these source/reservoir rocks, a 3D full-azimuth, high-density seismic survey was acquired. However, the surface in this region is covered by a thick loess layer, leading to seismic challenges such as complicated interferences and serious absorption of high frequencies. Despite a specially targeted seismic processing workflow, the prestack Kirchhoff time-migrated seismic data were still contaminated by severe noise, hindering seismic inversion and geologic interpretation. By taking account of the particular data quality and noise characteristics, we have developed a cascade workflow including three major methods to condition the poststack 3D seismic data. First, we removed the sticky coherent noise by a local pseudo [Formula: see text]-[Formula: see text]-[Formula: see text] Cadzow filtering. Then, we diminished the random noise by a structure-oriented filtering. Finally, we extended the frequency bandwidth with a spectral-balancing method based on the continuous wavelet transform. The data quality was improved after each of these steps through the proposed workflow. Compared with the original data, the conditioned final data show improved interpretability of the shale targets through geometric attribute analysis and depositional interpretation.

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Seismic Stratigraphy and Seismic Geomorphology: Insights on Characterization of a Carbonate Reservoir

Applied Mechanics and Materials ◽

10.4028/www.scientific.net/amm.138-139.447 ◽

2011 ◽

Vol 138-139 ◽

pp. 447-452 ◽

Cited By ~ 1

Author(s):

Ru Tai Duan ◽

Zhen Kui Jin ◽

Chong Hui Suo

Keyword(s):

Seismic Data ◽

Seismic Stratigraphy ◽

Depositional Environments ◽

Carbonate Reservoir ◽

Oil Field ◽

3D Seismic ◽

Element Analysis ◽

Hydrocarbon Production ◽

Seismic Geomorphology ◽

3D Seismic Data

Seismic stratigraphy and seismic geomorphology provides an indication of a carbonate platform’s internal and external architecture. High quality 3D seismic data integrated with wireline logs and core materials furthers detailed depositional element analysis, lithology prediction and diagenetic modification of the stratigraphic section, which help to build a depositional model, sequence stratigraphy framework and enhance the evaluation of the reservoir potential of this unit and a prediction of fluid flow during hydrocarbon production. This study mainly focus on using 3D seismic data calibrated with core and logs from oil field A to characterize the stratigraphy and geomorphology of the depositional elements of the carbonate reservoir (Aptaian Stage) and infer the process of the deposition where appropriate. Integration of seismic data with well data provides the frame work for reconstruction depositional evolution history the reservoir. The high seismic resolution of the A reservoirs also provides useful analogs for other subsurface reservoirs from similar depositional environments.

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RECENT DISCOVERIES IN THE PYRENEES MEMBER, EXMOUTH SUB-BASIN: A NEW OIL PLAY FAIRWAY

The APPEA Journal ◽

10.1071/aj04021 ◽

2005 ◽

Vol 45 (1) ◽

pp. 233 ◽

Cited By ~ 3

Author(s):

J.P. Scibiorski ◽

M. Micenko ◽

D. Lockhart

Keyword(s):

Seismic Data ◽

Joint Venture ◽

Depositional Environments ◽

3D Seismic ◽

High Quality ◽

Gas Field ◽

Geological Information ◽

Key Factor ◽

Complex Structural ◽

3D Seismic Data

Recent drilling by BHP Billiton Pty Ltd in WA-155-P(1) and WA-12-R, on behalf of its partners Apache Energy Ltd and INPEX ALPHA LTD, has resulted in the discovery of four oil fields in the southern Exmouth Sub-basin, namely Ravensworth, Crosby, Stickle and Harrison. These discoveries, together with the earlier discoveries made by West Muiron–5 and Pyrenees–2, define the Early Cretaceous Pyrenees Member play fairway.The Pyrenees Trend play was first conceived in 1999 following appraisal of the Macedon gas field (Keall, 1999), but the concept remained dormant until the integration of geological information with high quality 3D seismic data led to the recognition of hydrocarbon related seismic attributes in the postulated play fairway.Ravensworth–1 intersected a 37 m gross oil column below a 7 m gas cap in high quality Pyrenees Member sandstones beneath the regionally significant Intra- Hauterivian Unconformity. Ravensworth, located on a northeast–southwest trending fault terrace, is a complex structural-stratigraphic trap that relies on separate top, base and cross-fault seals. High quality 3D seismic data coupled with recent interpretation techniques were integral to its discovery. In particular, the quantitative interpretation of seismic amplitude populations was a key factor in decreasing exploration risk.The Ravensworth discovery was followed by successful exploration wells on the adjacent Crosby, Stickle and Harrison fault terraces. Four appraisal wells have since been drilled at the northern ends of the main discoveries.The oil in the Pyrenees Member discoveries is biodegraded, moderately viscous (8–11 cp) and heavy (18–19° API gravity). Methane-dominated gas caps were intersected in Ravensworth–1, West Muiron–5 and Pyrenees–2.The recent drilling and coring campaigns by BHP Billiton and others in the Exmouth Sub-basin have significantly advanced knowledge of the stratigraphy and depositional environments of the late Tithonian to early Berriasian Macedon, Muiron and Pyrenees Members of the lower Barrow Group. The lower Barrow Group is a third order sequence deposited rapidly in marine to fluviodeltaic environments in response to the breakup of Gondwana and the onset of active rifting along the West Australian margin.BHP Billiton and its joint venture partners are assessing the commercial viability of the Pyrenees Trend discoveries.

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Mesozoic tectonostratigraphic evolution of the North Carnarvon Basin unlocked using regional 3D seismic

The APPEA Journal ◽

10.1071/aj15070 ◽

2016 ◽

Vol 56 (2) ◽

pp. 564

Author(s):

Daniel Bishop ◽

Megan Halbert ◽

Katherine Welbourn ◽

Ben Boterhoven ◽

Stacey Mansfield ◽

...

Keyword(s):

Seismic Data ◽

Regional Scale ◽

Depositional Environments ◽

Single Channels ◽

Data Sets ◽

3D Seismic ◽

The North ◽

Basin Scale ◽

3D Seismic Data ◽

Carnarvon Basin

Interpretation of regional scale merged 3D seismic data sets covering the North Carnarvon Basin has for the first time enabled a detailed description of Mesozoic stratigraphic and structural features on a basin scale. Isoproportional slicing of the data enables direct interpretation of Triassic depositional environments, including contrasting low-stand and high-stand fluvial channel complexes, marginal marine clastic systems and reef complexes. Channels vary dramatically between sinuous-straight single channels within low net:gross floodplain successions, to broad channel belts within relatively high net:gross fluvial successions. The latter can be traced from the inboard part of the basin to the outer areas of the Exmouth Plateau. 3D visualisation and interpretation has demonstrated the huge variety of structural styles that are present, including basement-involved extensional faults, detached listric fault complexes, polygonal faults, and regional scale vertical strike-slip faults with flower structures. Fault trends include north–south, north–northeast to south–southwest, and northeast–southwest, with deformation events occurring mainly between the Rhaetian and Valanginian. Extensional and compressional deformation has created multiple horsts, three-way fault closures, fold belts and associated four-way anticlinal traps. Wrench tectonics may also explain pock-mark trains with the interpreted transfer of over-pressure from Triassic to Early Cretaceous levels. The use of regional scale merged 3D seismic data sets is now shedding light on tectonostratigraphic features on a basin scale that were previously unrecognised or enigmatic on 2D seismic or local 3D seismic data sets.

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3D seismic data integration to recommend drilling of PTT area, North Sumatra Basin

10.29118/ipa.1153.219.241 ◽

2018 ◽

Author(s):

A. Samodra

Keyword(s):

Data Integration ◽

Seismic Data ◽

3D Seismic ◽

Area North ◽

North Sumatra ◽

3D Seismic Data

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THE CASE STUDY OF CONVOLUTION NEURAL NETWORKS APPLICATION FOR THE PROCESSING OF REAL 3D SEISMIC DATA

Interexpo GEO-Siberia ◽

10.33764/2618-981x-2019-2-3-147-153 ◽

2019 ◽

Vol 2 (3) ◽

pp. 147-153

Author(s):

Georgy Loginov ◽

Anton Duchkov ◽

Dmitry Litvichenko ◽

Sergey Alyamkin

Keyword(s):

Neural Network ◽

Neural Networks ◽

Quality Control ◽

Data Quality ◽

Seismic Data ◽

3D Seismic ◽

Data Quality Control ◽

Static Corrections ◽

3D Seismic Data

The paper considers the use of a convolution neural network for detecting first arrivals for a real set of 3D seismic data with more than 4.5 million traces. Detection of the first breaks for each trace is carried out independently. The error between the original and the predicted first breaks is no more than 3 samples for 95% of the data. Quality control is performed by calculating static corrections and seismic stacks, which showed the effectiveness of the proposed approach.

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Characterising extrusive and intrusive magmatism at the Kipper Field, Gippsland Basin, using 3D seismic data

ASEG Extended Abstracts ◽

10.1071/aseg2016ab271 ◽

2016 ◽

Vol 2016 (1) ◽

pp. 1-7

Author(s):

Fun Meeuws ◽

Peter Reynolds ◽

Simon Holford ◽

John Foden ◽

Nick Schofield

Keyword(s):

Seismic Data ◽

3D Seismic ◽

Gippsland Basin ◽

3D Seismic Data

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New approach to appraise non-structural Tyumen formation traps in the absence of high quality of data

PROneft’ Proffessional’no o nefti ◽

10.51890/2587-7399-2021-6-3-43-51 ◽

2021 ◽

Vol 6 (3) ◽

pp. 43-51

Author(s):

Evgeniia M. Viktorova ◽

Daria I. Zhigulina ◽

Pavel Y. Kiselev ◽

Vladimir Y. Klimov

Keyword(s):

Seismic Data ◽

Depositional Environments ◽

3D Seismic ◽

Quality Of Data ◽

Resource Base ◽

High Quality ◽

Blind Test ◽

Sand Bodies ◽

3D Seismic Data

Background. On the one hand, the focus of exploration works changes to the more difficult reserves side, which were basically accumulated in the non-structural traps of Achimov and Tyumen formations. On the other hand, there are two important questions. The first is how the volume of reserves should be estimated correctly and the second is which volume of reserves is enough for economic successfully development. Aim. The main aim is to create a new actual approach of non-structural traps appraisal is considered in the absence of high quality of seismic data which allows identify such types of traps, which allows identify such types of traps. Materials and methods. Presented at the article algorithm enables estimate resources of non-lithological traps as exemplified in Tyumen formation, which was formed during depositional changes from continental to transitional depositional environments. The algorithm consists of some steps. The first step is collection on numbers, sizes and areas potential sand bodies based on different seismic attributes from analogies data. On the next step the coefficient which shows what numbers of geological bodies can be found on the unit of area was defined. Based on these data the probability distribution function which shows what part of studied area could be covered by potential bodies was made. After these steps, the integral resource base without regard to geological chance of success (gCoS) can be estimated. In order to account for geological risks the numbers of potential traps (including also non-structural traps), which were formed by meandering rives, tidal channels and point-bars, have to be defined. As a result, the discrete mathematical distribution of expected numbers of traps was made based on analogies data. If the oil infl ow was obtained from wells which have already drilled on the studied area part of resource base transfer to reserves (without including gCoS). Results. Discussed method was applied for “blind-test” on the new studied block with 3D seismic data. The obtained results of potential sand bodies fraction is correspond to the initial distribution from analogy fields. The method can be used for resource base potential on any block where there are lithological traps, which are controlled by mainly the facies conditions instead of structural plan, and also the 3D seismic data is absent. Conclusions. The appliance of discussed method which based on the available statistical data helps improve the quality estimation of change resource base range and allows to map the new prospective areas containing reserves and resources. One more important thing is this method allows to resolve the problem of base potential estimation and as a result to put a price on asset and risk capital values needed to explore the potential areas by drilling before the key outlays in the exploration program will be invested.

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