LAM IN ARIA—A NEW TIMOR SEA DISCOVERY

1996 ◽  
Vol 36 (1) ◽  
pp. 12 ◽  
Author(s):  
G.C Smith ◽  
L. A Tilbury ◽  
A. Chatfield ◽  
P. Senycia ◽  
N. Thompson.
Keyword(s):  
Joint Venture ◽  
Maximum Flow ◽  
Seismic Survey ◽  
Production Test ◽  
Oil Accumulation ◽  
Seismic Surveys ◽  
International Boundary ◽  
Timor Sea ◽  
Seismic Lines ◽  
East West

The Laminaria-1 discovery in the southeast of AC/P8 is a major new Timor Sea oil accumulation. The discovery well, drilled in October 1994, encountered a gross oil column of 102 m in deltaic to jiearshore marine sediments of the Callovian-Oxfordian Laminaria Formation. On production test, a maximum flow rate of 7,507 BOPD was recorded through a 5/8 in. choke. The oil is a light (59° API), undersaturated oil with a GOR of 175 SCF/STB. Laminaria-1 was the first well drilled by the AC/P8 Joint Venture since resumption of exploration following resolution of the international boundary between Australia and Indonesia.The Laminaria Prospect, originally identified prior to the boundary dispute, was detailed by seismic surveys in 1992 and 1993. The prospect was selected as the best of several structural targets, comprising a large complex horst block produced by major east-west faults, discernible on the 2D seismic lines at Aptian (KA) level. The prospect was expected to have Upper to Middle Jurassic Flamingo and Plover sandstone reservoirs, sealed by the Flamingo Group Shales,with hydrocarbons sourced from the same shales in adjacent synclines.Since the discovery, a comprehensive appraisal campaign has been undertaken to delineate the accumulation, including the acquisition of a large 3D seismic survey over almost the entire AC/P8 permit, and the drilling of a further two wells and a sidetrack. The Laminaria horst is now interpreted to comprise a series of tilted fault-blocks, orientated ENE to WSW and dipping to the southeast.

Discovery to development: a subsurface case history of the Kitan Oil Field, Timor Sea, Joint Petroleum Development Area, Timor-Leste and Australia

2013 ◽  
Vol 53 (2) ◽  
pp. 439
Author(s):  
Dave Wheller ◽  
Grant Ellis ◽  
Yohan Suhardiman ◽  
Ryosuke Yokote ◽  
Doani Selvaggi ◽  
...  
Keyword(s):  
Joint Venture ◽  
Oil Field ◽  
Oil Accumulation ◽  
Field Development ◽  
Timor Leste ◽  
History Of ◽  
Timor Sea ◽  
Development Area ◽  
Petroleum Development ◽  
East West

The Kitan oil field is located in the northern Bonaparte Basin in the Joint Petroleum Development Area, an area jointly administered by Timor-Leste and Australia. The Kitan structure is a Jurassic east-west trending tilted fault block. The Kitan–1 exploration well was drilled and successfully tested in early 2008. Kitan–2 appraisal well was drilled immediately after Kitan–1 and intersected the reservoir up-dip from Kitan–1 and confirmed the extension of the oil accumulation. The main oil-bearing section is in the shallow marine sandstone of the Middle Jurassic Laminaria Formation. It is divided into two reservoir zones: a blocky channelised sandstone (Unit–2) overlain by a dominantly finer-grained succession composed of coarsening-upwards para-sequences (Unit–1). Kitan oil field was declared a commercial discovery in April 2008 and a field development plan was submitted in May 2009 and approved in April 2010. Four development wells were drilled of which three were completed as producers, each employing an intelligent completion design to enable independent control and monitoring of the two reservoirunits. The three wells were tied back subsea via flexible flowlines and risers to the Glas Dowr FPSO. Oil production from the Kitan started in October 2011, about 3.5 years after the discovery of the field. The fast-track development of Kitan was achieved due to accelerated appraisal, prompt completion of studies, early commitment to long lead items, and excellent support from joint-venture partners and government.

3D baseline seismics at Ketzin, Germany: The C O2 SINK project

Geophysics ◽  
2007 ◽  
Vol 72 (5) ◽  
pp. B121-B132 ◽  
Author(s):  
Christopher Juhlin ◽  
Rüdiger Giese ◽  
Kim Zinck-Jørgensen ◽  
Calin Cosma ◽  
Hesam Kazemeini ◽  
...  
Keyword(s):  
Injection Site ◽  
Seismic Survey ◽  
Depth Interval ◽  
Storage Site ◽  
Borehole Data ◽  
Seismic Surveys ◽  
Drilling Operations ◽  
Heterogeneous Formation ◽  
Gas Chimneys ◽  
East West

A 3D 25-fold seismic survey with a bin size of 12 by [Formula: see text] and about [Formula: see text] of subsurface coverage was acquired in 2005 near a former natural gas storage site west of Berlin, as part of the five-year EU funded [Formula: see text] project. Main objectives of the seismic survey were to verify earlier geologic interpretations of structure based on vintage 2D seismic and borehole data and to map, if possible, the reservoir pathways in which the [Formula: see text] will be injected at [Formula: see text] depth, as well as providing a baseline for future seismic surveys and planning of drilling operations. The uppermost [Formula: see text] are well imaged and show an anticlinal structure with an east-west striking central graben on its top that extendsdown to the target horizon. About [Formula: see text] of throwis seen on the bounding faults. No faults are imaged near the planned drill sites. Remnant gas, cushion and residual gas, is present near the top of the anticline in the depth interval of about [Formula: see text] and has a clear seismic signature; both higher amplitudes in the reservoir horizons and velocity pulldown are observed. Amplitude mapping of these remnant gas horizons shows that they do not extend as far south as the injection site, which is located on the southern flank of the anticline. Amplitude anomalies, gas chimneys along an east-west striking fault, show that the stored or remnant gas either has been or is presently migrating out of the reservoir formations. Summed amplitude mapping of the planned injection horizon indicates that this lithologically heterogeneous formation may be more porous at the injection site.

THE ELANG OIL DISCOVERY ESTABLISHES NEW OIL PROVINCE IN THE EASTERN TIMOR SEA (TIMOR GAP ZONE OF COOPERATION)

1995 ◽  
Vol 35 (1) ◽  
pp. 44
Author(s):  
I. F. Young ◽  
T.M. Schmedje ◽  
W.F. Muir
Keyword(s):  
Seismic Data ◽  
Late Jurassic ◽  
Joint Venture ◽  
Seismic Survey ◽  
Normal Faults ◽  
Commercial Development ◽  
The North ◽  
3D Data ◽  
Porosity And Permeability ◽  
Timor Sea

The Elang-1 oil discovery in the Timor Gap Zone of Cooperation (ZOC) has established a new oil province in the eastern Timor Sea. The discovery well, completed in February 1994, recorded a flow of 5,800 BOPD (5,013 STBOPD) from marine sandstone of the Late Jurassic Montara beds. The oil is a light (56° API), undersaturated oil with a GOR of approximately 550 SCF/STB. Elang-1 was the first well drilled by the ZOCA 91-12 Joint Venture and only the fifth well in the ZOC since exploration of this frontier area resumed in 1992.The Elang Prospect, initially mapped by Petroz in the late 1970s on the basis of regional seismic data, was detailed by the 1992 Walet Seismic Survey. The prospect is the main crestal culmination on the Elang Trend, a prominent structural high to the north of the Flamingo High that was established during continental break-up in the Late Jurassic. The Elang Trend is bounded to the south by a series of en-echelon normal faults and connecting relay ramps and comprises a number of horst and tilted fault blocks.Elang-1 tested a near crestal culmination on the Elang Prospect and intersected a 76.5 m gross oil column below 3,006.5 m RT. At time of drilling this oil column was the thickest that had been encountered by any well in the Northern Bonaparte Basin. Good quality reservoir sandstone in six discrete bodies were intersected within the Montara beds. Core-measured porosity and permeability range up to 17 per cent and 2.2 Darcies within the oil column.Subsequent to the Elang discovery, the Joint Venture recorded a 402 km2 3D survey over the Elang Trend. Elang-2, an appraisal well spudded in September 1994 prior to receipt of the 3D data, established the lateral continuity of the Montara beds reservoirs. Flow rates of 6,080 BOPD (5,300 STBOPD) and 7,500 BOPD (5,970 STBOPD) from separate intervals have confirmed that high deliverabilities can be expected from individual sandstones. Further appraisal drilling is planned in the first half of 1995. This is expected to lead to commercial development of the field.

PETROLEUM POTENTIAL OF THE CEDUNA SUB-BASIN: IMPACT OF GNARLYKNOTS–1A

2005 ◽  
Vol 45 (1) ◽  
pp. 365 ◽  
Author(s):  
D. Tapley ◽  
B.C. Mee ◽  
S.J. King ◽  
R.C. Davis ◽  
K.R. Leischner
Keyword(s):  
Joint Venture ◽  
Hanging Wall ◽  
Seismic Survey ◽  
Wall Structure ◽  
Shelf Area ◽  
Hydrocarbon Source Rock ◽  
Petroleum Potential ◽  
North West ◽  
Hydrocarbon Charge ◽  
Play Elements

The Ceduna Sub-basin, located in the eastern Bight Basin, is one of the few frontier deepwater provinces in Australia whose hydrocarbon potential remains largely untested. The sediments of the sub-basin span an area of over 95,000 km2—comparable to the combined area of the Exmouth, Barrow and Dampier sub-basins on Australia’s North West Shelf. Prior to 2003, exploration wells had been drilled only on the present day shelf area of the sub-basin. The recent Gnarlyknots–1A well, drilled in May 2003 by the Woodside operated joint venture in EPP29, has provided the first calibration point in the under-explored deepwater area of the sub-basin.The well was the culmination of a basin analysis project that integrated results from prior drilling in adjacent areas, existing seismic surveys, regional gravity and magnetics interpretations, and a newly acquired 16,000 line km 2D seismic survey. Individual play elements of reservoir, seal, and hydrocarbon charge were analysed and combined to form play maps for key stratigraphic intervals. The Gnarlyknots prospect was chosen from more than 40 leads as the best location to test multiple play levels in an area interpreted pre-drill to be favourable for reservoir, seal, and charge.Gnarlyknots–1A confirmed the presence of several favourable play elements but failed to encounter commercial hydrocarbons. Excellent quality sandstone reservoirs, marine shale top seals and thermogenic hydrocarbon shows—indicating the presence of a hydrocarbon source rock in a mature kitchen area downdip—were all encountered in the well. The failure of the well is attributed to the absence of fault seal on the updip bounding fault of the drilled hanging wall structure. The implications of this well result for the prospectivity of the Ceduna Sub-basin have been analysed, and provide encouragement for Woodside to pursue future exploration programs in the region.

The Halladale and Black Watch gas fields—drilling AVO anomalies along Victoria's Shipwreck Coast

2009 ◽  
Vol 49 (1) ◽  
pp. 101 ◽  
Author(s):  
Andrew Constantine ◽  
Glenn Morgan ◽  
Randall Taylor
Keyword(s):  
Joint Venture ◽  
Seismic Survey ◽  
Amplitude Variation With Offset ◽  
Development Scenarios ◽  
Fault Block ◽  
Close Proximity ◽  
Strong Amplitude ◽  
Water Gradient ◽  
Seismic Amplitudes ◽  
Gas Fields

The Halladale and Black Watch fields are adjacent fault-dependent gas accumulations at the Turonian Waarre Formation level situated in the eastern Otway Basin, about 4–5 km from shore in VIC/RL2(v). The two fields were first identified in 2002 when anomalous seismic amplitudes were observed on the tail-ends of several 90s-vintage 2D lines that extended into what was then vacant acreage. After being awarded the block as VIC/P37(v) Origin Energy Limited and its joint venture (JV) partner, Woodside Energy Limited, acquired a 211 km2 full-fold 3D seismic survey over the anomalous amplitudes in late 2003. Subsequent analysis of the seismic volume revealed two tilted fault blocks with strong amplitude variation with offset (AVO) anomalies in the Waarre A and Waarre C units that conformed to structure and appeared to shut off at the same depth. A similar AVO anomaly was also observed in the overlying Santonian Nullawarre Formation, raising the possibility that Halladale and/or Black Watch had leaked or were leaking. In early 2005, the VIC/P37(v) JV drilled two exploration wells targetting the key Waarre C reservoir on the eastern flank of Halladale and eastern crest of Black Watch. Both wells encountered live gas columns in the Waarre C but no GWCs were observed on logs and wireline pressure data indicated the two fields were not in pressure communication. A third well was then drilled down-dip of the Waarre C AVO shut off on the Halladale fault block to obtain a water gradient from the Waarre C. This well proved invaluable in determining the height of the gas columns in the Waarre C at both fields as it showed the gas-water contacts (GWCs) at Halladale (1,760 mSS) and Black Watch (1,770 mSS) were shallow to their respective AVO shut offs by about 20 m and 10 m respectively. Subsequent analysis of shear wave sonic data from the third well indicated there is a 17 m residual gas column at the base of the Halladale Field. This suggests Halladale either leaked slightly at some time in the past or is still leaking. A similar scenario may also occur at Black Watch. Given the close proximity of the two fields to the coast, development scenarios from onshore are now being considered.

WARROON GAS DISCOVERY SUPPORTS EXPLORATION OF ANTICLINES

1981 ◽  
Vol 21 (1) ◽  
pp. 85
Author(s):  
B. R. BROWN
Keyword(s):  
Seismic Data ◽  
Acoustic Impedance ◽  
Gas Condensate ◽  
Seismic Survey ◽  
Seismic Surveys

Warroon, a small gas condensate discovery in the western Surat Shelf, was mapped as a faulted anticline from seismic data shot in April 1979. The discovery well was drilled in August 1979 on the then highest known point of the mapped closure. The well flowed up to 8 MMcf/D from about 2.4 m (eight feet) of Showgrounds Sandstone over the gross interval 2 048 to 2 060 m (6 720 to 6 760 ft). Subsequently, two small seismic surveys comprising 62 km and including experimental shooting and acoustic impedance processing have been shot over the anticline. A step-out will be considered in the 1981 drilling program.The discovery of gas and condensate in Warroon, and in the Glen Fosslyn discovery in an adjacent permit, optimistically suggests that the prospective area of the Wunger Ridge may be extended. A major seismic survey comprising over 450 km of 12-fold 96 channel recording was shot in the Spring of 1980. The interpretation of the data could lead to proposals to drill a number of wildcats on structures similar in appearance to Warroon.

THE CHELONIA SEISMIC SURVEY: MINIMISING ENVIRONMENTAL IMPACTS ON A NATURE RESERVE

1992 ◽  
Vol 32 (1) ◽  
pp. 429
Author(s):  
P.J. Long ◽  
V.L. Long
Keyword(s):  
Environmental Management ◽  
Environmental Impacts ◽  
Western Australia ◽  
Nature Reserve ◽  
Management Plan ◽  
Seismic Survey ◽  
Seismic Surveys ◽  
Innovative Methods ◽  
Environmental Management Plan ◽  
Bird Mortality

Onshore seismic surveys are traditionally associated with wide straight tracks, required for access by seismic vehicles and denuded of vegetation. The proposal by Lasmo Oil (Australia) Ltd and its co-venturers to perform a seismic survey on the Muiron Islands Nature Reserve was therefore received with some concern by residents of nearby Exmouth in Western Australia. The proponent undertook extensive surveys of the existing environment, however, and produced a strict environmental management plan which featured innovative methods to minimise impacts on both flora and fauna — in particular the extensive Wedge-tailed Shearwater colony on the islands. These methods were executed much as planned and caused negligible destruction of vegetation and no known bird mortality. The results indicate the management plan was highly successful and established a new benchmark for exploration in sensitive areas.This paper outlines the environmental management plan developed for the work and documents the results of the procedures employed. It concludes that such methods could be applied to similar projects elsewhere.

RIVOLI-1 GAS DISCOVERY — EXMOUTH SUB-BASIN, WESTERN AUSTRALIA

1992 ◽  
Vol 32 (1) ◽  
pp. 94
Author(s):  
Philip J. Lawry ◽  
Paul A. Carter
Keyword(s):  
Seismic Data ◽  
Joint Venture ◽  
Depositional Environments ◽  
Geochemical Analysis ◽  
Seismic Surveys ◽  
Range Type ◽  
Exmouth Gulf ◽  
Marine Seismic ◽  
Gas Bearing ◽  
Made In

Offshore exploration in the Exmouth Gulf commenced with seismic surveys during the early 1960s and resulted in the first well Bundegi-1 being drilled in 1978. This well, situated on the Rivoli-Bundegi Trend, encountered an interpreted residual hydrocarbon zone in the Birdrong Sandstone, an 18 m untested hydrocarbon zone in the Learmonth Formation, and tight, possibly gas bearing sandstones in the Mungaroo Formation.Modern shallow-water marine seismic data acquired by the EP 325 Joint Venture during surveys in 1987 and 1988 allowed accurate mapping of the basal Cretaceous section and the distribution of the Birdrong Sandstone. Complex structuring in the Jurassic and Triassic section was also resolved with the modern data.The Rivoli gas discovery, approximately 4.5 km northeast of Bundegi-1, was made in August 1989, with the intersection of a 10.5 m hydrocarbon column consisting mainly of gas but with a very thin oil leg (0.2 m). The Birdrong Sandstone reservoir comprises 10 m of fluvial sandstones overlain by 7 m of marginal marine sandstones and provides an important calibration point for depositional environments in this unit. The Rivoli gas pool occurs in a simple, downthrown anticline sealed by Winning Group shales. Geochemical analysis of oil extracted from core, suggests an earlier charge of 'Rough Range-type' oil, possibly generated from pre-Jurassic source rocks.Several prospects and a variety of play types are recognised and considerable exploration potential remains to be tested along the Rivoli-Bundegi Trend.

NORTH WEST SHELF 3-D SEISMIC—A DECADE OF DEVELOPMENTS

1993 ◽  
Vol 33 (1) ◽  
pp. 315
Author(s):  
P.S. Vaughan
Keyword(s):  
Joint Venture ◽  
Spatial Sampling ◽  
Seismic Surveys ◽  
North West ◽  
The North ◽  
Technological Developments

Woodside as Operator, on behalf of three Joint Venture groups, over the last decade has acquired eight 3-D seismic surveys covering some 4 600 km2 over the Rankin Trend and Dampier Sub-Basin Production Licences and Exploration Permits on the North West Shelf of Australia. This area represents approximately 45 per cent coverage of the present Woodside operated acreage in the area. The acquisition, processing and interpretation technology and also the benefits derived from the 3-D technique have changed remarkably since the first North West Shelf 3-D survey in 1981. This paper focusses on the main technological developments in 3-D seismic, particularly involving multi-source and streamer technology, increased spatial sampling and interpretation techniques which have changed the role of 3-D seismic in Exploration strategies through the 1980s and into the 1990s.

Australian national ocean bottom seismograph fleet advances conventional exploration

2017 ◽  
Vol 57 (2) ◽  
pp. 738
Author(s):  
Alexey Goncharov ◽  
Michal Malinowski ◽  
Dejan Sekulic ◽  
Ashby Cooper ◽  
Peter Chia ◽  
...  
Keyword(s):  
Regional Scale ◽  
Seismic Survey ◽  
Ocean Bottom ◽  
P Waves ◽  
Crust And Upper Mantle ◽  
Seismic Surveys ◽  
S Waves ◽  
Industry Standard ◽  
Ocean Bottom Seismographs ◽  
Obs Data

A fleet of new Australian ocean bottom seismographs (OBSs) have broadband frequency range, and similar instruments are available at only five or six institutions globally. These OBSs are multi-purpose devices able to record passive-source seismic data (earthquakes, ambient noise) as well as active-source (airgun generated) data and, at the same time, to monitor seismic survey noise and whale calls for environmentally responsible exploration. OBS data collected during commercial seismic surveys in Australian waters prove that it is possible to image the velocity distribution of the whole crust and upper mantle from analysis of both reflected and refracted phases generated by an industry-standard broadband airgun array. This means that valuable information on a regional scale can be obtained as a by-product of commercial seismic surveys. Three-component recording capability of OBSs allows analysis of S-waves in addition to the P-waves that are conventionally used in marine reflection surveys.

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