DEEP-WATER A New Frontier

• Deep water structures revealed by contemporary seismic and high resolution aeromagnetics • Gippsland petroleum systems extend into new acreage • Potential play-fairways identified

PESA News April/May 2000 VICTORIAN SUPPLEMENT MINISTER’S STATEMENT VICTORIAN SUPPLEMENT

he discovery of 's first giant petroleum fields in Bass Strait in the 1960's had a profound effect on both the Victorian and national economies. Major petrochemical industries and many other manufacturing and Tprofessional businesses are located in the State, largely because of the proximity to the oil and gas reserves in offshore Gippsland. As major a population and infrastructure base, the State provides employees and support for these companies as well as markets for their products. The Australian corporate headquarters of Exxon-Mobil, BP-Amoco and Shell are all located in , as well as smaller active oil companies.

Victoria is well served by its growing gas infrastructure. With coal fired electricity, the state has benefited from an abundance of energy sources, providing the most competitive energy pricing to business and domestic consumers in the nation.

The value of the resource extracted from the basins within and its Adjacent Area offshore exceeds $3 Billion per year. Although the State realises only a small portion of direct revenue from royalties, it is in the indirect benefit of having a local supply of oil and gas providing the ongoing relatively inexpensive energy that adds so much value to the State.

The Brack's Government was elected in 1999 with a mandate to increase energy supply security in the wake of the Longford tragedy in 1998. The Essential Services Commission will be established to address supply security for essential services including gas, electricity, water and public transport.

Intra- and Inter-state gas supply through the existing and future gas projects will not only augment supply security to Victoria and the adjacent states but is stimulating exploration interest. Victoria will also encourage the broadening of the gas supply base through providing information to attract and assist responsible exploration and interconnection with Victorian and interstate basins.

This encouragement of oil and gas exploration is the prime focus of this publication. As well as providing information relating to future releases of acreage under consideration, it provides a summary of activities relevant to the Petroleum sector by my Department and some of the companies already active in the area. I believe that both existing and future investors will be informed and retain it for future use.

Candy Broad Minister for Energy and Resources, Minister for Ports and Minister Assisting in State Development

CONTENTS

I MPV Division Structure 1

I Major Projects Demonstrate Confidence In Victorian Market - Geoff Collins 2

I Exploration Activities In Victoria - Maher Megallaa 3-6

Strike Oil - Well Positioned In Emerging Victorian Gas Province

Origin Energy - Explorating, Producing And Developing In The Otway Basin

Woodside - Gears Up For Eastern Australia

I Proposed 2000 Release Of Exploration Areas - Dr Mike Woollands 7

I Gippsland Basin: Potential Fields From Potential Fields - David Wong, David Moore & Dr Tom Bernecker 8-10

I Otway Basin Update - Andrew Constantine & David Moore 11

I Petroleum Resources & Production - 1999 - Kourosh Mehin 12-13

Esso - Opportunity Generation In Mature Fields - Bass Straits

I Petroleum Information Update - Bob Harms 14

I MPV Reports Listing 15

I List Of Tenements 16

I Tenements And Pipelines Map IBC

I Composite Deep-water Seismic Line OBC EGPL VICTORIAN SUPPLEMENT

MAJOR PROJECTS DEMONSTRATE CONFIDENCE IN VICTORIAN MARKET BY GEOFF COLLINS, MANAGER PETROLEUM FACILITATION

Construction commenced in NSW in August 2000 with first gas in mid 2002. The field, 1999 and in Victoria in January 2000. First which is about 10 km offshore in 60 m of gas is expected in September 2000. Initially, water, is estimated to have over 300 PJ of sales the pipeline will have a 60 PJ capacity, with gas. It is proposed that production is through up to 100 PJ planned as demand grows. two subsea completions to a processing plant Already a deal has been signed to supply 20 onshore. It is expected that gas would be Geoff Collins PJ to BHP steelworks in Port Kembla and Sithe piped through the South West pipeline which Energy's Smithfield cogeneration plant. Duke joins the Melbourne network at Lara. Major gas projects commencing in Victoria also has agreements to supply Energy will continue the pattern of the last few years Australia, Citipower and Integral Energy who Together, these projects indicate the breadth in taking advantage of the de-regulated will retail in the Sydney market. of the industry in Victoria. From production environment for gas marketing. Three to transmission to storage, they all have projects illustrate different segments of the The BHPP-Santos Minerva project is benefited from the de-regulated market that market. progressing to a decision on its future. The exists in Victoria and demonstrate a environmental work on determining an agreed confidence in the future. The Western Underground Gas Storage in route across the highly touristed Port western Victoria will use the nearly depleted Campbell National Park has been completed onshore Iona gasfield for winter gas and accepted. The project team put in production and summer storage. This takes outstanding effort in ensuring that broad NEW ONSHORE PETROLEUM advantage of the nearly two to one difference consultation and significant environmental ACT NOW IN OPERATION in winter and summer gas demand and the study led to an outcome that was acceptable de-regulation in prices. The project is owned to the majority of those affected. BHPP's plan The Petroleum Act 1998 came into effect by TXU, a Dallas based company, who also is for work to commence on the project late in on 1 December 1998. The Act brings own the Victorian electricity distributor and petroleum exploration and development retailer, Eastern Energy. The production administration into line with modern phase of the gas plant was completed in June, practice in Australia. The principal with first gas into the South West pipeline on changes are: 4th July 1999. In this initial phase, up to 100 TJ/day was supplied to the Melbourne gas • Exploration permits are for a five year market by producing gas from the Iona field, term with a single five year renewal with blended with low CO2 gas from the Mylor 50% relinquishment, bringing them into and Fenton Creek fields owned by Santos. line with other Australian legislation The injection phase of plant construction was • Introduction of Retention Leases to give completed March 2000, in time to allow the security to currently non-economic Iona reservoir to be filled prior to winter discoveries 2000. The storage capacity of the facility will be 10 PJ. Gas will be purchased from either • Production Licences to be for ‘life of Otway, Gippsland or Cooper Basin producers field’ The Western Underground Gas Storage project and injected over about 200 days. It will be is a vital link in the strategy to improve the • Recognition of gas storage depleted over about 80 days during winter, security of Victoria’s gas supply. with a maximum capacity of 200 TJ/day. It is • Legislated transparency in the acreage intended that, as demand grows, additional award process depleted fields in the area will be converted • Flexibility in royalty for marginal fields to gas storage. The project makes use of the South West pipeline, completed in 1999, to • Introduction of Operation Plans for transport gas to and from Melbourne. operations, a move away from prescriptive requirements The Eastern Gas Pipeline runs from the Longford gas plant in Gippsland, to Sydney • Clarification of access to land. Planning permit no longer required for via Canberra. This $450 million, 795 km exploration operations pipeline will provide opportunities along its length. These include reticulated natural gas • Improved access to data, in line with the for communities, power generation and ties PSLA to production from northwestern fields in the offshore Gippsland Basin. The project is Notice has been provided to onshore owned by Duke Energy, a North Carolina operators as to how the changes will affect based company that also owns the them. If you have any questions about the Queensland pipeline, two power stations in legislation, please contact, in the first WA, and is undertaking a feasibility study Bernie Fablish (left) and Mick Gander (right) instance, Rob King at Ph 9412 5069 or on a Longford to Tasmania pipeline. Inspect trenching and stringing near Nowra. email [email protected]

2 PESA News April/May 2000 EXPLORATION IN VICTORIA VICTORIAN SUPPLEMENT

EXPLORATION ACTIVITIES IN VICTORIA BY MAHER MEGALLAA, MANAGER ACREAGE RELEASE

Maher Megallaa

VIMP 2001 Promoting Exploration

In 1998-99, MPV, through a collaborative joint venture with Seismic Australia (SA), acquired and processed 981 line km of seismic in the deep-water region of the Gippsland Basin (GDW99 Survey) under the umbrella of VIMP 2001. This year, the petroleum component of the VIMP 2001 included the reprocessing of 4271 line km distributed as follows: -

• 2865 km from selected AGSO [BMR 1987] deep-water and relinquished VIC/P24 survey lines. Its objective is to 1) assist in evaluation of two areas to be released in May 2000 by the Joint Gippsland Basin reprocessed seismic grid (2865 km) available to industry on a non-exclusive Authority (see opposite map), and basis. 2) provide contemporary infill data for the GDW99 Survey and for the released shelf Gippsland Basin seismic through a joint Perth: area. The project was granted to venture with MPV. Veritas-DGC is under- Steve Jeffrey - Australian Seismic Brokers Australian Seismic Brokers (ASB) in a joint taking the reprocessing at their Perth data Ph 08 9479 5900 venture with MPV on a non-exclusive processing center. The final data set will form Email: [email protected] basis. a part of the ASB-Veritas non-exclusive data Melbourne: library, comprising newly acquired Maher Megallaa - Minerals & Petroleum • 1106 km from selected Shell OS88A and speculative seismic data and 150,000 km of Victoria OS90A survey lines and the processing of reprocessing, with a further 14,000 km of Ph 03 9412 5081 six lines from AGSO's VM96 survey (also reprocessing to be completed in 2000. The Email: [email protected] on a non-exclusive basis by ASB–MPV). Gippsland deep-water reprocessing is the first Singapore: The objective is to assist the industry in of the year 2000 projects and will include Sami Khan - Veritas - DGC evaluating the petroleum potential of the Kirchoff full pre-stack time migration. This Ph 65 258 1221 re-released Torquay Sub-Basin V99-1 algorithm, in which the data is transformed to Email: [email protected] acreage to be closed on the 6th April 2000 the migrated gather domain, has a number of (see Fig. 1. page 7). positive benefits. It will assist in producing Onshore Gippsland Exploration accurate velocity analysis and consequently • 200 km of regional lines in the onshore allowing multiple suppression techniques to Onshore Gippsland Basin permits continued Otway Basin. The objective is to provide be more vigorously applied to the pre-stack to receive exploration activities from MPV's Basin Study and industry time migrated gathers. As the area covered by committed seismic and well drilling geoscientists with contemporary data to be the reprocessed grid is of rugged sea floor programs. Bass Petroleum completed a augmented with other regional grid lines topography extending from the shelf edge geochemical survey and already acquired to assist in the understanding of the across to the Bass Canyon, to have well 50 km of seismic data from a planned 100 km structural evolution of the basin and the imaged pre-stack time migrated data will seismic survey in year 2000. While Lakes Oil Australian Southern margin in general. allow an easy progression to pre-stack depth is planning to drill one well in PEP 137. It also Seismic contracting companies were migration. Sample lines utilizing pre-stack recorded the Killingal seismic survey to invited and the tender will be announced depth migration are available for viewing and properly delineate the previously drilled shortly. additional lines will be processed should the North Seaspray prospect. In PEP 138 Lakes interpretation of the area indicate that this is Oil acquired a 25 km survey over a ASB - Veritas Gippsland beneficial to understanding the prospectivity 4-way dip closure near Woodside South 1 Reprocessing of the gazetted areas. with top and intra Latrobe Group objectives. It is currently assessing the potential of PEP Australian Seismic Brokers is currently The data is available for viewing by 136 after drilling Investigator-1 well in 1999 reprocessing 2865 line km offshore contacting: - and will acquire a small seismic survey in 2000.

PESA News April/May 2000 3 EXPLORATION IN VICTORIA VICTORIAN SUPPLEMENT

STRIKE WELL POSITIONED IN EMERGING VICTORIAN GAS PROVINCE

Strike Oil NL considers the Shipwreck Trough suppliers in Eastern Australia area of the Victorian Otway Basin (Fig. 1), to along side established producers, be the most likely source of alternate domestic ESSO/BHPP, Santos and Origin. gas supplies for Eastern Australia. The likely development of the The discovery of the Minerva and La Bella gas Minerva gasfield by BHPP and the fields, with estimated in place reserves of 500 exploration programs by Strike in and 200 Bcf respectively, confirms an active VIC/P44 and the Origin, Woodside, petroleum system. The Shipwreck Trough is Cal Energy group in adjacent the fairway for the excellent Warre Formation VIC/P43, will result in this area reservoir sands and overlying thick Belfast becoming the most active in the Mudstone seal found at Minerva. Prospects region over the next few years. and leads in the region indicate the potential for Tcf scale opportunities. Only five wells Strike's permit covers approximately have been drilled in the vicinity of the 2500 km2, immediately adjacent to 1000 km2 Trough. Two of these made the Minerva and La Bella gas fields, significant gas discoveries (Minerva and La and contains a significant portion of Bella), one flowed gas (Pecten 1A) and two the Shipwreck Trough. The Pecten 1A others were dry, indicating a very high early well drilled by Shell in 1967 (the first Fig. 1. success rate in a still immature exploration well drilled in the offshore Otway area. Basin), flow tested gas and water in the dip well could flow significant gas from what equivalent section to the gas pay zones in could be a multi-Tcf structural complex. Strike, an Australian unlisted exploration Minerva and La Bella. These fields were company, is well positioned in this emerging discovered in 1993, 26 years after Pecten 1A, Strike has commenced mapping and will re- offshore gas province with a 100% working using much improved seismic. The modern process much of the existing 2D seismic, prior interest in VIC/P44. Strike views its holding as seismic indicates the Pecten 1A well is to positioning 3D seismic over the most a core exploration assets, with the potential to significantly off structure on the downthrown prospective areas. Seismic Line CD (Fig. 3) propel it into the ‘major league’ of gas side of a major fault (Line AB Fig. 2). An up- indicates potential large fault block traps in the axis of the Shipwreck Trough (Fig. 1), adjacent to the Minerva Gas Field. Strike is planning to acquire the 3D seismic, necessary to define these large fault blocks, in the forthcoming summer season and aims to have a drilling location selected by mid to late 2001.

A commercial discovery, in the order of a Tcf of gas, would have a significant effect on a company Strike's size and would impact the Victorian and other Eastern States gas supply dynamics. The strategic location of VIC/P44 to markets, developing gas storage and pipeline infrastructure, suggest that a commercial discovery could be developed and brought to market in a timely manner. Fig. 2.

Fig. 3.

4 PESA News April/May 2000 EXPLORATION IN VICTORIA VICTORIAN SUPPLEMENT

ORIGIN ENERGY - EXPLORING, PRODUCING AND DEVELOPING IN THE OTWAY BASIN

Origin Energy (formerly Boral Energy) is an In 1999, Origin participated in the drilling of flow of 15.05 MMscf/day. Production to the active explorer and producer in both the three wells, all located in PPL 1, in which it has Melbourne market commenced in February Victorian and adjoining South Australian a 100% interest. The first two wells, North 2000 under a new contract with Energy 21. Otway Basin. In Victoria it operates and is a Paaratte 4 and North Paaratte 5 were deviated participant in four onshore exploration permits wells drilled in March and April 1999 from a Each of these wells demonstrates the ability of (PEP 101, 111, 119, and 133, see map inside surface location at the North Paaratte 1 well Origin Energy to identify drilling opportunities backcover), one offshore exploration licence site. The wells were planned as producers and and bring them on stream to address existing (VIC/P43) and has onshore gas production were positioned crestally to address attic gas and new markets. from three fields (North Paaratte, Wallaby reserves not accessible from existing wells. Creek and Wild Dog Road) in production Both wells successfully targeted the Late In its onshore exploration permits, Origin is licence PPL1. Recently this portfolio was Cretaceous Waarre Formation (Unit ‘C’ also maintaining an active work program of enlarged by a successful bid for a new sandstone reservoir) flowing at 15 MMscf/day technical studies and seismic acquisition that is exploration permit gazetted as VIC-99(1). during post-completion clean up operations. aimed at identifying new drilling opportunities The wells have since been completed and focussed at established and emerging Origin is the Operator of each of these permits were used to supplement gas supply from Bass marketing opportunities in the region. with the exception of PEP 119 which is Strait during the winter of 1999. operated by Santos Limited. This article In newly awarded offshore permit VIC/P43 summarises the highlights of recent and The third well Wild Dog Road 1 is an Origin and its Joint Venture participants planned activities by Origin Energy in the exploration well was drilled in December participated during December 1999 and Victorian Otway Basin. 1999. It is also located in PPL 1 and targeted a January 2000 in the recording of a large new fault-bounded structural closure defined 790 km2 3D seismic survey and the acquisition Origin acquired its equity in its onshore using the 1998 3D Waarre Seismic Survey at of 126 km 2D seismic. This program is aimed exploration and production licences by the top of the Waarre Formation, Unit ‘C’ at detailing a number of large Waarre purchase of these assets from Cultus Petroleum sandstone reservoir level. The structure is Formation leads located along the axis of the in 1998 and has since engaged in an active located to the north-east of the North Paaratte Shipwreck Trough. Following processing and work program of drilling, seismic, geological Gas Field. Wild Dog Road 1 intersected a gross interpretation of the new seismic, it is likely and geophysical studies and production hydrocarbon column of 20 m. The well was that an offshore well will be drilled during operations. cased and production tested resulting in a gas 2002.

WOODSIDE GEARS UP FOR EASTERN AUSTRALIA

The plays in Woodside's strategy to enter the Woodside picked up its first stake in Kipper by network, and frequent-flyer loyalty program of eastern Australian gas market were unveiled in buying Petroz Offshore Pty Ltd for $5 million. Shell, and potential access to competitive, quick succession in March this year. The agreement gave Woodside a foothold in alternative gas resources held by Woodside. Bass Strait with a 2.5% stake in the Kipper The first involved Woodside and its alliance block. At the time, Woodside also acquired a Woodside's interest in Pulse Energy is part of partner, Shell Development Australia, 5.889% stake in the adjacent Basker-Manta- its strategy to build relationships and capture reaching a significant milestone on March 6th Gummy block in VIC/P19. It mopped up the markets for its south-eastern, northern and with the announcement of a letter of intent to balance in March this year when it bought north-western Australian gas resources, and it supply gas to Methanex for a major synthetic Shell's 94.12% interest for $10 million. sees eastern Australia as an important and gas plant at Darwin. major long-term market. The third critical leg to Woodside's strategy Using the large Sunrise and Troubador gas occurred on March 8th when Woodside, Part of this strategy involves the commitment fields in the Timor Sea, the Northern Australia Shell, United Energy and Energy Partnership of business units to developing these Gas Venture partners have conditional announced the formation of Pulse Energy to opportunities. As part of the company's recent agreement from Methanex to supply 110 tackle the national retail energy market. organisational changes, Woodside appointed petajoules of gas a year for the proposed plant. Jeff Schneider as Director of Australian Gas. The four companies announced that Pulse His accountabilities look to build a profitable Two days after the Methanex announcement, Energy will initially service more than one new domestic gas business in eastern Australia Woodside and Santos announced their million Victorian customers with the aim of and to commercialise gas reserves in northern agreement to jointly acquire Shell's Bass Strait rapidly becoming a national energy player as Australia. interests in the Kipper Field in VIC/RL2. electricity and gas markets are deregulated. Schneider, formerly Woodside's General Woodside and Santos offered Shell $53.5 Effective ownership of the new company is Manager, Commercial, brings into his new million for its 34.5% interest. The acquisition Shell 40%, United Energy 25%, Energy role 21 years of experience with Woodside. In is subject to pre-emption by the other partners, Partnership 25% and Woodside 10%. former positions, he was instrumental in Esso and BHPP. A successful acquisition managing the restructuring of the domestic gas would result in Woodside having 30% and contracts in Western Australia from 1993- Santos having 20% of VIC/RL2. Pulse Energy combines the Victorian-based 1995 and in establishing the Woodside-Shell retail electricity business of United Energy Alliance in 1998. He also acted as a The push by Woodside into eastern Australia with the equivalent gas business of Ikon began in earnest in September 1999 when Energy, along with the brand name, customer Continued On Page 6

PESA News April/May 2000 5 EXPLORATION IN VICTORIA VICTORIAN SUPPLEMENT

Continued From Page 5 representative for Woodside's interest as an investor in projects such as the North West Shelf Venture and Laminaria.

Woodside's new direction, along with its relatively recent acquisitions in Victoria, are part of the growth plan to diversify the company's earnings base from the North West Shelf Venture and the Laminaria- Corallina oil field in the Timor Sea.

Under the new eastern and northern Australian gas business unit, a new group dedi-cated to Bass Strait development, and based in Mel- bourne, has been created. Mike Krzus has been appointed General Manager, Bass Strait, and he will have respon- sibility for reali- sing value from the Bass Strait investments.

Mike Krzus He will also work with Woodside's Australian Oil business unit, led by Keith Spence, to commercialise the Basker-Manta- Gummy prospect.

In complementing these new ventures, Woodside is also exploring in south-eastern Australia, with interests in the Otway and Gippsland basins.

Woodside began exploration in Otway permit VIC/P43 permit location map; highlighting in red the area where the Western Pride VIC/P43 in December 1999 as part of a $30 has been conducting the 3D seismic acquisirtion. million work program with Origin Energy (formerly Boral) and CalEnergy. Origin and CalEnergy each has a 25% interest in the permit and Woodside has 50%. manager for the Otway seismic program, has were unsuccessful, the enthusiasm of its moved to head up the geological services management at the time never waned. After being awarded the six-year exploration department within Woodside. Through 1959 and 1960 Woodside increased lease, the joint venture contracted Woodside its Gippsland acreage, but commercial to manage the exploration phase of the Looking outside Victoria, Woodside has also discoveries eluded it. program. An offshore well is planned this year secured another opportunity to participate in or early 2001. supplying gas to the eastern states of Australia 1n 1963, Woodside acquired permits over a through its 14.26% stake in Oil Search vast area of the North West Shelf off Western Woodside has also taken up an option to earn Limited. Acquired in 1999, this has Australia. Major gas discoveries in the 1970s 50% in a permit south of VIC/P43 in positioned the company to benefit from saw the birth of the North West Shelf Gas Tasmanian waters, covering about 6309 km2. successful implementation of the Papua New Venture, Australia's biggest and most The T/30P partners are Benaris N.V. with Guinea-to-Queensland gas pipeline. ambitious resource development. 20%, and Origin with 30%. The joint venture is in the third year of the permit term and is As the company nears its 50th anniversary, As Woodside is in pursuit of expanding and committed to seismic with a well possibly this Woodside - named after the town of Woodside developing its interests in eastern and year. Leads have been identified in both in Gippsland in 1954 - faces new oppor- northern Australia, it hopes to bring to these permits. tunities and prospects that enable the markets the core competencies and company to return to the place where it all capabilities that it has developed over 15 Managing the Otway Basin program and its started. years as operator of the North West Shelf seismic activities is Dr Joe McNutt, Venture, and as the major gas supplier to Woodside's Exploration manager for VIC/P43 Although the company's initial exploration Western Australia. and T/30P. Dr Mark Shuster, formerly project activities with one of Gippsland Oil's leases

6 PESA News April/May 2000 PROPOSED 2000 RELEASE OF EXPLORATION AREAS VICTORIAN SUPPLEMENT

PROPOSED 2000 RELEASE OF EXPLORATION AREAS OFFSHORE VICTORIA

BY DR MIKE WOOLLANDS, MANAGER BASIN STUDIES

Each year, Minerals and Petroleum Victoria and Paaratte Formations, and Timboon recommends to the Commonwealth which Sandstone. Other plays include the offshore Victorian acreage should be Paleocene Pebble Point and Eocene Dilwyn considered for release. Two offshore blocks Formations, and Oligocene low-stand fans off in the Otway Basin and three in the the edge of the continental shelf. The latter Gippsland Basin have been proposed for could have significant size potential, but are release this year (Figs. 1 and 2). A brief yet to be tested. summary of the areas is given below. Invitations to submit work programme bids The main plays in the eastern block are low- Dr Mike Woollands under the Commonwealth Petroleum stand plays in the Tertiary Wangerrip and (Submerged Lands) Act 1967, are expected to Nirranda Groups. Potential source rocks be made at the APPEA Annual Conference in include the Otway and the basal Sherbrook likely gas prone. The Waarre Formation Brisbane during May. Groups. Geochemical analysis of the latter, could also be a potential reservoir. by MPV and AGSO, indicates the base of this Otway Basin Areas (Fig. 1) unit is oil mature in the block, but is most Continued On Page 8

The western block is situated approximately 50 km SW of Portland (see Fig. 1). It is 1868 km2 in area and lies mostly in less than 200 m water depth, increasing to 500 m at its southwestern edge. The area overlies the Late Cretaceous Voluta Trough. Four wells have been drilled in the block: Voluta-1, Discovery Bay-1, Bridgewater Bay-1 and Normanby-1. All four targeted Late Cretaceous tilted fault- blocks, with Normanby-1 encountering weak gas shows in the basal Waarre Formation. The other wells were dry, being either off structure or the target horizons incorrectly picked.

The eastern block is situated approximately 90 km SE of Portland (see Fig 1). It is 1874 km2 in area and is situated at the shelf edge in 50 to 1000 m of water (80% less than 200 m deep). The area straddles the WNW- ESE Mussel Fault Zone, which separates the Voluta Trough from the Mussel Platform. Fig. 1. Otway Basin 2000 recommended acreage release areas. Only two wells have been drilled: Nautilus-1 and Triton-1; both proving dry. Nautilus-1 tested a Tertiary 'clastic-wedge' play, but the target had no reservoir. Triton-1 tested a Waarre Formation tilted fault block prospect, which proved water-wet and tight.

Despite these results, the two areas are likely to have significant potential. Previous failures can be attributed to poor seismic data and, as the discoveries at La Bella and Minerva attest, an active petroleum system does exist offshore, sourced from the gas-prone Early Cretaceous Eumeralla Formation, which underlies the blocks.

A re-evaluation has been carried out by MPV to identify play fairways within these blocks (VIMP Report No. 66). The main play type in the western block is Late Cretaceous tilted fault blocks, as at La Bella and Minerva. Potential targets include Waarre, Flaxman Fig. 2. Gippsland Basin 2000 recommended acreage release areas.

PESA News April/May 2000 7 GIPPSLAND POTENTIAL FIELDS VICTORIAN SUPPLEMENT

GIPPSLAND BASIN: POTENTIAL FIELDS FROM POTENTIAL FIELDS BY DAVID WONG, DAVID MOORE AND DR TOM BERNECKER, SENIOR GEOLOGISTS

Introduction

The Gippsland Basin in southeastern Australia is a world class oil and gas- producing province, with significant remaining potential that can be realised by applying new technology and concepts. MPV's current fully integrated basin-wide study aims to re- define prospectivity and delineation of new hydrocarbon play fairways, particularly in the eastern, deeper water areas of the basin. The study uses the newly acquired 980 km deep-water seismic, AGSO's 1999 David Wong David Moore Dr Tom Bernecker airborne magnetic survey (Fig. 1) and existing open file geophysical and geological data. This article discusses some Geology structures of the North and South Terraces of of the results and their implications on the the basin are, at least in part, reactivations of remaining basin prospectivity. Pre-rift these earlier faults. The largest of the Devonian rifts, the Buchan Rift, can be traced Aeromagnetics provide deep structural data Basement structural fabrics play an important using magnetics and gravity to the south- that, together with seismic interpretations, role in controlling basin architecture and the southwest, beneath the Sweetlips discovery permits a far sounder basis to develop reliable establishment of effective petroleum systems. and almost to the Snapper Field. The basin models rather than using seismic alone. The Palaeozoic surface, exposed onshore, has Snapper-Sweetlips anticlinal axis is near This study has shown the location and a magnetic signature and fabric that extends coincident and may well be linked with this geological role of previously unrecognised beneath the Gippsland Basin. New onshore basement feature (Fig. 1). Modelling on this deep structural features that impact on the mapping has shown that this basement and other structural/aeromagnetic prospectivity assessment of the basin. These comprises successive south-directed arcuate correlations using this new data features are discussed chronologically below. thrust slices. It is possible that the bounding Continued On Page 9

Continued From Page 7 The remaining two blocks are located in the results are being documented in VIMP Report southeastern deep-water part of the basin No. 65, which describes the geological Offshore Gippsland Basin Areas covering the Bass Canyon. Together, the two framework, depositional history and structure (Fig. 2) areas cover 5238 km², and water depths of the areas. A tectonic elements map (Fig. 3 range from 600 m (210 m in the northern on page 10) and a series of facies maps are Of the three proposed blocks, one shallow block) to 3000 m. The areas are covered by included, which describe key elements of the water area, covering 718 km², is located in widely spaced BMR seismic lines, the tails of deep-water petroleum systems. The the north of the basin. The area lies 50 km shallow-water lines and by a new regional characteristics of relevant nearby ESE of Lakes Entrance in water depths of 20 to grid acquired for MPV by Seismic Australia hydrocarbon accumulations are also 75 m. It straddles the Northern Terrace and (GDW99 Survey). The northern area also has examined, where they relate to the Northern Platform, and includes untested 1 to 3 km spaced seismic data in the interpreted play types in the deep water. Play prospects and leads associated with Top and shallower water parts. Only two wells have fairways are delineated and for each, intra-Latrobe Group, Golden Beach and been drilled in the latter area; both were dry, potential trapping styles are discussed and a Emperor Subgroup targets. The area is on the penetrating only the top of the Latrobe Group risk profile generated to assist in focusing main migration pathway for hydrocarbons and providing little information on deeper future exploration effort. generated in the basin, as evidenced by the prospective sections. Patricia-Baleen Gas Field. The block's Both areas have significant potential, in that potential has been documented by MPV The Basin Studies Group of MPV has carried all of the petroleum systems components are (VIMP Report No. 56) and further out a regional assessment of the area’s interpreted to be present. The prospective understanding is being developed through hydrocarbon prospectivity, based on an play fairways are on trend with known and integration of the new aeromagnetic data integration of open file and commercially tested accumulations of both oil and gas, with existing seismic mapping (see article available seismic data (including GDW99 some of which offer potential for large above and Fig. 4 on page 10 ). data) and new AGSO aeromagnetic data. The accumulations.

8 PESA News April/May 2000 GIPPSLAND POTENTIAL FIELDS VICTORIAN SUPPLEMENT

marine sedimentation in the basin that corresponds to the opening of the Tasman Sea. Northwest trending faults, normal to the Tasman extension direction, largely controlled deposition, particularly in the south and east. These contrast with previous rift phase structural trends. In the east of the magnetic image, similarly trending dyke swarms may be associated with the start of this phase. These faults are the first major set to significantly cut across the basement fabric and develop sub-parallel with the final sag axis of the basin.

This interval has important source rocks and potential for oil and deep gas traps. Prior to the current interpretation, there was little confidence in the presence or impact of these northwest-trending fault sets; and the Golden Beach Subgroup was relatively poorly understood. The new data are being applied to develop more robust models of this interval and to allow exploration of its considerable gas and oil potential.

Post-rift sequences

Volcanism accompanied episodes of post-rift Fig. 1. Location map showing both airborne magnetic image and new seismic coverage in relation to the normal faulting. Volcanic centres can be producing fields. Recommended release areas outlined in red. linked to the now-located basement- generated margin offsets. Thermal sub- sidence provided the accommodation space Continued From Page 8 information for better constrained basin and for the deposition of coal-bearing coastal structural modelling. plain sediments, marine sands and shales of may provide useful information about the Latrobe Siliciclastics. Deep basement prospectivity beneath these productive The Emperor Subgroup was deposited in a features subtly influenced these depositional trends. synrift phase coinciding with the opening of patterns. the Southern Ocean to the west. Its The Gippsland Rise, in the southeastern depositional setting is dominated by deep Eocene compression reactivated early rift Gippsland Basin (Fig. 3), has a distinctly lacustrine sedimentation in a series of half- faults, forming them into NE-SW trending different magnetic fabric. Magnetic highs here grabens on trends largely coincident with inversion anticlines. Finally, marine carbo- have a more circular appearance, suggesting those of the Strzelecki Group. nates of the Seaspray Group were deposited responses from post-deformational igneous in a mature drift phase setting in a temperate bodies. Similar potential field responses are The Golden Beach Subgroup (late synrift) is climate. also present on the western edge of the Permo- characterised by the first appearance of Continued On Page 12 Triassic Sydney-Bowen Basin onshore in southern New South Wales. Equivalent sedimentary rocks are known from the Lord Howe Rise and southeastern Tasmania. It is thus reasonable to expect the presence of these rocks below the eastern Gippsland Basin.

Synrift sequences

From Late Jurassic to mid-Cretaceous, the Gippsland Basin was part of a major continental rift system. Northeast-trending grabens and half-grabens, including the precursors to the offshore Central Deep and onshore Strzelecki Ranges, were filled with up to 10 km of dominantly fluvial sediments of the Strzelecki Group. This structural grain is strongly oblique to the current east-west Gippsland Basin axis and was partly controlled by the Palaeozoic basement grain. The new aeromagnetic data confirm the persistence and location of these trends across the basin, providing important

Fig. 2. Stratigraphic chart showing tectonic history and petroleum systems.

PESA News April/May 2000 9 GIPPSLAND POTENTIAL FIELDS VICTORIAN SUPPLEMENT

Continued From Page 9 Fig. 3. Structural elements map of the deep-water release areas. Results Faults and other structural features are based on integrating the new The use of the deep structural data, based on aeromagnetics and seismic with the aeromagnetic dataset, is leading to a new existing data. understanding of basement architecture, basin history and petroleum systems. This They show the interplay of the NE- has already provided new insights and will SW and NW-SE structural trends encourage new exploration in the Gippsland and the Golden Beach Basin. depositional system. Varying structural styles suggest many potential play types. The aeromagnetics and deep-water seismic provide a clear view of the basin rift sequences (Golden Beach Subgroup and older), unimpeded by the severe masking generated by the thick Latrobe Siliciclastics succession and Cainozoic carbonates of the central and western basin. Understanding the rift intervals in the deep water will prove invaluable for exploration and development in the basin.

In the eastern Gippsland Basin, a more detailed study has greatly improved the understanding of the complex depositional and structural history of the current deep- water gazettal acreage. The structural elements map (Fig. 3) shows part of the results Fig. 4. Integration of magnetic and of this deep-water evaluation carried out by old seismic data, southern part of the Basin Studies Group. See VIMP Report 65 northern Release Area and listed on Page 17. surrounds. Figure 1 gives approximate location. Another study (Fig. 4) is focused on the a) Esso's (1969) Top Strzelecki northern basin margin. In this area, the structural depth map; aeromagnetic interpretation shows basement b) Fault pattern from a) super- structures that may reflect the structures imposed on an image derived from controlling the overlying hydrocarbon the AGSO (1999) aeromagnetic accumulations. Further intergration of survey; aeromagnetic with seismic and other data is c) Basement fault patterns currently being carried out to understand the interpreted from the magnetic data relationships between faulting patterns and and integrating the Esso seismic stratigraphy. interpretation. North-trending faults are considered to reflect reactivated Palaeozoic faults, while The Future the ENE and WNW faults are younger, probably post-Palaeozoic. The study has already yielded important Many may have been inverted. information and will provide a new impetus for exploration and development in the basin. While the Esso interpretation The data and interpretation will be published seems to broadly fit with the magnetic data, several second- and made available to the industry and public order differences exist:- in the near future. • The Baleen-Patricia Gas Field is now seen to be controlled in part by ENE-trending faults; • The northern boundary fault, the Lake Wellington Fault system is now seen to be a stepped series of ENE and WNW-trending faults; • The fault patterns in the centre of the area have been better resolved; and • The basement ridge that Sweep 1 lies on can be seen to trend deeper into the basin towards the Tuna Field; at least one WNW fault seems to cross the ridge. Interpretation in the region is on-going.

10 PESA News April/May 2000 OTWAY BASIN TECHNICAL VICTORIAN SUPPLEMENT

OTWAY BASIN UPDATE BY ANDREW CONSTANTINE AND DAVID MOORE, SENIOR GEOLOGISTS

Andrew Constantine David Moore

As part of the VIMP 2001 Initiative, the • Top Basement as well as processing the VM96 survey Petroleum Development Unit (PDU) is acquired by AGSO for MPV in 1996 (c. 450 currently working on projects aimed at • Top Crayfish Subgroup line km). The OS88 and OS90 surveys are improving our understanding of the tectonic being reprocessed in order to better image the history of the Otway Basin and its • Top Eumeralla Formation Otway Group in the Torquay Sub-basin. The hydrocarbon potential. One of our primary VM96 survey consists of six offshore lines objectives this year is to produce a series of • Top Sherbrook Group, and located between the southern end of the regional potential field maps covering the Otway Ranges and King Island. These lines Victorian part of the Otway Basin and • Base Nirranda Group straddle the Sorell Fault Zone; a poorly Torquay Sub-basin. Data recently acquired by understood part of the Otway Basin which MPV include onshore aeromagnetics (Fig. 1) The TWT maps are being compiled from could have significant hydrocarbon potential. and Bouguer gravity (Fig. 2). These data are sources including in-house studies by PDU now available to the petroleum industry and personnel, open-file company reports, and Other Otway Basin data sets soon available have significantly increased our previously published NGMA grids. The maps include a comprehensive formation-tops understanding of the basin; in particular, the will be available in hard-copy format, and spreadsheet and a geochem spreadsheet way in which the Late Jurassic-Early later this year we will start integrating the containing open-file vitrinite reflectance, Cretaceous structure of the basin is seismic data with the magnetic and gravity Rock-Eval and porosity / permeability data. influenced by the orientation of pre-existing data. The PDU is also working on a new CD-ROM Palaeozoic basement faults. package containing PDF files of published The PDU is also near completing the papers on the Otway Basin from the APPEA Other products available soon include TWT reprocessing of approximately 1000 line km Journal, PESA Journal, and Exploration maps for the Otway Basin and Torquay Sub- of selected seismic lines from the offshore Geophysics, as well as published VIMP basin. Mapped horizons include: Torquay Sub-basin (OS88 and OS90 surveys), reports issued by MPV.

Fig. 1. Total magnetic intensity image of the Victorian part of the Otway Basin Fig. 2. Image of First Vertical derivative of Bouguer gravity of the Victorian showing the mapped northern limit of the Otway Group (green line) and the part of the Otway Basin showing the mapped northern limit of the Otway location of major basement faults (yellow lines). HF = Hummocks Fault, YF = Group and the location of major basement faults. Yarramyljup Fault, MF = Moyston Fault, SBF = Sorell / Bambra Fault. Gasfields shown in red.

PESA News April/May 2000 11 PETROLEUM RESOURCES & PRODUCTION - 1999 VICTORIAN SUPPLEMENT

PETROLEUM RESOURCES AND PRODUCTION IN VICTORIA, 1999 BY DR KOUROSH MEHIN, A/MANAGER PETROLEUM RESOURCES

Kourosh Mehin

Production Overview Remaining Oil and Gas Reserves Oil Production Gippsland Basin Victoria's production of crude oil and condensate mainly from offshore Gippsland By the end of June 1999, Basin, has been in decline since the mid-1980s. some 3508 million barrels The rate of production from new discoveries of liquid hydrocarbons were and from additional workover and infill drilling produced from the could not compensate for the production Gippsland Basin. The decline in the major fields. remaining recoverable reserves from developed Crude production increased during the 1996- fields in the basin are 97 as the Bream B, Moonfish and West Tuna estimated to be 567 million Fig. 1 fields development were completed and barrels. production rate reached around 240 kb/d during 1997 (Fig.1). The recoverable gas reserves in the developed offshore Unfortunately, this production rate was not Gippsland fields were sustained, as a result of disruption by a tragic depleted from the initial series of explosions at the Longford oil and gas- 9.8 trillion cubic feet (Tcf) to processing plant which occurred on the 25th 5.0 Tcf. Gas in-place in the September 1998. Oil production resumed in undeveloped fields in the December 1998 and the rate reached 190 kb/d offshore Gippsland Basin and continued to increase to reach 220 kb/d owned by Esso/BHPP and during 1999. other operating companies is estimated to be 3.4 Tcf. Production during 1998-99 from the developed Bream B, Moonfish and West Tuna Otway Basin fields and the completion of phase-1 of Blackback Field now accounts for nearly one Onshore third of Gippsland crude oil production. Fig. 2 Continued drilling of infill wells; field Gas is produced from the development and upgrading of production North Paaratte, Iona, Mylor, facilities, as well as workover operations over Fenton Creek and Wallaby Creek fields in the Port Exploration and Appraisal Drilling other major producing fields has also assisted Campbell region. As of 30th June 1999, continued in reversing the decline in production. production from these fields resulted in the During 1998-99, exploration and appraisal reduction of the recoverable reserves from the drilling activity in the offshore Gippsland Gas Production initial 40.0 Bcf to 23.8 Bcf. The initial recoverable region were low. In the onshore Gippsland carbon dioxide from the Boggy Creek field is Basin area, Lakes Oil NL drilled two The increase in the gas production is generally estimated to be 13.99 Bcf. Cumulative CO2 exploration wells: Baudin-1 (in PEP-135) and linked to the demand level and this trend is production from this field, to date, stands at Investigator-1 (in PEP-136); both wells failed to projected to increase with time as shown in 1496.3 Mscf with 12.5 Bcf remaining as reserves. discover commercial hydrocarbons. Figure 1. Other factors affecting the production rate during 1998-99 were the Longford Offshore The historical record of petroleum production incident and the seasonal demand for gas. The (oil, condensate and gas) from producing fields winter gas production demand reached 1050 The gas in place in the undeveloped Otway and development drilling are presented in million standard cubic feet/day (Mscf/d) Basin Minerva and La Bella fields is estimated Figures 3 and 4. compared to an average of around 700 Mscf/d to be 654 Bcf. during winter 1999 (Fig. 2). Continued On Page 13

12 PESA News April/May 2000 PETROLEUM RESOURCES & PRODUCTION - 1999 VICTORIAN SUPPLEMENT

Continued From Page 12

Retention Leases The Retention Leases over the Sole and Mulloway discoveries were renewed for a further period of five years, with a work program directed towards determining feasibility of production early in the term of these licences. The applications for renewal of Retention Leases over the Basker/Manta and Gummy fields are still under consideration.

The Minerva gasfield in the Otway Basin (offshore Port Campbell area) is being considered for development as feedstock for a fertiliser plant at . The gas reserve in La Bella field is currently considered to be subcommercial and does not warrant an immediate development. The field will thus remain as a Retention Lease for the time being. Fig. 3. Petroleum Production Bass Strait Fig. 4. Development Wells - Victoria (1984/85 - (1984/85-1998/99). 1998/99).

OPPORTUNITY GENERATION IN MATURE FIELDS - BASS STRAIT

Esso/BHPP continue to find opportunities to Additional drilling programs have been a increase the reserves and rate from the mature focus area since 1990, with over 100 wells oilfields in the Gippsland Basin, most of having been drilled in the mature Gippsland which are in excess of 85% depleted. oilfields. Post-drilling results and advances in Opportunities generated include reservoir geoscience, reservoir and drilling technology management, additional drilling, workovers have already supported second campaigns of and debottlenecking work such as gas and additional drilling on several platforms. As water handling facility upgrades. These the remaining targets grow smaller, more cost programs provide production buildup of over effective drilling programs are required. In 25 kbd each year. 'Most appropriate' 1998, a tubing pull workover unit was technologies are applied. upgraded to provide drilling capability. This provides significant flexibility and reduces The Bass Strait reservoirs are generally multi- mobilisation costs, allowing smaller drilling darcy sands with a strong water drive. Many programs to become economic. The success of the fields have multiple sands. Bream and of the operations to date have been the major reservoir in West Tuna/Tuna have outstanding, with no Lost Time Injuries or thin oil columns with large gas caps. reportable environmental spills recorded, and Reservoir management strategies include significant improvement in well reach and programs such as intermittent production efficiencies over time. The rig has from high water cut or high GOR wells that successfully completed a three well, third allow water and gas cones to heal during round of drilling at Kingfish B and an eight shut-in periods. Favourable oil and reservoir well program at Halibut. Additional properties allow some significant results to be programs of three to five wells are being achieved, improving the efficiency of the assessed. operation and extending the producing life of Tuna Platform the wells. Gas injection strategies reflect Well completion planning includes an optimising closure of both of gas and water assessment of lifetime recompletion require- contacts, as well as enhancing recovery ments for tubing size, packer settings and gas alternatives such as electric submersible resulting from the stripping of light ends from lift design. This provides the minimum future pumps or downhole water separation are residual oil as a result of high GOR workover cost/opportunity to access minor under consideration. production. Production from the 12 m West recompletion potentials. Industry tech- Tuna/Tuna oil column has exceeded 40% of nological advances are being utilised, with Continuing to 'look for oil where you already the OOIP, with a number of the wells just seven new completion and workover have oil' has been proven and will continue beginning to show a significant watercut or techniques trialed in 1999 and 2000. While to provide additional opportunities for the GOR. gas lift provides effective artificial lift, Bass Strait.

PESA News April/May 2000 13 PETROLEUM INFORMATION VICTORIAN SUPPLEMENT

PETROLEUM INFORMATION GROUP UPDATE BY BOB HARMS, MANAGER INFORMATION SERVICES

Information Group has made a conscious ROM and exabyte. Datasets currently effort to try and recover lost enclosures, and available include: reassemble reports from jumbled or loose originals. Although this is extremely time- • Victorian Petroleum GIS CD-ROM ($30) consuming, it is essential, especially for older wells where the original paper copies are in • Victorian Biostratigraphy Reports Scanned poor condition or not stored in a logical Images Package ($100) order. • Offshore Otway Scanned Well Once catalogued, the WCRs are scanned in Completion Reports Package ($100) black and white TIF format, and if colour figures are present, in colour TIF/JPEG format. • Offshore Otway LIS/LAS/DLIS Well Logs The files are then quality checked and, where Exabyte Tape ($100) possible, converted to user-friendly PDF (Acrobat) file format. Once converted, the And in the future, the Petroleum Information Bob Harms Group will try to bookmark the chapters and Group plans to issue several more packages hyperlink the separate files. Each file is then comprising scanned geochemistry reports and identified by its original hardcopy unique published VIMP reports. Cataloguing barcode filename, and can be linked and viewed either through the standard file- Web Site The most useful way the Petroleum system explorer, or through the digital file Development Unit (PDU) can enhance the viewing capabilities of GIS systems such as The MPV web site provides some basic value of petroleum data in its custody is to MPV's-dbMap assets management database information on contact details and acreage manage it efficiently. A key part of this system. release information. The site can be viewed process requires defining the nature of these at http://www.nre.vic.gov.au/minpet/pet.htm assets by cataloguing. However, existing data Although this process is slow, over 300 WCRs catalogues consist of non-computerised have now been scanned. Individual WCRs For more information on this project, please manual card indexes, which do not have the can now be ordered from the Petroleum contact: rich functionality of modern computer-based Information Group at a cost of $100 per well, cataloguing. with selected pre-made CD-ROM packages [email protected] (e.g. offshore Otway WCRs) available at a Ph 03 9412 5015 To bridge this functionality gap, a cost of $100 per set. In the future, the dbMap/Oracle Metadata Assets Catalogue Petroleum Information Group intends to put [email protected] was developed by Petrosys Pty Ltd for MPV. all the scanned WCRs on high-density media Ph 03 9412 5015 Over the past three years, the Petroleum (e.g. DVD), so the cost per-well can be Information Group of PDU has been drastically reduced even further. [email protected] barcoding and cataloguing DNRE's data Ph 03 9412 5074 assets (e.g. tapes, reports, sepias, maps, well dbMap Titles Database logs, etc…), and entering these data into To order WCRs and other data, please dbMap. One of the first datasets the Group The Titles component of dbMap/Oracle contact: tackled is the PDU well completion report database is currently under development by (WCRs) collection. In addition to normal Petrosys Pty Ltd. The development of this [email protected] library-type barcoding and cataloguing of the module, together with the assets Ph 03 9412 5169 WCRs, PDU has also carried out additional management, seismic and well data modules, barcoding so that the reports can be will allow the user to display and manage the [email protected] specifically scanned and stored as digital appropriate acreage blocks. In addition, it Ph 03 9412 5085 image files. will allow the user to plan, schedule and monitor work programme activities and The Geological Survey of Victoria is offering Well Completion Report Scanning associated events, such as seismic or well free gravity, aeromagnetic and other minerals- activities. It also matches and links assets exploration oriented digital datasets on CD- One of the most commonly requested items such as seismic tapes, or well completion ROM contact: from PDU is WCRs. In the past, the WCRs reports and logs, to these work programme were sent outside for photocopying; a time- activities, and also calculates the release David Bibby consuming and expensive process. To status of data or assets according to the Ph 03 9412 5017 overcome this problem, the PDU is now legislative confidentiality rules built into the scanning the reports and putting them on CD- database. Roger Buckley ROM, which will allow the data to be more Ph 03 9412 5052 efficiently, and more quickly, distributed. In Data Packages addition, by scanning the WCRs, the reports cannot be lost or damaged in the future. Over The PDU is continuously adding to, and the past several years, the Petroleum updating, its pre-made data packages on CD-

14 PESA News April/May 2000 MPV REPORT LISTINGSTITLE VICTORIAN SUPPLEMENT

Previous Releases GSV Report 103 The stratigraphy, structure, geophysics and hydrocarbon potential of the Eastern Otway Basin, Victoria Geological Survey of Victoria 1995 ...... $200 VIMP Report 15 The stratigraphy and structure of the Tyrendarra Embayment, Otway Basin, Victoria Ryan, S.M., Knight, L.A., & Parker, G.J. 1995...... $60 VIMP Report 16 A preliminary appraisal of the pre-Tertiary infrabasins beneath the Murray Basin, northwestern Victoria Knight, L.A., McDonald, P.A., Frankel, E. & Moore, D.H. 1995 ...... $50 VIMP Report 17 Seismic interpretation of the onshore western Otway Basin, Victoria Perincek, D., Simons, B., Pettifer., G.R., & Gunatillake, K. 1995 ...... $100 VIMP Report 18 The structure, stratigraphy and petroleum potential of the Portland Trough, Otway Basin, Victoria Lavin, C.J., & Naim, H. 1995 ...... $80 VIMP Report 21 Seismic interpretation of the offshore Otway Basin, Victoria Sarma, S. 1995 ...... $100 VIMP Report 22 Early Cretaceous source rocks of the Victorian onshore Otway Basin Mehin, K. & Link, A.G. 1995 ...... $60 VIMP Report 23 Early Cretaceous stratigraphy along the northern margin of the Otway Basin Parker, G.J. 1995...... $60 VIMP Report 30 Hydrocarbon play fairways of the onshore Gippsland Basin, Victoria Chiupka, J.W. 1996 ...... $50 VIMP Report 31 Early Cretaceous source rock evaluation for oil and gas exploration, Victorian Otway Basin Mehin, K. & Link, A.G. 1996 ...... $60 VIMP Report 41 The petroleum prospectivity of the Casterton Petroleum System in the Victorian onshore Otway Basin Lavin, C.J. & Muscatello, T. 1997...... $50 VIMP Report 42 Hydrocarbon plays and play fairways of four vacant offshore Gippsland Basin areas Chiupka, J.W., Megallaa, M., Jonasson, K.E., & Frankel, E. 1997...... $150 VIMP Report 43 Late Cretaceous source rocks offshore Otway Basin, Victoria and South Australia Mehin, K. & Link, A.G. 1997 ...... $75 VIMP Report 53 The Casterton Formation-Otway Basin, Victoria Lavin, C.J. & Muscatello, T. 1998...... $75 VIMP Report 54 Cretaceous source rocks onshore Gippsland Basin, Victoria Mehin, K. & Bock M.P. 1998 ...... $75 VIMP Report 55 Hydrocarbon prospectivity of the offshore eastern Otway Basin, Victoria, for the 1998 Acreage Release Geary, G.C. & Reid, I.S.A. 1998 ...... $150 VIMP Report 56 Hydrocarbon prospectivity of the Northern Terrace, Offshore Gippsland Basin, for the 1998 Acreage Release Megallaa, M., Bernecker, T. & Frankel, E. 1998 ...... $100 VIMP Report 57 Geology and prospectivity of the western Victorian Voluta Trough, Otway Basin, for the 1998 Acreage Release Lavin, C.J. 1998 ...... $150 VIMP Report 60 Hydrocarbon prospectivity of the offshore Torquay Sub-basin, Victoria; Gazettal Area V99-1 Messent, B.E., Collins, G.I. & West, B.G. 1999 ...... $250 VIMP Report 61 Petroleum systems, play fairways and prospectivity of the offshore southern Gippsland Basin, Victoria; Gazettal Area V99-2 Smith, M. 1999 ...... $250 VIMP Report 62 Hydrocarbon potential of the western onshore Otway Basin in Victoria; 1999 Acreage Release. Mehin, K. & Constantine, A.C. 1999 ...... $250

New Releases VIMP Report 65 (in prep.) Petroleum prospectivity of the deep-water Gazettal Areas V00-3 and V00-4, southeastern Gippsland Basin, Victoria, Australia. Smith, M.A., Bernecker, T., Liberman, N., Moore, D. H. & Wong, D. 2000 ...... $TBA VIMP Report 66 (in prep) Hydrocarbon prospectivity of V00-1 and V00-2, Late Cretaceous Voluta Trough, offshore Otway Basin: Constantine, A.C. 2000...... $TBA OIL AND GAS RESOURCES OF VICTORIA. Minerals and Petroleum Victoria, Petroleum Development Unit: Malek, R. & Mehin, K. 1999 ...... $150

Digital Data Packages Victorian Petroleum GIS Data CD Package (1999 Version) ...... $30 Victorian Biostratigraphic Reports CD Package ...... $100 Victorian Offshore Otway Well Completion Reports CD Package ...... $100 Petroleum Reports & Publications CD Includes Oil & Gas Resources of Victoria and non-current VIMP Reports...... $100

PESA News April/May 2000 15 LIST OF TENEMENTS VICTORIAN SUPPLEMENT

PRODUCTION FIELD(S) TENEMENT HOLDER EXPIRY DATE LICENSES

VIC/L1, L2, L3, L4 Barracouta and Marlin Esso ✷ / BHPP 24/08/2009 VIC/L5, L6, L7, L8 Halibut and Kingfish Esso ✷ / BHPP 19/09/2010 VIC/L9 Tuna Esso ✷ / BHPP 12/07/2016 VIC/L10, L11 Snapper and Flounder Esso ✷ / BHPP 28/05/2018 VIC/L13, L14 Bream Esso ✷ / BHPP 15/12/2006 VIC/L15, L16, L17, L18 Dolphin, Perch and Seahorse Esso ✷ / BHPP 13/06/2010 VIC/L19 West Fortescue Esso ✷ / BHPP 12/07/2016 VIC/L20 Blackback Esso ✷ / BHPP 01/01/2019

EXPLORATION BASIN TENEMENT HOLDER EXPIRY DATE PERMITS

VIC/P19 Gippsland Petroz ✷ / Shell / Crusader / News Corp / Aust Worldwide Exploration Pending Renewal VIC/P34 Gippsland BHPP ✷ 26/01/2001 VIC/P35 Otway OCA ✷ 26/07/2002 VIC/P36 Gippsland Amity ✷ / Latrobe Oil & Gas / Pan Pacific Petroleum 26/07/2001 VIC/P38 Gippsland Amity ✷ / Latrobe Oil & Gas 30/07/2003 VIC/P39 Gippsland Mosaic ✷ / Indo Pacific Energy / Euro Pacific Energy 30/07/2003 VIC/P40 Gippsland Amity ✷ /Latrobe Oil & Gas / Pan Pacific Petroleum / Tri-C Resources 13/05/2004 VIC/P41 Gippsland Eagle Bay ✷ 13/05/2004 VIC/P42 Gippsland Bass Strait ✷ 13/05/2004 VIC/P43 Otway Boral ✷ / Woodside / CalEnergy (UK) 10/08/2005 VIC/P44 Otway Strike Oil ✷ 10/08/2005 VIC/P11 (V) Gippsland Basin Oil (Cultus) ✷ 04/09/2001

RETENTION FIELD TENEMENT HOLDER EXPIRY DATE LEASES

VIC/RL1 Mulloway Esso ✷ / BHPP Pending Renewal VIC/RL2 Kipper Esso ✷ / Shell / Crusader / Petroz / BHPP 14/12/2003 VIC/RL3 Sole Shell ✷ / Mobil / Santos Pending Renewal VIC/RL4 Sunfish Esso ✷ / BHPP 27/08/2000 VIC/RL5 Patricia / Baleen Basin Oil (Cultus) ✷ 13/11/2001 VIC/RL7 La Bella BHPP ✷ / Santos 27/02/2003 VIC/RL8 Minerva BHPP ✷ / Santos 29/11/2002 VIC/RL1 (V) Golden Beach Bridge ✷ / Basin Oil 24/07/2002 LOCATION Basker / Manta Shell ✷ / Petroz Pending Renewal ONSHORE TITLES

PRODUCTION BASIN TENEMENT HOLDER EXPIRY DATE LEASES

PPL 1 Otway Boral ✷ 01/03/2000 PPL 2 Otway Western Underground Gas Storage ✷ 30/12/2005 PPL 3 Otway Boggy Creek ✷ 09/05/2008 PPL 4 Otway Santos 06/04/2014

EXPLORATION BASIN TENEMENT HOLDER EXPIRY DATE PERMIT

PEP 101 Otway Boral ✷ / Newfield Expl. Aust. 12/11/2000 PEP 108 Otway Santos ✷ 28/02/2000 PEP 111 Otway Boral ✷ / Pan Pacific / Lakes Oil / Newfield Expl. Aust. 03/02/2000 PEP 119 Otway TMOC Exploration ✷ / Boral 13/11/2000 PEP 131 Gippsland Bass Petroleum ✷ 21/05/2000 PEP 132 Otway Santos ✷ / Beach 31/03/2000 PEP 133 Otway Boral ✷ 26/04/2000 PEP 135 Gippsland Petrotech ✷ / Westco Mining 28/08/2000 PEP 136 Gippsland Lakes Oil ✷ / Westco Mining 16/06/2000 PEP 137 Gippsland Petrotech ✷ 16/03/2000 PEP 138 Gippsland Petrotech ✷ 16/06/1999

✷ OPERATOR

16 PESA News April/May 2000 TENEMENTS AND PIPELINES MAP VICTORIAN SUPPLEMENT