ECONOMIC ADVANTAGES OF USING EXPLORATION 3D SEISMIC ON THE NORTH WEST SHELF

1996 ◽  
Vol 36 (1) ◽  
pp. 385
Author(s):  
O.A. Larsen ◽  
J. Winterhalder ◽  
J.S. Boardman ◽  
J.N.G. Smith
Keyword(s):  
Net Present Value ◽  
Comprehensive Evaluation ◽  
High Capacity ◽  
Development Program ◽  
Cost Effective ◽  
Oil Field ◽  
3D Seismic ◽  
North West ◽  
Oil Companies ◽  
The North

The development of high capacity seismic 3D vessels has been so rapid that the oil industry has yet to optimise its investment in seismic data. However, the oil companies are becoming increasingly aware of the financial benefits of multi-client surveys which maximise vessel efficiency and provide a comprehensive evaluation of large areas.Many oil companies continue to design exploration seismic programs based on 2D seismic and acquire 3D seismic surveys after drilling the exploration/discovery well and generally after at least one appraisal well. Such single client surveys are limited by expected field outlines, which results in high unit costs for the seismic and missed opportunities beyond these outlines.The immediate benefits identified from obtaining early 3D data include: a higher success rate, optimisation of well locations, more rapid and cost effective appraisal, earlier screening studies, and an advanced development program. The combination of these factors can accelerate production by up to 18 months.For the scenarios evaluated in this paper, the use of 3D seismic early in the exploration period translates into an increase in Net Present Value of A$18-33 million and Expected Monetary Value of A$50-58 million for a 50 MMBBL oil field.

DEMETER HIGH RESOLUTION 3D SEISMIC SURVEY—REVITALISED DEVELOPMENT AND EXPLORATION ON THE NORTH WEST SHELF, AUSTRALIA

2006 ◽  
Vol 46 (1) ◽  
pp. 101 ◽  
Author(s):  
K.J. Bennett ◽  
M.R. Bussell
Keyword(s):  
High Resolution ◽  
Seismic Data ◽  
New Technologies ◽  
Seismic Survey ◽  
Future Application ◽  
3D Seismic ◽  
Gas Field ◽  
North West ◽  
The North ◽  
Exploration And Development

The newly acquired 3,590 km2 Demeter 3D high resolution seismic survey covers most of the North West Shelf Venture (NWSV) area; a prolific hydrocarbon province with ultimate recoverable reserves of greater than 30 Tcf gas and 1.5 billion bbls of oil and natural gas liquids. The exploration and development of this area has evolved in parallel with the advent of new technologies, maturing into the present phase of revitalised development and exploration based on the Demeter 3D.The NWSV is entering a period of growing gas market demand and infrastructure expansion, combined with a more diverse and mature supply portfolio of offshore fields. A sequence of satellite fields will require optimised development over the next 5–10 years, with a large number of wells to be drilled.The NWSV area is acknowledged to be a complex seismic environment that, until recently, was imaged by a patchwork of eight vintage (1981–98) 3D seismic surveys, each acquired with different parameters. With most of the clearly defined structural highs drilled, exploration success in recent years has been modest. This is due primarily to severe seismic multiple contamination masking the more subtle and deeper exploration prospects. The poor quality and low resolution of vintage seismic data has also impeded reservoir characterisation and sub-surface modelling. These sub-surface uncertainties, together with the large planned expenditure associated with forthcoming development, justified the need for the Demeter leading edge 3D seismic acquisition and processing techniques to underpin field development planning and reserves evaluations.The objective of the Demeter 3D survey was to re-image the NWSV area with a single acquisition and processing sequence to reduce multiple contamination and improve imaging of intra-reservoir architecture. Single source (133 nominal fold), shallow solid streamer acquisition combined with five stages of demultiple and detailed velocity analysis are considered key components of Demeter.The final Demeter volumes were delivered early 2005 and already some benefits of the higher resolution data have been realised, exemplified in the following:Successful drilling of development wells on the Wanaea, Lambert and Hermes oil fields and identification of further opportunities on Wanaea-Cossack and Lambert- Hermes;Dramatic improvements in seismic data quality observed at the giant Perseus gas field helping define seven development well locations;Considerably improved definition of fluvial channel architecture in the south of the Goodwyn gas field allowing for improved well placement and understanding of reservoir distribution;Identification of new exploration prospects and reevaluation of the existing prospect portfolio. Although the Demeter data set has given significant bandwidth needed for this revitalised phase of exploration and development, there remain areas that still suffer from poor seismic imaging, providing challenges for the future application of new technologies.

DRIVERS FOR THE DEVELOPMENT OF AN INTEGRATED SUPPLY BASE AND OFFSHORE SUPPLY CHAIN, NORTH WEST SHELF, AUSTRALIA

2004 ◽  
Vol 44 (1) ◽  
pp. 593
Author(s):  
E.D. Graham
Keyword(s):  
Supply Chain ◽  
Critical Mass ◽  
Cost Effective ◽  
Integrated Services ◽  
Economic Benefits ◽  
Security Issue ◽  
North West ◽  
The North ◽  
User Facility ◽  
Integrated Service

Since the commencement of the major developments on the North West Shelf, the offshore resource industry, during both its construction and operational phases, has faced considerable logistical impediments to cost-effective solutions for the offshore supply chain. These impediments have included distance, scant resources, lack of infrastructure both on and offshore and lack of critical mass.Throughout the world, offshore projects have greatly benefitted from the availability of integrated services to cater for the transport of equipment from the point of manufacture or distribution to the offshore location.Within the Australian context the privately controlled Esso Barry Beach and Dampier Woodside facilities are examples of integrated services, but both differ considerably from a public multi-user facility. The model used in the Timor Sea of one vessel or vessels for the use of several operators is another example.The NorthWest Shelf has now reached the critical mass and it became apparent several years ago that the area needed an integrated supply base available to multiple operators. It would need to include a heavy loadout wharf, laydown areas, slipway and engineering facilities and office space to service forthcoming projects, as well as planning and cooperation amongst all players to maximise efficiency and use of scant resources as drivers for economic benefits to offshore operators in the region.Furthermore the fallout from the events of 11 September 2001 and continuing threats of terrorism has meant the security of marine assets has become an important part of each operator’s everyday life. The introduction of new legislation relating to this security issue is planned for mid 2004.In 2000 and 2001 Mermaid Marine Australia Limited undertook a major expansion of its Dampier supply base, and established a world-class facility to meet the growing demands of the region.This complex has for the first time provided the northwest of Australia, particularly the North West Shelf, Carnarvon Basin and the onshore developments on the Burrup Peninsula, with a facility for offloading and loadout of heavy shipments and fabrication and slipway facilities, coupled with the advantages of a large supply base. This facility can also be expanded to meet growth and the emerging requirements related to security.This paper describes the drivers for change commencing with the earliest supply chains and following through to the integrated service now availabe. These drivers meet the requirements of the offshore operators in the region as well as showing the benefits anticipated from this integrated service. The paper also outlines in detail the requirements of the International Maritime Organisation for worldwide changes to port and offshore security.

Prospectivity insights from automated pre-interpretation processing of open-file 3D seismic data: characterising the Late Triassic Mungaroo Formation of the Carnarvon Basin, North West Shelf of Australia

2015 ◽  
Vol 55 (1) ◽  
pp. 15 ◽  
Author(s):  
Cliff C. Ford ◽  
James K. Dirstein ◽  
Alistair John Stanley
Keyword(s):  
Spatial Databases ◽  
Late Triassic ◽  
Data Sets ◽  
3D Seismic ◽  
Gas Reservoirs ◽  
Waveform Data ◽  
Open File ◽  
North West ◽  
The North ◽  
Carnarvon Basin

Waveform data from pre-interpretation processing is used in nine Late Triassic interpretation case studies from an area extending more than 30,000 km2 across the Exmouth Plateau, Kangaroo Trough and Rankin Trend on the North West Shelf of Australia. Events selected from a database of automatically generated surfaces extracted from six large open-file 3D marine surveys (~16,000 km2) are used to analyse reservoirs, seals, and pore fluid within the Brigadier and Mungaroo formations in this peer-reviewed paper. Today, geoscience teams are challenged with vast data sets such as the archived versions of more than 125 Carnarvon Basin 3D seismic surveys. Pre-interpretation processing delivers a database of numerous seismic events that cannot be effectively managed using traditional interpretation workstations. With, however, a 3D viewer to query, edit and merge the results, geoscience teams are able to review many large surveys and the surfaces in their interpretation workflows. At the 2013 WABS Conference in Perth, WA, two papers offered models for the Late Triassic gas reservoirs. These models represent many years of synthesis and integration of data by teams of geoscientists from two of the major operators on the North West Shelf. Validation and corroboration of the proposed models was gained by using selected pre-interpretation surfaces. Stacking patterns, waveform fitness, amplitude and two-way time surfaces from these spatial databases revealed geological insights about the formations, such as their complexity of structure, extent of reservoirs, and continuity of seals, along with a better understanding about the trapping and charge systems of the fields.

IMPACT OF 3D SEISMIC ON EXPLORATION AND DRILLING SUCCESS IN THE DAMPIER SUB-BASIN, WA

1999 ◽  
Vol 39 (1) ◽  
pp. 87
Author(s):  
D.R. Kingsley ◽  
L.A. Tilbury
Keyword(s):  
Success Rate ◽  
3D Seismic ◽  
3D Technology ◽  
Spatial Continuity ◽  
North West ◽  
Associated Production ◽  
The North ◽  
3D Data ◽  
Stratigraphic Reservoir ◽  
Structural Definition

Application of 3D technology and the strategy of acquiring 'wall-to-wall' 3D data over WA-28-P and the associated production licences has had a major impact on the exploration and appraisal success of the North West Shelf Venture.The different aspects of 3D technology have contributed to this success to varying degrees according to the geological setting of the prospects and fields. In general, all have benefited from improved structural definition, better stratigraphic/reservoir definition, improved depth conversion and the spatial continuity of data inherent in 3D datasets.Noteable discoveries attributable to 3D technology include North Rankin West (NRA–22), Perseus–1 (and appraisals Perseus–2, –3A, Perseus South–1), Capella–1, Sculptor–1, Hermes (Lambert–2), Keast–1, Dockrell–2, and appraisal wells Yodel–2, Egret–2 and Lambert–4. Despite this outstanding success, several noteable dry wells, including West Dixon–1 (Triassic), Spica–1, Malmsey–1 and Wanaea–5 (appraisal), have been drilled.The continuing application of 3D technology, although in an increasingly mature area where more subtle and higher risk traps will be the norm, is expected to maintain a high success rate for the North West Shelf Venture.

Population Fluctuations and Reproduction of Rabbits in a Pastoral Area on the Coast North of Carnarvon, W. A.

1983 ◽  
Vol 10 (1) ◽  
pp. 97 ◽  
Author(s):  
DR King ◽  
SH Wheeler ◽  
GL Schmidt
Keyword(s):  
Breeding Season ◽  
Oryctolagus Cuniculus ◽  
Cost Effective ◽  
Effective Control ◽  
Population Fluctuations ◽  
North West ◽  
The North ◽  
Pastoral Area ◽  
Average Rainfall ◽  
Summer Rain

The population fluctuations and reproductive biology of rabbits, Oryctolagus cuniculus (L.), were studied in a coastal pastoral area in the north-west of Western Australia between 1974 and 1981. Numbers were highest in late 1975-early 1976 and declined during a period of below-average rainfall in 1976-79, but were still found in all landforms. The breeding season was more regular than that of rabbits in other pastoral areas, and appeared to be a response to winter rains which were relatively predictable in timing, if not amount. Successful summer breeding also followed heavy summer rain. There appears to be no opportunity for cost-effective control of rabbits in the area by techniques currently available, as even when numbers are low the rabbits are widespread.

THE TARBAT-IPUNDU OIL FIELD, A CASE STUDY IN IDENTIFYING BYPASSED OIL

1998 ◽  
Vol 38 (1) ◽  
pp. 36
Author(s):  
T.P. Lonergan ◽  
P.G. Ryles ◽  
S.T. McClure ◽  
D.W. McMillan
Keyword(s):  
Multidisciplinary Team ◽  
Development Program ◽  
Oil Field ◽  
Growth Potential ◽  
Total Production ◽  
Field Development ◽  
The North ◽  
Bypassed Oil ◽  
Existing Data ◽  
Eromanga Basin

Since 1995 the Tarbat-Ipundu Field has developed from a marginal 200 BOPD (31.8 kL/d) field with perceived limited growth potential to a developing resource with production up to 3,000 BOPD (476.9 kL/d). This increase was achieved through the efforts of a dedicated multidisciplinary team and an aggressive 'fit for purpose' drilling and evaluation program.The Tarbat-Ipundu Field is located in PL 52 of ATP 299P in southwestern Queensland, approximately 115 km to the northeast of the Jackson Oil Field. The field was discovered by Hartogen Energy Ltd in 1986 with the drilling of Ipundu 1 which came on-line at 100 BOPD (15.9 kL/d) from the Wyandra Sandstone and the Murta Member. The discovery well was followed by the drilling of Tarbat-1 in 1988 on a subculmination to the north. Tarbat-1 encountered oil in the Wyandra Sandstone but watered out after producing 17 KSTB (2,702 kL) of oil. During 1991 a further four wells were drilled in the Ipundu Field by the then operator, Ampolex Pty Ltd. Two of these wells were plugged and abandoned. In January 1994 the field was producing at 220 BOPD (34.9 kL/d) after a total production of 350 KSTB.The Santos Group acquired a majority interest and Operatorship of the Tarbat-Ipundu Field in 1994. An integrated geological and engineering evaluation of Tarbat-1, incorporating experience gained in other parts of the Eromanga Basin, indicated the potential for bypassed oil in the Hutton Sandstone. Similarly, additional potential was recognised in the Wyandra Sandstone and Murta Member in the Tarbat-Ipundu wells. To evaluate this potential Tarbat-2 was drilled in August 1995 at a location 315 m to the northwest of Tarbat-1. Drill stem tests in Tarbat-2 resulted in flows of 2,037 BOPD (323.8 kL/d) from a 26 m gross hydrocarbon column in the Hutton Sandstone and 770 BOPD (122.4 kL/d) from a 14 m gross hydrocarbon column in the Wyandra Sandstone.An aggressive appraisal and development program followed the drilling of Tarbat-2 which has resulted in the drilling of an additional 25 wells. Proved and Probable Oil in Place estimates have increased from 5.2 MMSTB (0.826 ML) in 1994 to 44.2 MMSTB (7.02 ML) in 1997. As at June 1997 the field produces oil from the WyandraSandstone, Murta Member and Hutton Sandstone of the Eromanga Basin. A combined oil offtake of up to 3,000 BOPD (476.9 kL/d) has been achieved from the field. Continued field development is planned for 1998.The successful 're-discovery' of the Tarbat-Ipundu Field illustrates the potential benefit of a systematic review and integration of all existing data via a multidisciplinary team. The increasing cost of new data acquisition makes it imperative that the existing data is thoroughly evaluated prior to the investment of further exploration capital. The Tarbat-Ipundu Field demonstrates the potential to add significant new reserves from focussed targeting and evaluation of potential bypassed hydrocarbon accumulations.

PREPARATION AND IMPLEMENTATION OF A SAFETY MANAGEMENT SYSTEM IN BHPP

1997 ◽  
Vol 37 (1) ◽  
pp. 657
Author(s):  
P.C. Hunter
Keyword(s):  
Management System ◽  
Oil And Gas ◽  
Safety Management ◽  
Oil Field ◽  
Safety Performance ◽  
Asia Pacific ◽  
Gas Treatment ◽  
Safety Management System ◽  
North West ◽  
The North

BHP is a leading global resources company which comprises four main business groups: BHP Copper, BHP Minerals, BHP Steel and BHP Petroleum. BHP Petroleum (BHPP) global operations are divided into four Regions and Australia/Asia Region is responsible for exploration, production, field development and joint ventures in the Asia-Pacific region. In Australia, the Company's largest producing assets are its shares of the Gippsland oil and gas fields in Bass Strait and the North West Shelf project in Western Australia.BHPP operates three Floating Production, Storage and Offloading (FPSO) vessels-Jabiru Venture, Challis Venture and Skua Venture-in the Timor Sea and one FPSO, the Griffin Venture, in the Southern Carnarvon Basin. Stabilised oil is offloaded from all four FPSOs by means of a floating hose to a shuttle tanker. Gas from the Griffin Venture is compressed and transferred through a submarine pipeline to an onshore gas treatment plant.BHPP's Asian production comes from the Dai Hung oil field offshore Vietnam where BHPP is the operator and from Kutubu in Papua New Guinea.In Melbourne, BHPP operates a Methanol Research Plant and produced Australia's first commercial quantities of methanol in October 1994.BHPP is an extremely active offshore oil and gas explorer and has interests in a number of permits and blocks in the Australian-Indonesian Zone of Co-operation.This paper discusses BHPP's approach to safety management, both for its worldwide operations and specifically in Australia/Asia Region. It explains how BHPP's worldwide safety management model takes regional regulatory variations into account. It shows, specifically, how this has been done in Australia/Asia Region using what BHPP considers to be a best practice approach.The paper describes how BHPP Australia/Asia Region benchmarked its performance against other operators in Australia and the North Sea. It explains how the findings of the benchmarking study were used to plan the preparation of a safety management system (SMS). The structure of the SMS is described along with the legal requirements in Australia.The paper concludes that implementation of the SMS is progressing according to plan and points out that safety cases for the FPSOs have been submitted to the Regulators. Implementation of the SMS and the drive for world class safety standards is having a substantial effect and safety performance is improving. One measure of safety performance, the Lost Time Injury Frequency Rate (LTIFR) is down from around 15 at the end of 1994 to under 3 in December 1996.

scholarly journals Development of an imperialist competitive algorithm (ICA)-based committee machine to predict bit penetration rate in oil wells of Iran

2015 ◽  
Vol 37 ◽  
pp. 173 ◽  
Author(s):  
Ayub Abbasi Garavand ◽  
Gholamreza Esmaeilian
Keyword(s):  
Oil And Gas ◽  
Real Data ◽  
Cost Effective ◽  
Imperialist Competitive Algorithm ◽  
Oil Field ◽  
Engineering Project ◽  
Committee Machine ◽  
Oil Companies ◽  
Competitive Algorithm ◽  
Intelligent Models

Drilling operation of a well is one the most expensive and time consuming procedures of oil and gas exploitation. Oil companies are always seeking for safe and cost-effective techniques for drilling. The main goal and motivation of drilling optimization is achieving the highest efficiency of work. Optimization and minimization of operational costs is one of the most important prerequisites of any engineering project. Rate of penetration is a crucial factor n drilling controlling cost and time of drilling. In the current research, capabilities of single independent intelligent models are employed for developing a hybrid committee machine that can predict bit penetration bit with high accuracy. To get this goal, three single intelligent models, including neural network, fuzzy logic and neuro-fuzzy, are trained. In the second step, the outputs of these models are integrated by imperialist competitive algorithm (ICA). Finally, a linear equation is achieved which gets outputs of single models as inputs and integrate them somehow the final results is closer to the actual value. The developed ICA-based committee machine is tested by 145 real data points gathered from the drilled wells in an oil field. Correlation of actual and predicted value of ROP obtained from committee machine shows that the model predicts ROP with accuracy of 88 percent. Such model can be used for optimization of drilling parameters in future drilling operations.

AUSTRALIAN MEGASURVEYS—THE KEY TO NEW DISCOVERIES IN MATURING AREAS?

2005 ◽  
Vol 45 (1) ◽  
pp. 407 ◽  
Author(s):  
H. Edwards ◽  
J. Crosby ◽  
N. David ◽  
C. Loader ◽  
S. Westlake
Keyword(s):  
Data Sets ◽  
Well Control ◽  
North West ◽  
Oil Companies ◽  
The North ◽  
3D Data ◽  
Detailed Search ◽  
Time Critical ◽  
Small Finds ◽  
2D And 3D

In a maturing province such as the North West Shelf, it is time-critical to find remaining hydrocarbon resources as well as to develop small finds before existing big field installations and their associated infrastructure are decommissioned. Finding the remaining smaller fields with subtle geophysical expression is a challenge, and a thorough understanding of the petroleum geology is essential. To achieve this, the subsurface structure and depositional systems must be understood in a regional as well as a local context.To date, exploration companies’ regional models have been based on a mixture of 2D and 3D seismic of varying vintages, orientations, and quality. Consequently they have been incomplete and lacking detail. To address this problem, PGS initiated the MegaSurvey Project, merging a number of 3D surveys into large, consistent 3D data sets. For the first time, the regional picture and prospect-size detail are both available from a single dataset.Two MegaSurveys for the North West Shelf are now available; the Vulcan Sub-Basin MegaSurvey (VMS) and the Carnarvon MegaSurvey (CMS).The MegaSurvey seismic data and consistent horizon interpretation (tied to released well control) enables asset- focussed oil companies to concentrate on the more detailed search-for-the-subtle-trap to find, understand, and develop remaining reserves. Interpretation of the first MegaSurvey (Vulcan Sub-Basin) was completed in 2004 and work is focussed on the Carnarvon MegaSurvey, the interpretation of which will be completed in March 2005.The PGS 3D MegaSurveys allow visualisation of the subsurface both on a scale and resolution that has hitherto been unavailable. They provide an essential new tool to help fully unlock the remaining potential of the North West Shelf.

Fluorescence application to hydrocarbon monitoring in North West Shelf marine waters

2015 ◽  
Vol 55 (1) ◽  
pp. 345
Author(s):  
Felicity Harrison ◽  
Riley McAuliffe ◽  
Jose Romero ◽  
Keith Stubbs ◽  
Carolyn Oldham
Keyword(s):  
Standard Procedure ◽  
Cost Effective ◽  
Temporal Variations ◽  
Fluorescent Properties ◽  
Marine Waters ◽  
North West ◽  
Hydrocarbon Detection ◽  
Background Fluorescence ◽  
The North ◽  
Effective Manner

The application of fluorometry to hydrocarbon detection in marine waters is a standard procedure in many parts of the world. This technology is advantageous because spatial and temporal variations in hydrocarbon distributions can be acquired readily and rapidly in a cost-effective manner compared to traditional sampling methods. Its application to North West Shelf marine waters has been examined through two recent research studies. In the first study, the fluorescent properties of North West Shelf hydrocarbons were compared to those from North America. In general, peak fluorescence of North West Shelf samples are lower than North American and European hydrocarbons. Hence, fluorometer specifications (e.g. excitation and emission wavelengths) need to be tailored for hydrocarbon detection within North West Shelf waters. The second study measured low background fluorescence of a representative region of the North West Shelf using the fluorometer specifications recommended in the first study. This indicates that background fluorescence is unlikely to affect hydrocarbon detection in the marine waters of the North West Shelf. These studies support the use of fluorometry as a technique to reliably detect and to monitor unplanned (e.g. spills) and planned (e.g. producted formation water) hydrocarbon discharges across the North West Shelf.

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