THE RENEWED SEARCH FOR OIL AND GAS IN THE BASS BASIN: RESULTS OF YOLLA-2 AND WHITE IBIS-I

1999 ◽  
Vol 39 (1) ◽  
pp. 248 ◽  
Author(s):  
R.G. Lennon ◽  
R.J. Suttill ◽  
D.A. Guthrie ◽  
A.R. Waldron
Keyword(s):  
Joint Venture ◽  
Oil And Gas ◽  
Oil Accumulation ◽  
Field Development ◽  
Seismic Control ◽  
White Ibis ◽  
Basement High ◽  
Oil Rim ◽  
Coal Measures ◽  
Exploration Well

Boral Energy Resources Ltd and its Joint Venture partners drilled two weUs in the offshore Bass Basin during 1998. Both wells targetted reservoirs in the Upper Cretaceous to Eocene Eastern View Coal Measures (EVCM).Yolla–2, located in Petroleum Licence T/RL1, appraised sandstones within the EVCM, first established gas bearing in the Yolla structure by the 1985 exploration well Yolla–1, drilled by Amoco. The exploration well White Ibis–1, located in adjacent permit T/18P, was a crestal test on a large basement high updip of the 1967 well Bass-3, drilled by Esso.Both wells of the 1998 drilling program encountered gas columns in the objective Paleocene to Lower Eocene section of the EVCM (Intra-EVCM). Liquids-rich gas was recovered from these reservoirs in wireline tests. Formation pressure data suggest a thin oil rim is developed in White Ibis–1. Neither well was tested in cased hole though White Ibis–1 was suspended for potential re-entry. Yolla–1 also encountered a gas and oil accumulation at the top of the Eastern View Coal Measures, but this level was not an objective in Yolla–2.Based on well results and 3D seismic control, a gas resource of between 450–600 BCF OGIP is currently estimated in the Yolla Field. The gas accumulation encountered in White Ibis–1 is estimated at 85 BCF OGIP.The 1998 drilling campaign has provided encour-agement to the T/RL1 and T/18P Joint Ventures to continue the search for both oil and gas in the Bass Basin. Markets for gas are being pursued in both Tasmania and Victoria and engineering studies are being undertaken in parallel to refine parameters for a potential Yolla Field development. The White Ibis Field may provide a candidate as a satellite to such a development. Depending on the outcomes of these studies, further drilling may occur in 1999 to increase confidence in the reserves base in the Yolla Field, and to further evaluate the exploration potential of T/18P.

scholarly journals Limitation of gas inflows under the conditions of development of Botuobinsky horizon

2020 ◽  
pp. 159-166
Author(s):  
I. I. Krasnov ◽  
V. F. Tomskaya ◽  
E. I. Inyakina ◽  
K. O. Tomsky ◽  
M. S. Ivanova ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Geological Structure ◽  
Operating Conditions ◽  
Computational Method ◽  
Field Development ◽  
Oil Reserves ◽  
Main Factors ◽  
The Republic ◽  
Effective Development ◽  
Oil Rim

The article presents the results of the study of the geological structure of oil and gas deposits in Botuobinsky horizon, affecting the gasification of producing wells and gas breakthrough into the oil rim in the conditions of field development. In the course of the research, a characteristic of the reservoir was given, and the optimal gas-free flow rate was determined by a computational method, which allows us to limit the gas inflow for the operating conditions of the Srednebotuobinskoye oil and gas condensate field. The field under consideration is one of the unique storehouses of the East-Siberian oil cluster located in the Republic of Sakha (Yakutia). The main factors influencing the effective development of oil reserves of gas and oil deposits within the Central block and the Kurung license area are substantiated.

APPRAISING THE YOLLA FIELD IN THE BASS BASIN—HOW EFFECTIVE DATA COLLECTION, ANALYSIS AND INTEGRATION INCREASED ESTIMATED HYDROCARBON VOLUMES IN PLACE

2006 ◽  
Vol 46 (1) ◽  
pp. 15
Author(s):  
D.M. Brooks ◽  
B.A. Pidgeon ◽  
A.D. Hall ◽  
R.J. Taylor ◽  
J.L. Parvar
Keyword(s):  
Joint Venture ◽  
Volatile Oil ◽  
Field Size ◽  
Gas Reservoirs ◽  
Depositional Facies ◽  
Field Development ◽  
Recoverable Reserves ◽  
Coal Measures ◽  
Solution Gas ◽  
Associated Solution

Between June and October 2004, two development wells (Yolla–3 and –4) were drilled on the Yolla field in Bass Strait by the T/L1 joint venture. The top and intra-Eastern View Coal Measures (EVCM) hydrocarbon-bearing reservoirs in the field were intersected close to prognosis. A previously undiscovered oil-bearing intra-EVCM sand was encountered in Yolla–4 and the upper EVCM gas and oil bearing reservoir section was completed in Yolla–3 and its productivity confirmed.A key objective of the development drilling campaign was to collect detailed geological and engineering data to assist in field development and quantification of the resource. Subsequent interpretation of these data led to a revision of the depositional facies and reservoir parameters and provided new inputs into a complex 3D reservoir model.The new reservoir model resulted in an upward revision in calculated gas in-place volumes for the intra-EVCM gas reservoirs of about 100 bcf (2,832 m3 x106) or 20% of the pre-drill field size to 600 bcf (16,991 m3x106) and a corresponding increase in recoverable reserves estimates. The upper EVCM is now interpreted to hold 16.5 MMstb (2,623,005 kL) of oil-in-place and total gas-in-place including the gas cap and the solution gas in the oil leg of 33 bcf (934.5 m3x106). These volumes add to the gas reserves for the field, and it is expected that the volatile oil leg will contribute to a richer liquids yield when the zone is produced. The new oil pool in the intra-EVCM has been provisionally estimated at 3.2 MMstb (508,704 kL) oil-inplace with associated solution gas of 2.5 bcf (71 m3x106).

Some lessons learnt from drilling a shale gas well in Western Australia

2014 ◽  
Vol 54 (1) ◽  
pp. 15
Author(s):  
Vamegh Rasouli
Keyword(s):  
Mechanical Properties ◽  
Shale Gas ◽  
Gas Flow ◽  
Joint Venture ◽  
Gas Well ◽  
Eastern Area ◽  
Well Design ◽  
Surface Location ◽  
Coal Measures ◽  
Exploration Well

The Arrowsmith–2 well is the first dedicated shale gas well in WA. The well is situated in the central eastern area of Permit EP413, with the surface location being about 30 km north of the township of Eneabba. Norwest, as the operator and on behalf of its joint venture partners, drilled the Arrowsmith–2 exploration well in mid-2011. In 2012 the well was subsequently perforated and fracture stimulated in five discrete stages across four formations: the High Cliff Sand Stone (HCSS); Irwin River Coal Measures (IRCM); Carynginia Formation; and, Kockatea Shale. The fraccing results have shown excellent rates of gas flow for the size of the intervals fracced, and have produced oil and/or condensate to surface from the two intervals flowed back. This paper discusses some drilling operation and design aspects of Arrowsmith–2. A review of the regional geology, basic well design, and well objectives will be given. The importance of geomechanical studies for minimising wellbore-related problems during drilling and after that for hydraulic fracturing operation will be discussed, and the results of the studies undertaken presented. The wireline logging suite run in this well was used to interpret the formations’ mechanical properties. Also, laboratory tests were performed to estimate hydro-mechanical properties of the formations. The lessons from drilling this well will be used for drilling future wells in the area with the objective of saving time and costs.

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.

The changing face of Queensland's petroleum industry

2011 ◽  
Vol 51 (1) ◽  
pp. 225 ◽  
Author(s):  
Alison Troup ◽  
Peter Green
Keyword(s):  
Coal Seam ◽  
Oil And Gas ◽  
Petroleum Industry ◽  
Petroleum Exploration ◽  
Success Rates ◽  
Coal Seam Gas ◽  
Petroleum Wells ◽  
Well Data ◽  
Coal Measures ◽  
Exploration Well

The cycles and related changes in exploration targets identified in this study show the evolution of the Queensland petroleum industry from conventional petroleum to coal seam gas dominance. Delineation of these cycles was undertaken using petroleum exploration well data, and production and reserves statistics. Although the cycles are defined on the basis of exploration activity, there is a very different history in the types of targets and commodities explored for in the Bowen-Surat and Cooper-Eromanga basins. Trends in exploration success have been influenced by technology improvements, better understanding of target reservoirs, proximity to infrastructure, government policy and world oil prices. Four distinct exploration cycles have been identified from the data. During the first cycle (1959–74) exploration focused predominantly on the shallower Jurassic-aged reservoirs in the Bowen-Surat basins resulting in the discovery of most of the major conventional oil and gas fields. The second cycle (1979–89) saw exploration begin in earnest in the Cooper-Eromanga basins and a switch to predominantly Triassic-aged reservoirs in the Bowen-Surat basins. The first coal seam gas exploration wells were drilled during this cycle. The third cycle (1990–99) shows a decrease in the number of conventional petroleum wells across both regions and the beginning of the switch to the present dominance of coal seam gas. The fourth cycle (2000–present) shows a significant decrease in the number of conventional exploration wells drilled across both regions, but an increase in the success rates. All conventional discoveries in the Bowen-Surat basins during cycle four have been in Permian-aged reservoirs, reflecting a change in the exploration focus to deeper parts of the Bowen Basin. Coal seam gas exploration has expanded significantly, with the Walloon Coal Measures being targeted, resulting in nearly four coal seam gas wells drilled for each conventional petroleum exploration well state-wide since 2000. Examination of coal seam gas exploration highlights the many false starts since the first well was drilled in 1980. Exploration has shifted from area to area as companies tested different exploration concepts and completion techniques. The most obvious shift has been from Permian-aged targets of the Bowen Basin into the Jurassic-aged Walloon Coal Measures in the Surat and Clarence-Moreton basins, as its prospectivity was realised.

A method of technical diagnostics for offshore structures

1994 ◽  
Vol 16 (2) ◽  
pp. 43-48
Author(s):  
Do Son
Keyword(s):  
Diagnostic Method ◽  
Joint Venture ◽  
Oil And Gas ◽  
Residual Life ◽  
Life Time ◽  
Offshore Structures ◽  
Technical Diagnostics ◽  
Offshore Platforms ◽  
South Vietnam ◽  
Local Destruction

This paper describes the results of measurements and analysis of the parameters, characterizing technical state of offshore platforms in Vietnam Sea. Based on decreasing in time material characteristics because of corrosion and local destruction assessment on residual life time of platforms is given and variants for its repair are recommended. The results allowed to confirm advantage of proposed technical diagnostic method in comparison with others and have been used for oil and gas platform of Joint Venture "Vietsovpetro" in South Vietnam.

Main directions of searching for hydrocarbons in Nadym-Pursk oil and gas region

2021 ◽  
pp. 23-31
Author(s):  
Y. I. Gladysheva
Keyword(s):  
Oil And Gas ◽  
Raw Materials ◽  
Accumulation Rate ◽  
Sedimentary Basins ◽  
Seismic Exploration ◽  
Research Approach ◽  
Field Development ◽  
The North ◽  
The Sixties ◽  
Hydrocarbon Deposits

Nadym-Pursk oil and gas region has been one of the main areas for the production of hydrocarbon raw materials since the sixties of the last century. A significant part of hydrocarbon deposits is at the final stage of field development. An increase in gas and oil production is possible subject to the discovery of new fields. The search for new hydrocarbon deposits must be carried out taking into account an integrated research approach, primarily the interpretation of seismic exploration, the creation of geological models of sedimentary basins, the study of geodynamic processes and thermobaric parameters. Statistical analysis of geological parameters of oil and gas bearing complexes revealed that the most promising direction of search are active zones — blocks with the maximum sedimentary section and accumulation rate. In these zones abnormal reservoir pressures and high reservoir temperatures are recorded. The Cretaceous oil and gas megacomplex is one of the main prospecting targets. New discovery of hydrocarbon deposits are associated with both additional exploration of old fields and the search for new prospects on the shelf of the north. An important area of geological exploration is the productive layer of the Lower-Berezovskaya subformation, in which gas deposits were discovered in unconventional reservoirs.

Study on the Characteristics of Well Completion Technology in Deepwater Oil and Gas Field Development

2021 ◽  
Vol 3 (8) ◽  
pp. 70-72
Author(s):  
Jianbo Hu ◽  
◽  
Yifeng Di ◽  
Qisheng Tang ◽  
Ren Wen ◽  
...  
Keyword(s):  
Deep Water ◽  
Deep Sea ◽  
Oil And Gas ◽  
Gas Field ◽  
Marine Research ◽  
Field Development ◽  
Research Technology ◽  
Well Completion ◽  
Development Capacity ◽  
Exploration And Development

In recent years, China has made certain achievements in shallow sea petroleum geological exploration and development, but the exploration of deep water areas is still in the initial stage, and the water depth in the South China Sea is generally 500 to 2000 meters, which is a deep water operation area. Although China has made some progress in the field of deep-water development of petroleum technology research, but compared with the international advanced countries in marine science and technology, there is a large gap, in the international competition is at a disadvantage, marine research technology and equipment is relatively backward, deep-sea resources exploration and development capacity is insufficient, high-end technology to foreign dependence. In order to better develop China's deep-sea oil and gas resources, it is necessary to strengthen the development of drilling and completion technology in the oil industry drilling engineering. This paper briefly describes the research overview, technical difficulties, design principles and main contents of the completion technology in deepwater drilling and completion engineering. It is expected to have some significance for the development of deepwater oil and gas fields in China.

Diagnostic Results of Current Distribution Injected Water Flow in the Productive Formation for Neft Dashlary Oilfield

2021 ◽  
Author(s):  
Khidir Mansum Ibragimov ◽  
Nahide Ismat Huseinova ◽  
Aliabas Alipasha Gadzhiev
Keyword(s):  
Current Distribution ◽  
Oil And Gas ◽  
Experimental Studies ◽  
Oil Field ◽  
Fluid Distribution ◽  
Field Development ◽  
Hydrodynamic Parameters ◽  
Oil And Gas Fields ◽  
Oil Field Development ◽  
Gas Fields

Abstract For controlling the oil field development proposed an economically efficient express calculation and visualization method of the hydrodynamic parameters current values distribution in the productive formation. The presented report shows the results of applying this technique for determining the injected water propagation direction into the productive formation (X horizon) at the «Neft Dashlary» field. Based on the calculated results, the current distribution of the injected water was visualized in the selected section of the formation. High accuracy of the calculation was confirmed by comparing obtained results with the results of a simultaneous tracer study conducted in the field conditions. During tracer studies it was tested a new tracer material, more effective than its analogs. According to laboratory and experimental studies, the addition of 0.003% of this indicator substance to the volume of injected water is the optimal amount for its recognition in the well's product. At the allocated area of the "Neft Dashlari" field, the benefits from the use of the calculation method amounted to 62.9 thousand manats. Based on the obtained satisfying results of the new method for calculating hydrodynamic parameters and the use of a tracer indicator application at the «Neft Dashlary» oilfield, it is recommended to apply these developments in other oil and gas fields for mass diagnostic of the reservoir fluid distribution in a selected area of productive formations.

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