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Oceania
Cross-hole data analysis Initial P-wave anisotropy analysis was carried out by comparing the zero-offset P-wave and VSP derived interval velocities with the cross-hole P-wave velocities derived for the common source-receiver depth level, at the same depth intervals. The average P-wave anisotropy for the main lithological units is given in Table 1. Detailed analysis of these measurements can be found elsewhere (i.e.
- Oceania > Australia (0.31)
- North America > United States (0.29)
- North America > Canada (0.19)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.48)
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Coal (0.47)
This where V is the P-wave velocity and Q is the rock quality suggests that it is the combination of the sands at the factor. This means that for materials of similar density and interface that produces the acoustic impedance contrast velocity, the bulk modulus is dependent on Q, which can be required for a reflection, which is a provocative statement thought of as the ability of the sediment to transmit seismic and challenges the need for separate layers with different energy. Q is also related to the attenuation coefficient (ฮฑ) acoustic impedances.
Seismic processing was developed to produce stacked sections with coherent panels of dip corresponding to real structural elements.
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.49)
- Geology > Rock Type > Sedimentary Rock (0.31)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (1.00)
- Geophysics > Seismic Surveying > Seismic Processing > Seismic Migration (0.98)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.97)
- Oceania > Papua New Guinea > Southern Highlands > Papuan Basin > PL 3 > Gobe Field (0.94)
- Oceania > Papua New Guinea > Southern Highlands > Papuan Basin > PDL 6 > Petroleum Development Licence-6 (PDL 6) > Moran Field (0.94)
- Oceania > Papua New Guinea > Southern Highlands > Papuan Basin > PDL 6 > Petroleum Development Licence-5 (PDL-5) > Moran Field (0.94)
- (9 more...)
Choose a non-negative differentiable function ฮธ(x) such The fundamental equations of potential field theory have an interesting interpretation when regarded as a particular that ฮธ(x)dx 1; enforce the scaling property R case of a multiscale wavelet transform.
As part of the Australian Geological Survey Organisation's (AGSO) Timor Sea Project, a major upgrade of the marine ship-track potential field and bathymetry data which have been acquired on the north-west Australian margin since 1963 has been undertaken.
- Geophysics > Gravity Surveying (0.84)
- Geophysics > Magnetic Surveying > Magnetic Acquisition > Airborne Magnetic Acquisition (0.41)
Similar sinusoidal variations in stacking velocity have been noted in the Gulf of Mexico (Pickard 1992). Through simple modeling, Pickard demonstrates that a near surface low velocity anomaly over a 1/4 to a full cable length will induce a high stacking velocity immediately above the anomaly. This is due to a flattening of the moveout curve caused by the delay in the near offset reflections. Low stacking velocities are induced on either side of the anomaly due to greater moveout caused by the retarding of the far offset arrivals. This is precisely the effect observed in the stacking velocities of OS96-310.
- Oceania > Australia > Queensland > Surat Basin (0.99)
- Oceania > Australia > Queensland > Central Highlands > Bowen Basin (0.99)
- Oceania > Australia > New South Wales > Surat Basin (0.99)
- (4 more...)
3D Multiple Moveout Wavefield Transformation For Pre-conditioning Data For the Removal of Water Bottom Multiples
Hartley, B.M. (Curtin University of Technology, Department of Exploration Geophysics.) | Uren, N.F. (Curtin University of Technology, Department of Exploration Geophysics.) | Lamont, M.G. (Curtin University and Texseis Inc, Houston, Texas.)
Theory Wavefield transformations have been used for many years The three-dimensional transform is a simple extension of to precondition seismic data to enhance useful features of the derivation of the two-dimensional transform and starts the seismic record or to suppress unwanted signal or noise.
Abstract An efficient approach to wellbore stability analysis and management of shale instability by taking into consideration the dominant instability mechanism(s) has been developed. The mechanism(s) is dependent on the type of shale, in-situ stress environment and drilling fluid system used. These factors determine whether a drilling fluid program can be developed using a mechanical (stress-induced) wellbore stability analysis or complex time-dependent drilling fluid-shale interaction and thermal mechanisms need to be taken into account. A range of wellbore stability analytical tools for efficient management of shale instability is presented. A pragmatic approach to use drilling fluid design charts together with a shale property database and property correlations for designing optimal drilling fluids to manage shale instability efficiently is described. The utilisation of the tools is demonstrated through a field case study in which strategies are developed to control wellbore instability in horizontal wells. Parametric analyses conducted demonstrate the effects of shale and drilling fluid properties on time-dependent wellbore (in)stability. They highlight the conditions in which the drilling fluid-shale interaction mechanisms are critical and need to be incorporated in the analysis. P. 165
- Europe (1.00)
- Asia (1.00)
- Oceania > Australia > Western Australia > North West Shelf (0.28)
- South America > Colombia > Casanare Department > Llanos Basin > Cusiana Field > Mirador Formation (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Muderong Shale Formation (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Barrow Basin > Griffin Field (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Alpha Arch > Barrow Basin > Griffin Field (0.99)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Drilling > Drilling Fluids and Materials (1.00)
Management of Wellbore Instability & Formation Damage by Improved Drilling Mud Design
Azizi, T. (School of Petroleum Engineering, the University of New South Wales) | Chen, H. (School of Petroleum Engineering, the University of New South Wales) | Rahman, S.S. (School of Petroleum Engineering, the University of New South Wales)
Abstract Wellbore instability and formation damage are the two major problems encountered by the petroleum industry. It is commonly accepted that formation damage is mainly caused by fluid-rock interaction due to the change in pore fluid chemistry which is caused by invading mud filtrate. Invasion of mud filtrate can be reduced by forming a tight filter cake on the wellbore wall. A tight filter cake can also provide support to the wellbore wall and prevent wellbore collapse. Therefore, the most effective option for solving wellbore instability and formation damage problems is to design a drilling mud that is compatible with formations in relation to both fluid-rock interaction and mud caking characteristics. This paper considers a number of mud systems with novel features and investigates their potential use in drilling and completion of tight gas formations in Central Australia, which are highly susceptible to formation damage. Among the four (4) muds investigated, ester based mud has been found to be the most effective in reducing formation damage by producing a tight filter cake on the wellbore wall. P. 113
- Oceania > Australia (0.67)
- North America > United States > Texas (0.28)
- Geology > Mineral > Silicate > Phyllosilicate (0.50)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.32)
This paper (SPE 51181) was revised for publication from paper SPE 35077, first presented at the 1996 IADC/SPE Drilling Conference held in New Orleans, 12-15 March. Original manuscript received for review 12 June 1996. Revised manuscript received 30 April 1997. Paper peer approved 17 April 1998. Summary This paper presents an alternative planning approach to the drilling and completion process, technical limit, which has resulted in a step change in Woodside's performance. Three new wells and six subsea completions were finished 20% under budget with this tool and with a simple philosophy characterized by the following questions.What is current performance? What is possible? What is needed to get there? The target was to drill a directional well in 20 days when the previous best time was 42 days. A target of 12 days was set on subsea completions, although a conventional approach had previously been 20+ days. The methodology was to ask what would be possible if everything went perfectly on every operation making up the well time. This is not the usual trouble free time but a well time built up of individual components, with each component representing its theoretical best performance. Details of how the approach was used to plan, and operational data that confirm that the technical limit can be approached are presented. As a result, the well construction performance delivered step change improvement when managed against the technical limit. P. 197
- Oceania > Australia > Western Australia (0.29)
- North America > United States > Louisiana > Orleans Parish > New Orleans (0.24)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Dampier Basin > North West Shelf > WA-9-L > CWLH Field > Wanaea Field > Angel Formation (0.93)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Dampier Basin > North West Shelf > WA-28-P > CWLH Field > Wanaea Field > Angel Formation (0.93)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Dampier Basin > North West Shelf > WA-11-L > CWLH Field > Wanaea Field > Angel Formation (0.93)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Dampier Basin > North West Shelf > CWLH Field > Cossack Field > Angel Formation (0.89)