Prospectivity and Exploration Challenges of SC 41 - Deepwater Sandakan Basin, South Sulu Sea

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Prospectivity and Exploration Challenges of SC 41 - Deepwater Sandakan Basin, South Sulu Sea
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    Copyright South East Asia Petroleum Exploration Society SEAPEX Exploration Conference 2009 Orchard Hotel, Singapore 20 th  – 24 th  April 2009 Day: Wednesday 22 nd  April Session: Philippines and Malaysia Session Time: 1100-1130 hrs Prospectivity and Exploration Challenges of SC 41 -Deepwater Sandakan Basin, South Sulu Sea Joe Scibiorski, John Jong, Jack Rosser, Pat Boss and Bob Cassie - Tap Oil Limited The Sandakan Basin is one of several circum Borneo Upper Tertiary sag basins. It contains up to 6 km of primarily Miocene to Pliocene deltaic and deepwater sediments. The basin has high potential but is under-explored. Similar Borneo basins including the Baram Delta, the North Sabah Basin, the Tarakan Basin, and the Kutei Basin have combined reserves of greater than 10 billion bbls of oil and 35 tcf of gas. Permit SC 41 covers an area of approximately 3,580 km 2  in Filipino waters of the north-eastern portion of the Sandakan Basin. Water depths range from 200 to 2000 m. The Tap led Joint Venture became involved in mid 2006, acquired the 750 km 2  Alpine 3D seismic survey in 2007, and drilled the Lumba Lumba-1A exploration well in mid 2008. The main exploration interest of the Tap JV is the deepwater sediments of SC 41. The focus of previous exploration in the Sandakan Basin and SC 41 was on shallow water deltaic and carbonate plays, which have been successful in other circum Borneo basins. Failure of these play types in the Sandakan is attributed to seal failure due to high sand content and cross fault leakage. The only previous test of deepwater sediments in SC 41 was Wildebeest-1, drilled by Unocal in 2000 and based on 2D seismic coverage. It drilled a thick succession of claystones and siltstones but encountered oil (recovered in MDTs) in two thin sandstone zones. The well demonstrates the presence of hydrocarbons and effective sealing facies in the deepwater sediments.    Copyright South East Asia Petroleum Exploration Society The primary section of interest in SC 41 is the Late Miocene, with up to 3 km of sediment deposited in less than 3 million years. Potential reservoirs and traps can occur at any level within this section. Slope accommodation space is created by tectonism and slumping. The resulting topography is often in-filled by interpreted turbiditic channel or fan deposits. Reservoir has been inferred based primarily upon seismic morphology and seismic amplitude contrast. AVO and seismic attributes have been used qualitatively, but quantitative measurements have not been possible due to lack of well control for calibration. The structural processes in and proximal to SC 41 include northerly trending extensional faulting of the shelfal area, associated folding and thrusting in the deepwater areas, and toe thrusting in deepwater regions to the east of the permit. Structuring is interpreted to have occurred during and/or after reservoir deposition, resulting in a variety of trapping styles including structural closures, ponded reservoirs, and purely stratigraphic traps. Evidence of an effective petroleum system in the deepwater sediments of SC 41 is given by the Wildebeest-1 oil recoveries, numerous interpreted gas clouds over structural closures and proximal to interpreted reservoirs, amplitude cut offs at faults, probable flat spots, surface mounds, and surface pock marks. To date the Tap JV has identified in excess of 20 prospects and leads with resource potential ranging from 5 to greater than 150 mmbbls. These leads have diverse structural and stratigraphic components. Lumba Lumba-1A tested a large, inverted structure with multiple objectives in interpreted channel and channel fan complexes. The structure is partially obscured by interpreted gas clouds, similar to many large Borneo oil fields (e.g. Kikeh). Lumba Lumba-1A tested the primary reservoir objectives and although elevated gas readings were observed it did not encounter reservoir quality rocks – the primary pre drill risk. The result of the well was disappointing but has little impact on risks associated with other prospects and leads because of their diverse structural settings, reservoir morphologies, and seismic attributes. Future exploration challenges of the region are primarily focused on detection of reservoir fairways, delineation of effective reservoirs, and fluid identification . Interpretation is ongoing. Reprocessing of the Alpine 3D including PSDM and seismic inversion will assist in imaging through zones of low reflectivity associated with interpreted gas clouds, address other areas of deteriorated seismic quality, obtain better amplitude balancing, and enable better calibration to wells. Current interpretation efforts are focused on correlations of additional regional surfaces, prospect identification for deeper objectives, and further seismic analysis of existing prospects and leads. Although significant technical challenges remain, the size and number of remaining prospects along with the favourable Filipino fiscal terms makes the Sandakan Basin a prize worth pursuing.  11111   www.tapoil.com.au This presentation contains some references to forward looking assumptions, representations, estimates, budgets, and outcomes. These are uncertain by the nature of the business and no assurance can be given by Tap Oil Limited that its expectations, estimates, budgets and forecast outcomes will be achieved. Actual results may vary materially from those expressed herein. Prospectivity and Exploration Challenges of SC41Deepwater Sandakan Basin, South Sulu Sea SEAPEX Exploration Conference, 22 April 2009Presented by Tap Oil Ltd DMS#101058  Outline of Presentation 1. Introduction2. Geological Framework3. Petroleum Systems4. Lumba Lumba-1A Review5. Prospectivity6. Conclusions 222 April 2009  Outline of Presentation 1. Introduction2. Geological Framework3. Petroleum Systems4. Lumba Lumba-1A Review5. Prospectivity6. Conclusions 322 April 2009
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