Uncertainty and Sensitivity Analysis on Clastic Systems: Integrated Workflows for Understanding and Managing the Risk, A Case Study in Tuwayil Formation UAE

2021 ◽  
Author(s):  
Mahmud Ebeid ◽  
Humberto Parra ◽  
Dipankar Ghosh ◽  
Jeonggil Kang ◽  
Kwangwon Seo
Keyword(s):  
Free Water ◽  
Sensitivity Analyses ◽  
Limited Data ◽  
Full Field ◽  
Field Development ◽  
Area Of Interest ◽  
Depositional System ◽  
The 1960S ◽  
Well Data ◽  
Clastic Reservoir

Abstract This study has been done on Late Cretaceous tight clastic reservoir located south west of Abu Dhabi city with the border with Saudi Arabia. The field was discovered in the 1960s and a few wells were drilled subsequently. The Tuwyail clastic reservoir is characterized as tight with average permeability below 1 mD. The trap is identified as structural trap as north south anticline with gentle dip in both sides. Total of six wells were drilled targeting Tuwyail reservoir which part is of Wasia group. However, assessing potential of this accumulation poses a great challenge not only in terms of understanding of the depositional system which still unknown before but also in terms of quality of the legacy data like well data that impact the modeling studies. The aim of this paper is to provide an insight on integrated workflows for assessing the different uncertainties on clastic systems with limited data, focused on the most important sensitivities parameters impacting the oil in place, like reservoir proportions, free water level [FWL] and lateral distributions of the sedimentary elements within the area of interest which playing a big rules in future developing of the field. Before moving to full field development a full uncertainty and sensitivity analyses were conducted for the Tuwayil reservoir to find the highly uncertain parameters that impacting the future development of the reservoir, in the same time the main challenges is the limited data with low quality as the wells had been drilled in 60s with limited technology at that time and the core data were left in a bad conditions since the filed was left behind.

scholarly journals The Waitsia Field, onshore North Perth Basin, Western Australia

2016 ◽  
Vol 56 (1) ◽  
pp. 29 ◽  
Author(s):  
Neil Tupper ◽  
Eric Matthews ◽  
Gareth Cooper ◽  
Andy Furniss ◽  
Tim Hicks ◽  
...  
Keyword(s):  
Flow Characteristics ◽  
Development Planning ◽  
Upper Permian ◽  
Depth Interval ◽  
Lower Permian ◽  
Minimal Processing ◽  
Gas Field ◽  
Full Field ◽  
Field Development ◽  
Primary Porosity

The Waitsia Field represents a new commercial play for the onshore north Perth Basin with potential to deliver substantial reserves and production to the domestic gas market. The discovery was made in 2014 by deepening of the Senecio–3 appraisal well to evaluate secondary reservoir targets. The well successfully delineated the extent of the primary target in the Upper Permian Dongara and Wagina sandstones of the Senecio gas field but also encountered a combination of good-quality and tight gas pay in the underlying Lower Permian Kingia and High Cliff sandstones. The drilling of the Waitsia–1 and Waitsia–2 wells in 2015, and testing of Senecio-3 and Waitsia-1, confirmed the discovery of a large gas field with excellent flow characteristics. Wireline log and pressure data define a gross gas column in excess of 350 m trapped within a low-side fault closure that extends across 50 km2. The occurrence of good-quality reservoir in the depth interval 3,000–3,800 m is diagenetically controlled with clay rims inhibiting quartz cementation and preserving excellent primary porosity. Development planning for Waitsia has commenced with the likelihood of an early production start-up utilising existing wells and gas processing facilities before ramp-up to full-field development. The dry gas will require minimal processing, and access to market is facilitated by the Dampier–Bunbury and Parmelia gas pipelines that pass directly above the field. The Waitsia Field is believed to be the largest conventional Australian onshore discovery for more than 30 years and provides impetus and incentive for continued exploration in mature and frontier basins. The presence of good-quality reservoir and effective fault seal was unexpected and emphasise the need to consider multiple geological scenarios and to test unorthodox ideas with the drill bit.

Cardiac Elastography, Full-Field Development

2008 ◽  
pp. 506-513
Author(s):  
Tomy Varghese ◽  
Q Chen ◽  
P Rahko ◽  
James Zagzebski
Keyword(s):  
Full Field ◽  
Field Development

Achieving Cementing Improvement in Horizontal Tight Gas Field Development

2015 ◽  
Author(s):  
Pungki Ariyanto ◽  
Mohamed.A.. A. Najwani ◽  
Yaseen Najwani ◽  
Hani Al Lawati ◽  
Jochen Pfeiffer ◽  
...  
Keyword(s):  
Tight Gas ◽  
Cement Slurry ◽  
Tight Sandstone ◽  
Gas Field ◽  
Full Field ◽  
Field Development ◽  
Horizontal Drain ◽  
Tight Reservoir ◽  
Design For All ◽  
Zonal Isolation

Abstract This paper outlines how a drilling team is meeting the challenge of cementing a production liner in deep horizontal drain sections in a tight sandstone reservoir. It is intended to show how the application of existing technologies and processes is leading to performance gain and improvements in cementing quality. The full field development plan of the tight reservoir gas project in the Sultanate of Oman is based on drilling around 300 wells targeting gas producing horizons at measured depths of around 6,000m MD with 1,000m horizontal sections. Effective cement placement for zonal isolation is critical across the production liner in order to contain fracture propagation in the correct zone. The first few attempts to cement the production liner in these wells had to overcome many challenges before finally achieving the well objectives. By looking at the complete system, rather than just the design of the cement slurry, the following criteria areas were identified: –Slurry design–Mud removal and cement slurry placement–Liner hanger and float equipment Improvements have been made in each of these areas, and the result has been delivery of a succesfully optimised liner cementing design for all future horizontal wells.

Reservoir to market: generating project value by coupling surface facilities with reservoir data in integrated asset modelling

2017 ◽  
Vol 57 (2) ◽  
pp. 652
Author(s):  
Stephen Stokes
Keyword(s):  
Supply Chain ◽  
Development Planning ◽  
Cutting Edge ◽  
Concept Design ◽  
Full Spectrum ◽  
Full Field ◽  
Field Development ◽  
Cost Reductions ◽  
Definition Of ◽  
Assessing Sensitivity

Reservoir to market is a cutting-edge integrated asset modelling (IAM) initiative that is deployed to deliver robust field development and concept design solutions with enhanced project economics. The approach offers the potential to identify supply-chain cost reductions across the full spectrum of upstream developments, from full field development planning to individual equipment item modification. The process offers particular value in Greenfield and Brownfield development planning, in identifying and assessing sensitivity options and in definition of the optimum concept.

Implications of accurate geomechanical modelling and systematic core testing for sanding evaluation and sand control decisions – a case study from Perth Basin

2020 ◽  
Vol 60 (1) ◽  
pp. 267
Author(s):  
Sadegh Asadi ◽  
Abbas Khaksar ◽  
Mark Fabian ◽  
Roger Xiang ◽  
David N. Dewhurst ◽  
...  
Keyword(s):  
Management Strategies ◽  
Mechanical Tests ◽  
Well Test ◽  
Sand Production ◽  
Gas Field ◽  
Stress Regime ◽  
Full Field ◽  
Field Development ◽  
Sand Control ◽  
Rock Mechanical Properties

Accurate knowledge of in-situ stresses and rock mechanical properties are required for a reliable sanding risk evaluation. This paper shows an example, from the Waitsia Gas Field in the northern Perth Basin, where a robust well centric geomechanical model is calibrated with field data and laboratory rock mechanical tests. The analysis revealed subtle variations from the regional stress regime for the target reservoir with significant implications for sanding tendency and sand management strategies. An initial evaluation using a non-calibrated stress model indicated low sanding risks under both initial and depleted pressure conditions. However, the revised sanding evaluation calibrated with well test observations indicated considerable sanding risk after 500 psi of pressure depletion. The sanding rate is expected to increase with further depletion, requiring well intervention for existing producers and active sand control for newly drilled wells that are cased and perforated. This analysis indicated negligible field life sanding risk for vertical and low-angle wells if completed open hole. The results are used for sand management in existing wells and completion decisions for future wells. A combination of passive surface handling and downhole sand control methods are considered on a well-by-well basis. Existing producers are currently monitored for sand production using acoustic detectors. For full field development, sand catchers will also be installed as required to ensure sand production is quantified and managed.

LOW COST FLOATING PRODUCTION FACILITY CONCEPTS FORTROPICAL WATERS

2000 ◽  
Vol 40 (1) ◽  
pp. 481
Author(s):  
L.C. Rathie ◽  
G.F. Hogan ◽  
M.J. Paton
Keyword(s):  
Cost Reduction ◽  
Low Cost ◽  
Effective Means ◽  
Production Facility ◽  
Significant Cost ◽  
Full Field ◽  
Field Development ◽  
Significant Cost Reduction ◽  
Boundary Limits ◽  
Area Development

A number of floating production facility concepts can be readily applied to the development of small and marginal oilfields in moderately deep tropical waters. These concepts can be used to extend the lives of existing mature fields. They can be deployed for a significant cost reduction compared with a conventional full field development provided that boundary limits for application of the concepts are not exceeded.Simple, standardised, reliable and proven equipment should be utilised that may be deployed in innovative ways. Wherever possible, existing equipment should be used and rented where this is economical.Marginal field projects should be managed and operated by small organisations competent in these activities to minimise overheads and maximise flexibility.An inter-field transfer approach (Ocean Truck) offers many options for developing a number of such projects as part of an area development strategy.Cooperation between operators, both as partners in a particular project and in different projects where the same facilities can be used sequentially or in parallel, can be an effective means to control costs and ensure that small oil accumulations are developed.

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