Full-Field Simulation for Development Planning and Reservoir Management at Kuparuk River Field

Abstract Pressure transient analysis (PTA) has been used as one of the important reservoir surveillance tools for tight condensate-rich gas fields in Sultanate of Oman. The main objectives of PTA in those fields were to define the dynamic permeability of such tight formations, to define actual total Skin factors for such heavily fractured wells, and to assess impairment due to condensate banking around wellbores. After long production, more objectives became also necessary like assessing impairment due to poor clean-up of fractures placed in depleted layers, assessing newly proposed Massive fracturing strategy, assessing well-design and fracture strategies of newly drilled Horizontal wells, targeting the un-depleted tight layers, and impairment due to halite scaling. Therefore, the main objective of this paper is to address all the above complications to improve well and reservoir modeling for better development planning. In order to realize most of the above objectives, about 21 PTA acquisitions have been done in one of the mature gas fields in Oman, developed by more than 200 fractured wells, and on production for 25 years. In this study, an extensive PTA revision was done to address main issues of this field. Most of the actual fracture dynamic parameters (i.e. frac half-length, frac width, frac conductivity, etc.) have been estimated and compared with designed parameters. In addition, overall wells fracturing responses have been defined, categorized into strong and weak frac performances, proposing suitable interpretation and modeling workflow for each case. In this study, more reasonable permeability values have been estimated for individual layers, improving the dynamic modeling significantly. In addition, it is found that late hook-up of fractured wells leads to very poor fractures clean out in pressure-depleted layers, causing the weak frac performance. In addition, the actual frac parameters (i.e. frac-half-length) found to be much lower than designed/expected before implementation. This helped to improve well and fracturing design and implementation for next vertical and horizontal wells, improving their performances. All the observed PTA responses (fracturing, condensate-banking, Halite-scaling, wells interference) have been matched and proved using sophisticated single and sector numerical simulation models, which have been incorporated into full-field models, causing significant improvements in field production forecasts and field development planning (FDP).

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The Waitsia Field, onshore North Perth Basin, Western Australia

The APPEA Journal ◽

10.1071/aj15003 ◽

2016 ◽

Vol 56 (1) ◽

pp. 29 ◽

Cited By ~ 2

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.

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A Case Study of the Full-Field Simulation of a Reservoir Containing Bottomwater

10.2118/21203-ms ◽

1991 ◽

Cited By ~ 2

Author(s):

G.R. King ◽

D.E. Snyder ◽

T.S. Obut ◽

R.L. Perkins

Keyword(s):

Full Field ◽

Field Simulation

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A Full-Field Simulation Study of the Effect of Foam Injection on Recovery Factor of an Iranian Oil Reservoir

10.3997/2214-4609-pdb.147.iptc11181 ◽

2007 ◽

Author(s):

S.M. Seyed Alizadeh ◽

N. Alizadeh ◽

B. Maini

Keyword(s):

Simulation Study ◽

Recovery Factor ◽

Oil Reservoir ◽

Full Field ◽

Field Simulation

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

The APPEA Journal ◽

10.1071/aj16216 ◽

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.

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