Sanding: A Rigorous Examination of the Interplay Between Drawdown, Depletion, 
Start-up Frequency and Water Cut

Allam, R.; Kidd, Gordon; Bennett, C.E.; Grose, Trevor; Robinson, Peter; Malyn, Jeremy

doi:10.2523/89895-ms

Cited by 7 publications

(6 citation statements)

References 7 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…One of the most effective means of controlling sand production is with a conservative, disciplined bean-up and down process (Vaziri et al, 2006). It is believed that a gradual, extended bean-up enables pore pressure equalization in the near-wellbore region to minimize the potential of formation rock tensile failure and/or fines migration.…”

Section: Bean Up/down Criteriamentioning

confidence: 99%

Sand Management in Tangguh Big Gas Wells

Warnken¹,

Asri²,

Anantokusumo³

et al. 2013

SPE Asia Pacific Oil and Gas Conference and Exhibition

View full text Add to dashboard Cite

Tangguh is a Liquefied Natural Gas (LNG) greenfield development located in Bintuni Bay, Papua Barat, Indonesia. There are fourteen wells that are designed to produce up to 240 MMcf/D per well. Sand and other solids from the reservoir are managed with a comprehensive, holistic strategy to provide operational assurance from the sandface to the processing facility.The Tangguh gas wells are identically completed in the Roabiba formation with seven inch monobore cased-hole perforated completions. Each well flowline is equipped with a dedicated non-intrusive acoustic sand detector and wet gas flowmeter. Well bottomhole pressures are monitored continuously with permanent downhole pressure sensors.Extensive log and core analyses suggested that Roabiba formation competency was sufficient to not require downhole sand control. Similarly, surface processing facilities and flowlines were constructed with a design basis of very low levels of sand and other solids production. Produced liquid yields are low and formation water is not expected until the latter years of field depletion.An integrated sand management strategy has been implemented since pre-startup with an underlying theme of formation sand prevention. Following completion, all wells were methodically cleaned up to remove potential formation drilling damage and other completion related debris. Wells were initially cleaned up to 100 MMcf/D with rig testing equipment and later ramped up to their maximum allowable rate to the permanent production facility.Measured formation sand production is negligible to date. Real-time well performance is monitored continuously and managed with rigorous constraints to minimize potential sand and other solids production. Detection of acoustic signals over a pre-determined limit are investigated and followed up with further action as necessary.

show abstract

Section: Bean Up/down Criteriamentioning

confidence: 99%

Sand Management in Tangguh Big Gas Wells

Warnken¹,

Asri²,

Anantokusumo³

et al. 2013

SPE Asia Pacific Oil and Gas Conference and Exhibition

View full text Add to dashboard Cite

show abstract

“…According to rock failure mechanism in sand production scenarios, rock strength is one of the dominant factors that influence sand production in unconsolidated reservoirs [10]. Fig.…”

Section: Effect Of Rock Strengthmentioning

confidence: 99%

The Quantitative Analysis of Optimized Pressure Drawdown in Unconsolidated Sand Reservoirs

Feng

Xue

2008

Canadian International Petroleum Conference

View full text Add to dashboard Cite

Sand production is a serious problem in unconsolidated sandstone, it's becomes more critical as operators follow more aggressive production strategies. A successful sand control or management needed to evaluate sand production probability, to quantify risk reduction, and to establish practical operational scheme for safe and optimum production.In this paper, focusing on the coupling between fluid flow and solid deformation, a consistent geometrical frame for sand prediction is established, which includes the capacity to predict sand production onset, sand quantities and sand production rates. Finite element method is used to solve the coupled governing equation system. Field data for sand production and enhanced oil production from Bohai Oilfield (Tianjin, China) were used to validate the model for the sand rate and sand production. Our studies indicate that the optimized pressure drawdown in unconsolidated sand be controlled by the following key physical parameters: (1) rock strength; (2) fluid viscosity; (3) pressure drawdown build-up strategy and pressure disturbance. The simulation results relating cumulative sand production and sand production rate to these important variables are presented.The study suggests that the proposed model may be used to generate quantitative information for predicting sand production and optimizing pressure drawdown. This provides a tool for sand-management in exploiting the weakness of sanding-prone scenarios.

show abstract

“…These instruments can thus be used as a go/nogo gauge for optimizing drawdown while minimizing sand production. [11][12][13][14] Another approach is dilution of the produced sand. If a single or small group of wells in a large field are the only sand producers, they can be co-mingled with low sanding wells to dilute the overall sand effect.…”

Section: Production Limitsmentioning

confidence: 99%

A Comparison of Methodologies for Handling Produced Sand and Solids to Achieve Sustainable Hydrocarbon Production

Rawlins

Hewett²

2007

All Days

View full text Add to dashboard Cite

fax 01-972-952-9435. AbstractAll oil and gas wells produce sand or solids in varying types and amounts. The size and concentration of natural solids (i.e. formation sand) and artificial solids (i.e. workover debris) determine their net effect on production equipment and the resulting management of hydrocarbon production. Conventional exclusion methodology prevents solids from entering the wellbore but may adversely affect inflow production due to skin buildup. Inclusion methodology allows the solids to be produced with well fluids for surface separation and handling. A comparison of the performance, operability, cost impact, and effect on production rate is made for both methods through application examples. The goal is to show that the increased production resulting from allowing solids to be produced in some high sand rate wells allows more sustainable hydrocarbon production with a cost benefit compared to downhole exclusion for certain producing regions.

show abstract

Sanding: A Rigorous Examination of the Interplay Between Drawdown, Depletion, Start-up Frequency and Water Cut

Cited by 7 publications

References 7 publications

Sand Management in Tangguh Big Gas Wells

Sand Management in Tangguh Big Gas Wells

The Quantitative Analysis of Optimized Pressure Drawdown in Unconsolidated Sand Reservoirs

A Comparison of Methodologies for Handling Produced Sand and Solids to Achieve Sustainable Hydrocarbon Production

Contact Info

Product

Resources

About