Integrated Risk Analysis for Scale Management in Deepwater Developments

Mackay, Eric James; Jordan, Myles Martin; Feasey, Neil D.; Shah, D.; Kumar, Pradeep; Ali, Syed A.

doi:10.2118/87459-ms

Cited by 31 publications

(22 citation statements)

References 20 publications

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“…The ability to predict the formation of such scales is well published and in recent years the use of reservoir simulation has allowed the mixing of these fluids within the reservoir and the near wellbore region to be predicted (Collins 2005 Mackay et al, 2004). In this study the ability to assess the location of water breakthrough and its composition forms the initial element of the risk assessment.…”

Section: Equationmentioning

confidence: 99%

Scale Squeeze Placement Options in Subsea Multi-Lateral Horizontal Wells Completed With Sliding Sleeve Technology

Jordan

Ishkov²,

Vazquez³

et al. 2016

All Days

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The deployment of scale squeeze treatments in subsea horizontal wells has always presented a challenge in terms of understanding the location of injected fluids vs the location of the produced water where scale formation will occur. Over the years software packages such as Eclipse has been able to provide valuable information on the possible placement options for such wells when production logging tool (PLT) data have not been available. The development of multi-lateral drilling/completion technology has further complicated the placement challenges in such wells.In this paper Eclipse simulation data has been linked to SQUEEZE designs software for two subsea production wells completed with multi laterals and sliding sleeves to allow selective placement of the squeeze treatment. The objective of the study was to evaluate the options of bullhead deployment in terms of both laterals being open during the squeeze vs two squeeze stages being sized and selectively placed into each lateral again via bullhead deployment, but this time using the sliding sleeve technology to divert the chemical.Information on cross flow issues, the pump rates required to allow effective placement are presented, along with the differences in chemical volumes, pump time and soak times required for the two potential treatment options. The finding from this study show the clear advantages in terms of treatment volumes, reduced clean up time and extended treatment life (reduced intervention frequency) of bullhead deployment of two squeeze steps, one to each lateral, achieved by utilizing the sliding sleeve technology in these two production wells.

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Section: Equationmentioning

confidence: 99%

Scale Squeeze Placement Options in Subsea Multi-Lateral Horizontal Wells Completed With Sliding Sleeve Technology

Jordan

Ishkov²,

Vazquez³

et al. 2016

All Days

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“…12,26 This assessment has been carried out for the two Blane wells to understand the challenges that localized scale formation could have over the production life of the two long (A02 at 729m and A04 at 1 053m) wells. Following on the evaluation of the injection water breakthrough location, an assessment was made of the ability to bullhead fluids along the well and their location relative to these injection water breakthrough zones.…”

Section: Near Well Bore Simulations For Brine Production and Squeeze mentioning

confidence: 99%

“…This is the first placement option that requires to be assessed before core complex and costly intervention/placement options are assessed. This approach of using reservoir simulation data from Eclipse to better understand fluid ingress and placement as a function of pump rate has been published in the past by the co-authors 12,26,27 and is now viewed as industry best practice in new field developments. In Figures 22 and 23 the location of water production 6 hours, 1 week and 1 year after the bullheaded treatment is presented as green lines for the wells A02 and A04 respectively.…”

Section: Placement Challenges -Injection Water Ingress Vs Bullhead Pmentioning

confidence: 99%

“…In many cases, due to the relatively short production intervals (20ft to 200ft), comparatively uniform permeability and relatively even pressures within layers, achieving an even distribution of the scale squeeze treatment chemicals along the production interval is not problematic. The use of squeeze design software such as SQUEEZE 28 has become the most common way to calculate the treatment volumes required for such treatments and in more complex wells such as Wells A02 and A04 the integration of the SQUEEZE code with Eclipse simulation data to provide better information on fluid placement has proved very effective 12,26,29,30 .…”

Section: Initial Squeeze Design Volumesmentioning

confidence: 99%

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Selection of Scale Control Strategy on a Sub Sea Developed Field in the North Sea and How 6 Different Companies Contributed

Sørhaug

Jordan

McCartney³

et al. 2014

SPE International Oilfield Scale Conference and Exhibition

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The Blane field is a sub-sea oil and gas production development located in the southern part of the North Sea straddling the UK and Norwegian border. The field is expected to produce inorganic scale (BaSO 4 ) when injection water containing sulphate breaks through in the production wells. This will require scale inhibitor squeezes from an intervention vessel to mitigate scale deposition.The wells were completed with long horizontal sections straddling multiple producing zones. This could potentially result in scale deposition severely reducing productivity if both formation water and injection water were to be produced simultaneously into the wells. Adding to the complexity, the perforation guns were left in the wellbore as part of the completion preventing any access to the perforation area. The distribution of scale inhibitor during a squeeze pumping operation could therefore be uneven leaving parts of the well poorly protected. In addition, the guns prevent physical removal of any type of materials in the well bore like asphaltenes, sand and scale which could plug off the perforations during a pumping operation with a well intervention tool; Wireline, coiled tubing, etc.. Injection water supplied from a host platform is used for pressure support of the reservoir. During the field development, the injection water was expected to contain mostly produced water reducing the scale potential considerably as it would have low sulphate content. When water injection started, very little produced water was being produced resulting in mostly seawater being available available for pressure support. Scale deposition in the well and around the well bore could therefore prove to be impossible to control unless reactions in the reservoir would reduce the scale potential or a reliable scale inhibitor squeeze method to mitigate scaling could be identified.This paper describes the joint effort of 6 different companies to identify the risks associated with the inorganic scaling during production and how a scale squeeze strategy was developed. The work included scale inhibitor selection, a geo-chemical study, and reservoir and near well bore simulations, sub-sea deployment selection, deciding on water chemistry and production monitoring and development of an overall management plan.

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“…This solids deposition can cause formation damage in the reservoir formation in addition to restriction/blockage in the wellbore area and in flow lines. Scale formation is due to three main mechanisms (Mackay et al, 2004): …”

mentioning

confidence: 99%

Impact of Fluid Distribution on Scale Inhibitor Squeeze Treatments in Pattern Floods and Fractured Wells

Rakhimov¹,

Vazquez²,

Mackay³

2010

Proceedings of SPE EUROPEC/EAGE Annual Conference and Exhibition

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The most common method for preventing scale formation in the well completions is by applying a scale inhibitor (SI) squeeze treatment. Near-well squeeze treatment models generally assume that the flow pattern around the well is radial. Although, this assumption may be reasonable in most scenarios, this paper investigates whether strictly non-radial flow patterns around the well have a major effect on the squeeze treatment.Sensitivity calculations were performed to identify the impact of waterflood patterns such as Two-Spot, Five-Spot, Line Drive, etc. on the squeeze treatment lifetime in vertical production wells. The second part of the project then continued the study of the impact of flow patterns in fractured vertical production wells. The outcome is that scale squeeze treatments initiated at the same watercut appear not to be impacted by the various flood patterns studied. However, investigation showed that fractured wells typically have longer squeeze lifetimes in comparison to non-fractured wells.Calculations show that for fractured wells, inhibitor adsorption on the face of the fracture itself has no impact on the treatment lifetime; the longevity of the squeeze is determined by the inhibitor adsorption in the matrix rock outside the fracture. The benefit a fracture brings is in terms of propagating the SI further from the well than would occur in an unfractured radial treatment. In the fractured well the inhibitor is then more greatly retarded by contact with rock over a greater distance than would occur in a matrix only radial treatment. Sensitivity calculations were performed to identify the impact of fracture length. IntroductionMineral scale precipitation is a significant problem in the oil and gas industry. Oilfield scales are inorganic crystalline deposits, which can precipitate in the reservoir formation, flow lines and/or surface facilities. This solids deposition can cause formation damage in the reservoir formation in addition to restriction/blockage in the wellbore area and in flow lines. Scale formation is due to three main mechanisms (Mackay et al., 2004):

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Integrated Risk Analysis for Scale Management in Deepwater Developments

Cited by 31 publications

References 20 publications

Scale Squeeze Placement Options in Subsea Multi-Lateral Horizontal Wells Completed With Sliding Sleeve Technology

Scale Squeeze Placement Options in Subsea Multi-Lateral Horizontal Wells Completed With Sliding Sleeve Technology

Selection of Scale Control Strategy on a Sub Sea Developed Field in the North Sea and How 6 Different Companies Contributed

Impact of Fluid Distribution on Scale Inhibitor Squeeze Treatments in Pattern Floods and Fractured Wells

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