Magnus Scale Inhibitor Squeeze Treatments - A Case History

Ravenscroft, Peter; Cowie, L.G.; Smith, P.S.

doi:10.2118/36612-ms

Cited by 33 publications

(5 citation statements)

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“…4,5,6,7,8,9,10 Where the completed interval is longer, it is often necessary to enter the well and use coiled tubing to spot the inhibitor or use another method of fluid diversion. 11,12 The design of such treatments has focused on the use of placement software which allows treatment volumes to be evaluated and economic evaluation of the treatment life versus cost to be carried out. 13,14,15 The frequency of the inhibitor squeezes will depend on the Minimum Inhibitor Concentration (MIC) needed to inhibit scale formation.…”

Section: Scale Inhibitor Squeeze Treatmentsmentioning

confidence: 99%

“…Reveres the injection sequence AFD/base oil followed by the emulsion solution (simulated backflow in the well) 11. Flood core with crude oil to Swi at reservoir temperature 12 17. The core will be examined by environmental scanning electron microscopy prior to/after chemical treatment and permeability data assessed Brine and oil permeability measured while carrying out both types of floods are presented in Tables 6 and 7.…”

Section: Well Typementioning

confidence: 99%

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Coreflood Studies to Examine Potential Application of Novel Scale Inhibitor Products to Minimise Intervention During Field Life Cycle

Jordan¹,

Collins²,

Gyani³

et al. 2002

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractWith the development of more and more subsea fields, the challenge for scale inhibitor squeeze treatments is to reduce intervention frequency by extending squeeze treatment lifetime whilst concomitantly reducing any potential damage in both low water cut and higher water cut wells. This paper discusses the technical problems and examines new technologies for treatment of such production wells through their life cycle.Scale control technology available to control scale formation within the reservoir and near-wellbore area of production wells will be outlined with a focus on the current developing technology to control scale within low water cut wells. Moreover, it is shown that the new technical area of emulsion scale inhibitor delivery systems, originally designed to control scale within low water cut wells, has application in both low and high water cut wells This study assists in developing an understanding of the mechanism of interaction of emulsion-based products; in particular the impact of the level of water saturation within the core system. In addition, it demonstrates that the emulsion particles are retained in the core matrix during both crude and brine flowback. This paper indicates that the emulsion product offers the potential for extremely long squeeze lifetimes with minimal damage in oil production wells with rising water cut. It also demonstrates how different technologies have their own place in the life cycle of a production well.

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Section: Scale Inhibitor Squeeze Treatmentsmentioning

confidence: 99%

Section: Well Typementioning

confidence: 99%

Coreflood Studies to Examine Potential Application of Novel Scale Inhibitor Products to Minimise Intervention During Field Life Cycle

Jordan¹,

Collins²,

Gyani³

et al. 2002

All Days

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“…The causes for reduction can come from wetting alteration/water blocking at water sensitive reservoirs (Jordan et al 1998;Graham et al 1999;Poynton et al 2000;Guan et al 2003) and/or poor well cleanup for wells with poor lifting (Ravenscroft et al 1996;Collins 1997;Graham et al 2002;Wat et al 2001;Guan and Rohde 2009). The application of nonaqueous scale inhibitors has been proposed to address some of these concerns, many types have been reported ranging from invert emulsion-type technologies (Lawless and Smith 1999;Collins et al 2000;Smith et al 2000), microemulsions (Miles et al 2003), encapsulated products Collins 1997) amphiphilic solvent systems, (Collins et al 1998;Guan et al 2006;) and oil-miscible materials (Wat et al 1999;Wat et al 1998a;Wat et al 1998b).…”

Section: Introductionmentioning

confidence: 99%

The Development of a Water-Free and Light Oil-Soluble Scale Squeeze Inhibitor Meeting Environmental Requirements

Gao¹,

Grinrod²,

Rohde³

2010

Proceedings of SPE International Conference on Oilfield Scale

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The major technical drive for introducing oil-soluble scale inhibitors is to overcome the potential oil production decline caused by conventional aqueous-based scale-inhibitor squeeze packages in situations where relative permeability effects, water blocking, fluid lifting or deep penetration into the near well formation are of major concern. The particular requirement for a true oil-soluble scale inhibitor in a low-pressure reservoir with wells having lifting problems is that the package density needs to be lower than that of water. Additionally in certain geographical regions like Norway, the environmental regulations are very tight.This paper illustrates the development of a true oil-soluble scale-inhibitor package with zero water content. The product is light with a density of much less than 1 g/cm 3 and its environmental category in Norway is yellow. The successful product is the result of numerous formulation trials. Details of chemistry selection and the formulation development will be discussed in the paper. Following the success in formulation, the product has undergone stability, solubility and core flood testing to further evaluate its suitability as a squeeze inhibitor. The core flood results show an extended scale inhibitor return during the post flush; the scale inhibitor is still well above MIC (Minimal Inhibitor Concentration) for > 700 pore volume (PV) of post flush. The possible mechanism for this squeeze lifetime extension is discussed in the paper. No formation damage was observed during the reservoir condition multiphase core flood indicating the nondamaging nature of the true oil-soluble product. Based on this successful development, a field trial is planned.This paper discloses the development of a true oil-soluble scale-inhibitor formula that is water free, low density and in the yellow environmental category, which can be applied downhole as scale squeeze inhibitor providing a prolonged squeeze lifetime.

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“…At present there is little literature relating to the use of viscosified solutions for scale inhibitor treatments, other than for temporary diversion. [9][10][11][12][13][14][15][16] Although viscous treatments are not usually associated with scale inhibitor treatments, the viscosity of the main chemical injection pill (typically 10 -20 % scale inhibitor dissolved in sea water) will normally be higher than that of the overflush (seawater). Moreover, in other less conventional treatments involving higher viscosity main treatments, including for example emulsified chemical treatments, the overflush used is generally a much lower viscosity fluid (diesel).…”

Section: Squeeze Placement In Horizontal Wells -Introductionmentioning

confidence: 99%

Potential Application of Viscosified Treatments for Improved Bullhead Scale Inhibitor Placement in Long Horizontal Wells – A Theoretical and Laboratory Examination

Stalker¹,

Graham²,

Oliphant

et al. 2004

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractScale control in subsea horizontal wells is recognised as a particular technical and economic challenge, especially if effective chemical placement cannot be achieved through conventional bullhead squeeze treatments.When long horizontal or highly deviated wells produce from areas of high permeability contrast and high wellbore crossflow, coil tubing operations can often be the only manner in which effective chemical placement can be guaranteed. The costs associated with such treatments are extremely expensive and often prohibitive when compared with conventional bullhead operations. Such aspects were recognized as a particular risk for successful chemical treatments in the Draugen field, operated by Norske Shell. The Draugen field is located in the environmentally sensitive Haltenbank area of the Norwegian Continental Shelf, and produces oil from 6 horizontal (>1,000 ft.) wells completed with pre-packed resin screens to achieve effective sand exclusion. A moderate barium sulphate scaling potential was anticipated following sea water breakthrough requiring squeeze treatments. In order to improve chemical placement in this field and reduce the requirement for coil tubing interventions for squeeze treatment, work was initiated to investigate the potential use of viscosified fluids to improve downhole chemical placement.A range of viscosifying agents was selected following detailed literature review based upon the rheology that was expected to lead to improved chemical placement. This included common water control additives such as xanthan and HEC (hydroxyethylcellulose) biopolymers and formulated water in oil (WIO) or oil in water (OIW) emulsions. Various formulations were selected that would either remain stable (higher viscosity) or to break (to low viscosity) at reservoir temperature. It should be noted, however, that viscosities were selected far below those normally applied in water shut off or multi-stage chemical diversion treatments. A series of formation damage core flood experiments has been conducted using analogue cores to ensure that the various formulations were non damaging, allowing rapid recovery to pre-treatment effective oil permeability. In addition, more sophisticated core flooding equipment was designed to examine chemical placement and recovery in zones of different permeability.In summary, this paper presents a literature review describing the properties of different viscosifying agents and their potential applicability for improving bullhead scale inhibitor squeeze treatments. Core flood studies on viscosifying agents with selected rheological properties will then be presented to demonstrate the potential advantages of such applications for improved chemical placement by bullhead application in horizontal wells.

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Magnus Scale Inhibitor Squeeze Treatments - A Case History

Cited by 33 publications

References 0 publications

Coreflood Studies to Examine Potential Application of Novel Scale Inhibitor Products to Minimise Intervention During Field Life Cycle

Coreflood Studies to Examine Potential Application of Novel Scale Inhibitor Products to Minimise Intervention During Field Life Cycle

The Development of a Water-Free and Light Oil-Soluble Scale Squeeze Inhibitor Meeting Environmental Requirements

Potential Application of Viscosified Treatments for Improved Bullhead Scale Inhibitor Placement in Long Horizontal Wells – A Theoretical and Laboratory Examination

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