Use of Inhibitors for Scale Control in Brine-Producing Gas and Oil Wells

Rogers, L.A.; Varughese, K.; Prestwich, S.M.; Waggett, G.G.; Salimi, Mozaffar; Oddo, J.E.; Street, Emma; Tomson, Mason B.

doi:10.2118/15457-pa

Cited by 23 publications

(6 citation statements)

References 4 publications

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“…Phase I phosphonate return corresponds to the residual phosphonate that does not attached to the solid phase and returns in 3 pore volumes; phase II return corresponds to the dissolution from a high solubility solid phase and phase III return corresponds to the dissolution from a crystalline solubility phase (2) For DTPMP, phase II return can be characterized with a solubility product, pK sp = 52.4 -52.6 by assuming a stoichiometry of Ca 3 H 4 DTPMP; and phase III return corresponds to the dissolution from a crystalline solubility solid phase (pK sp = 53.3 -…”

Section: Discussionmentioning

confidence: 99%

“…1,2 More recent papers have advanced the knowledge of inhibitor reactions under various production conditions. [3][4][5][6][7][8][9][10][11][12] The primary conclusions from several previous studies of NTMP(aminotri(methylene phosphonic acid))calcite reaction are [13][14][15][16] : (1) The extent of NTMP retention by carbonate-rich formation rock is limited by the amount of calcite that can dissolve prior to inhibitor-induced surface poisoning; (2) Calcite-surface poisoning effect is observed after approximately 20 molecular layers of phosphonate surface coverage that retards further calcite dissolution; (3) The consequence of retarded calcite dissolution is that less basic ion, − 2 3 CO , is released into solution, leaving the solution more acidic; therefore, more soluble calcium phosphonate solid phases form.…”

Section: Introductionmentioning

confidence: 99%

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Mechanistic Understanding of Rock/Phosphonate Interactions and the Effect of Metal Ions on Inhibitor Retention

Tomson¹,

Kan²,

Fu³

et al. 2006

Proceedings of SPE International Oilfield Scale Symposium

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper discusses the effects of Ca 2+ , Mg 2+ , and Fe 2+ on inhibitor retention and release. Better understanding of phosphonate reactions during inhibitor squeeze treatments has direct implication on how to design and improve scale inhibitor squeeze treatments for optimum scale control. Putting various amounts of metal ions in the inhibitor pill adds another degree of freedom in squeeze design, especially in controlling return concentrations and squeeze life.Phosphonate reactions during squeeze treatments involve a series of self-regulating reactions with calcite and other minerals. However, excess calcite does not improve the retention of phosphonate due to the surface poisoning effect of Ca 2+ . The squeeze can be designed so that maximum squeeze life is achieved by forming a low solubility phase in the formation. Addition of Ca 2+ , Mg 2+ , and Fe 2+ in the pill solution at 0.1 to 1 molar ratios significantly improves the retention of phosphonate. Alternatively, these metal ions can be dissolved from the formation while an acidic inhibitor pill is in contact with the formation minerals. Both BHPMP and DTPMP returns were significantly extended by the addition of metal ions, e.g. Ca 2+ and Fe 2+ . The addition of Mg 2+ may increase the long-term return concentration, which is important for some wells where a higher inhibitor return concentration is needed.The laboratory squeeze simulations were compared to two field return data obtained from squeeze treatments performed on two wells located in a sandstone reservoir in Saudi Arabia. The sandstone formation contains significant amounts of ironbearing minerals.

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Section: Discussionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Mechanistic Understanding of Rock/Phosphonate Interactions and the Effect of Metal Ions on Inhibitor Retention

Tomson¹,

Kan²,

Fu³

et al. 2006

Proceedings of SPE International Oilfield Scale Symposium

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“…With this method, the scale-control options include the following: limiting production so that the drop in pressure is not sufficient to induce precipitation; injecting trace concentration of inhibitors in the surface equipment; injecting trace concentrations of inhibitors downwell to pressurize the fluid above the flash point; and squeezing inhibitor into the formation so that the inhibitor will be released slowly when production begins [2,12,43]. In addition, the use of downhole pumps can prevent scaling within the wellbore.…”

Section: Calcium Carbonatementioning

confidence: 99%

Geothermal produced fluids: Characteristics, treatment technologies, and management options

Finster

Clark

Schroeder

et al. 2015

Renewable and Sustainable Energy Reviews

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a b s t r a c tGeothermal power plants use geothermal fluids as a resource and create waste residuals as part of the power generation process. Both the geofluid resource and waste stream are considered produced fluids. The chemical and physical nature of produced fluids can have a major impact on the geothermal power industry and influence the feasibility of power development, exploration approaches, plant design, operating practices, and reuse/disposal of residuals. In general, produced fluids include anything that comes out of a geothermal field and must subsequently be managed on the surface. These fluids vary greatly, depending on the reservoir being harnessed, plant design, and life cycle stage in which the fluid exists, but generally include water and fluids used to drill wells, fluids used to stimulate wells in enhanced geothermal systems, and makeup and/or cooling water used during operation of a power plant. Additional geothermal-related produced fluids include many substances that are similar to waste streams from the oil and gas industry, such as scale, flash tank solids, precipitated solids from brine treatment, hydrogen sulfide, and cooling-tower-related waste.This review paper aims to provide baseline knowledge on specific technologies and technology areas associated with geothermal power production. Specifically, this research focused on management techniques related to fluids produced and used during the operational stage of a power plant, the vast majority of which are employed in the generation of electricity. The general characteristics of produced fluids are discussed. Constituents of interest that tend to drive the selection of treatment technologies are described, including total dissolved solids, noncondensable gases, scale, corrosion, silicon dioxide, metal sulfides, calcium carbonate, metals, and naturally occurring radioactive material. Management options for produced fluids that require additional treatment for these constituents are also discussed, including surface disposal; reuse/recycle; agricultural, industrial, and domestic uses; mineral extraction and recovery; and solid waste handling.

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“…High concentrations of iron have in the past been tied to problems with scale inhibitor treatments. 5 It has been cited by a number of authors as a potential source of damage in many chemical treatments. 6,7 In addition to the residual concentration of iron after the acid treatment, core flood studies by Company A had shown iron values of > 900 mg/L would be generated through the dissolution of the normal iron minerals as a result of the treatment chemical.…”

Section: Postmortemmentioning

confidence: 99%

Iron Phosphonate Stabilized Emulsion And Formation Damage During An Adsorption Squeeze Treatment For Scale Mitigation

Lynn

Nasr-El-Din

Hashem

2002

Proceedings of International Symposium and Exhibition on Formation Damage Control

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractStarting in 1997, calcium carbonate scale was found on gravel pack screens and production equipment in a shallow Saudi Arabian sandstone formation. A campaign of scale control measures was initiated using several types of treatment programs. These programs included forced precipitation, adsorption squeezes, and encapsulated scale inhibitors. These methods have been well described in the literature.

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Use of Inhibitors for Scale Control in Brine-Producing Gas and Oil Wells

Cited by 23 publications

References 4 publications

Mechanistic Understanding of Rock/Phosphonate Interactions and the Effect of Metal Ions on Inhibitor Retention

Mechanistic Understanding of Rock/Phosphonate Interactions and the Effect of Metal Ions on Inhibitor Retention

Geothermal produced fluids: Characteristics, treatment technologies, and management options

Iron Phosphonate Stabilized Emulsion And Formation Damage During An Adsorption Squeeze Treatment For Scale Mitigation

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