Selection and Deployment of a Scale Inhibitor Squeeze Chemical for the BP 
Miller Field

Poynton, Neil; Kelly, Caroline; Fergusson, Alasdair; Ray, John J.; Webb, Philip; Strong, Allison

doi:10.2523/87466-ms

Cited by 5 publications

(1 citation statement)

References 2 publications

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“…PVS is typically applied by injection into the production well (“squeeze treatment”) that necessitates the cessation of oil production . Once production is restarted, PVS performance in the field suffers from weak adsorption onto the rock.…”

Section: Introductionmentioning

confidence: 99%

Controlled release of poly(vinyl sulfonate) scale inhibitor to extend reservoir treatment lifetime

Veisi

Johnson

Shafer‐Peltier

et al. 2018

J of Applied Polymer Sci

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Precipitate scale formation is a major issue for the oil industry, plugging equipment, and reservoirs and resulting in increased operational costs. Poly(vinyl sulfonate) (PVS) is often used as a scale inhibitor to prevent the formation of barium sulfate scale. However, PVS effectiveness is limited by its short lifetime in reservoir. In this article, PVS has been entrapped in polyelectrolyte complex nanoparticles (PECNPs), altering its charge and thus enabling improved adsorption on the rock surface. As the ionic strength of the surrounding brine increases, the PVS is then released from the PECNPs, making it available to inhibit scale formation gradually. Positively charged PECNPs were made using a combination of poly(ethyleneimine) (PEI) and PVS. After NPs optimization, static adsorption tests were performed, which confirm the nanoparticles' rapid and strong adsorption. An increase in the ionic strength of the displacing fluid was used to decompose the PECNPs structure and release the PVS into solution.

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Section: Introductionmentioning

confidence: 99%

Controlled release of poly(vinyl sulfonate) scale inhibitor to extend reservoir treatment lifetime

Veisi

Johnson

Shafer‐Peltier

et al. 2018

J of Applied Polymer Sci

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Assessment of Barite Scaling Potentials, Sulfate Removal Options, and Chemical Treating Strategies for the Tombua-Landana Development

Chen

Burnside

Widener

et al. 2007

International Symposium on Oilfield Chemistry

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fax 01-972-952-9435. AbstractThis paper discusses the development of a holistic water and scale management plan for a green-field development, which faces a new order of scale management challenges. Specifically, this paper documents a scale risk assessment and the development of a scale management plan during the frontend engineering design of the Tombua-Landana development in West Africa. The complexity of scale management is compounded by the presence of multiple reservoirs with very different scaling potentials and by the plans for produced water reinjection. The objective of the study was to define a complete scale management plan, which incorporates flexibility for future unknowns and minimizes the total cost of scale management, without over-capitalization.The Tombua-Landana field will produce from multiple reservoirs that incorporate several distinct formation waters with barium content as high as 800 mg/l and will require seawater injection for reservoir pressure maintenance from day one. Scaling tendency predictions were made for the major groups of formation water, both with and without seawater injection. In addition, a variety of produced water reinjection scenarios were investigated. This field study typifies several industry trends in inorganic scale management: (i) Deepwater West Africa is emerging as a new focus area for sulfate scaling; (ii) Deepwater economics require co-production of multiple reservoirs in order to reach threshold reserves and will necessitate the installation of major infrastructures; (iii) Economic and environmental drivers support the use of produced water reinjection, even though this exacerbates water compatibility problems and creates new challenges for reservoir monitoring.

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Holistic Approach for a Successful Scale Squeeze Treatment Using Core Flood Data from Other Reservoir

Sundramoorthy

Ibrahim

Nordin

et al. 2020

SPE International Conference and Exhibition on Formation Damage Control

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This paper describes field experience of designing a successful scale squeeze program for an oil well. This was done utilizing an adsorption isotherm derived from a core flood data from other reservoir. Correlation and reliability of the adsorption isotherm with actual field flow back data after squeeze treatment for a period of 18-month are given. Moreover, utilizing the knowledge generated, a bespoke multilayer adsorption isotherm was optimized for a treated well for more efficient squeeze design for next treatment. In order to achieve our objective, an adsorption isotherm from other reservoir core flood was first generated. With the knowledge not limited to current candidate well production rates, well properties, perforation height, number of zones and other essential parameters, a 18-month squeeze treatment program was designed. Water chemistry 18-month data was utilized to validate the scale squeeze design. An improved multilayer adsorption isotherm bespoke for this well was generated. In conjunction with flow-back production data, a scheduled sampling program and water analysis utilizing Inductively Coupled Plasma (ICP) for post treatment Scale Inhibitor (SI) residuals data was collected to validate the adsorption isotherm derived from other reservoir. As predicted by the model for post treatment monitoring, the SI residual concentration; back calculated from SI chemistry utilized for the treatment are found to have an excellent correlation with the adsorption isotherm derived from a different reservoir. Hence, the 18-month squeeze design derived from a different reservoir was a great success. The slight difference between real flow back data and the adsorption isotherm generated from other reservoir become a benchmark to derive an improved adsorption isotherm to optimize the scale inhibition protection than the current treatment. In summary, parameters such as mineralogy study, porosity, permeability, crude properties and dynamic scale loop (DSL) study are the utmost important information to be analyzed prior using other reservoir core flood data as reference. As results shown, these are the best way to generate squeeze design with limited information had in hand.

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Selection and Deployment of a Scale Inhibitor Squeeze Chemical for the BP Miller Field

Cited by 5 publications

References 2 publications

Controlled release of poly(vinyl sulfonate) scale inhibitor to extend reservoir treatment lifetime

Controlled release of poly(vinyl sulfonate) scale inhibitor to extend reservoir treatment lifetime

Assessment of Barite Scaling Potentials, Sulfate Removal Options, and Chemical Treating Strategies for the Tombua-Landana Development

Holistic Approach for a Successful Scale Squeeze Treatment Using Core Flood Data from Other Reservoir

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