High-Density Monomer System for Formation Consolidation/Water Shutoff Applications

Eoff, Larry; Funkhouser, Gary P.; Cowan, Mike

doi:10.2118/50760-ms

Cited by 8 publications

(3 citation statements)

References 3 publications

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“…(For complete results and experiment details, consult the original version of this paper. 5 ) Monomer solutions prepared in seawater weighted with NaCl were more amenable to initiation with hydroperoxide. In this case, the fluid did not have to be deoxygenated for a useful gel time.…”

Section: Resultsmentioning

confidence: 99%

High-Density Monomer System for Formation Consolidation/Water-Shutoff Applications

Eoff

Funkhouser

Cowan

2001

SPE Production &Amp; Facilities

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This paper describes an in-situ polymerizable organic monomer hydrogel system for formation consolidation during deepwater drilling applications in which a water-soluble vinyl monomer solution is polymerized in-situ to seal and consolidate unstable geological zones. In deepwater wells, shallow zones may have pore pressures close to parting pressures. In these situations, lost circulation or flowing zones can be difficult to control and can lead to a complete loss of the well.Hydroperoxide and azo initiators are used for polymerizing solutions of 2-hydroxyethyl acrylate monomer in aqueous solutions of synthetic seawater, sodium chloride (NaCl), calcium chloride (CaCl2), calcium bromide (CaBr2), and zinc bromide (ZnBr2), with densities from 8.6 to 17.5 lbm/gal. These monomer solutions undergo controlled polymerizations in the formation to yield a crosslinked hydrogel matrix that can withstand high differential pressures. A similar monomer system has been used for water-shutoff applications but had never been formulated in heavy brines or used in the cool temperatures (50 to 60°F) typical of the shallow water-flow zones. The use of a high-density hydrogel for consolidation purposes would be an advantage in shallow waterflow zones because the gelant solution of the hydrogel could be spotted over, and allowed to flow into, the problem zone where the gelant flow is driven by the hydrostatic pressure of the treatment fluid. This process enables the use of the monomer system in wells where high-pressure injection of the treatment fluid into the formation is not an option.This article describes the hydrogel system's development, including gel-time curves and compressive strengths of consolidated sandpacks, and discusses factors affecting the performance and application of the system.

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Section: Resultsmentioning

confidence: 99%

High-Density Monomer System for Formation Consolidation/Water-Shutoff Applications

Eoff

Funkhouser

Cowan

2001

SPE Production &Amp; Facilities

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“…[8][9][10][11][12][13] The system is water-thin during the jetting operation and is activated by an azo-initiator, which creates a sealant with ringing-gel properties (Tables 4 and 5). The monomer system alleviates plugging and filtration problems that occur during matrix penetration with other high molecular weight polymer systems, such as polyacrylamide gels.…”

Section: Hydrajetting Fluid/sealantmentioning

confidence: 99%

Improved Zonal Isolation Through the Use of Sealants Before Primary Cementing Operations

East¹,

McIntyre²,

Tucker³

et al. 2000

Proceedings of IADC/SPE Drilling Conference

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TX 75083-3836, U.S.A., fax 01-972-952-9435.References at the end of the paper. AbstractZonal isolation in injection, geothermal, and producing wells is critical both to reservoir evaluation efforts and to operations, but often, cementing between the casing and the wellbore is still the only method of zonal isolation performed in many wells. Although zonal isolation and well diagnostics techniques have improved, primary cementing techniques may be inadequate for some reservoir conditions, resulting in undesirable water flows, gas flows, or both. If zonal isolation is inadequate, then expensive, often complicated remedial cementing work will be needed for improved well and reservoir performance.If conformance technology is applied during the drilling phase, it can improve the performance of primary cementing processes, making them safe and economical. Conformance treatments seal problem intervals before primary cementing, thereby alleviating potential well-control problems. These treatments also help ensure successful primary cementing operations and prevent isolation loss caused by the casing expanding and contracting during production-pressure cycles. The formation itself, rather that the cement sheath alone, becomes the zonal isolation mechanism.During the drilling phase, zonal isolation requires the use of coiled tubing, a hydrajetting device, a depth-correlation device, and a sealant. The sealant should be water-thin during placement, and should become an elastic polymer only after it is set in place. This zonal isolation technique requires an understanding of (1) depth correlation to openhole logs, through the use of mud-pulse technology, and (2) hydrajetting tech-niques that remove mud filter cake while placing the sealant. This paper presents examples of this technique for a 7 7 /8-in. wellbore and a 13 ½-in. wellbore.

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“…Eoff et al (2011) developed a water‐dispersible, aliphatic epoxy‐resin system (WDR) with specific aims to plug fractures/vugs, reduce formation permeability, and artificially increase formation fracture gradients. The system turned out to be capable of significantly enhancing the compressive strength of cores and sandpacks, and decreasing the permeability of treated cores (Eoff and Funkhouser, 1999; Ng and Adisa, 1997). Huang et al (2018) synthesized a nanoscale acrylic resin/nano‐SiO 2 composite (AR/SiO 2 ) with a core‐shell structure for water‐based drilling fluid (WBM), which can efficiently plug shale pores, suppress fluid invasion and improve wellbore stability in the shale gas drilling process.…”

Section: Introductionmentioning

confidence: 99%

Seepage Characteristics of Emulsion with Phase Transition Behaviors

Jiang

Sun³

et al. 2020

J Surfact & Detergents

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Petroleum resins have excellent thermal tolerance and selective plugging capability. As the environment temperature exceeds their softening point, petroleum resins transform from a solid into a viscous Newton fluid, accompanied by the transformation of the system from particle dispersoid to emulsion. The presence of phase transition decides that the seepage regularity and plugging characteristics of petroleum resins are different from either particle dispersoid or emulsion. Herein, rheological measurements and physical model flooding experiments were performed to investigate the injection and plugging performance of petroleum resins. A correlation chart of the injection pressure, formation permeability, and the ratio of resin particle size to pore diameter is established. The dispersoid is demonstrated to present good injectivity when the ratio of the resin particle size to the pore‐throat diameter of the porous media is lower than 0.35. Moreover, when the environment temperature is lower than or around the petroleum resin softening point, the injection performance of the dispersoid is not affected by temperature. Comparably, while the environment temperature is 30 °C higher than the resin softening point, the injection pressure increases due to phase transition. As indicated by the plugging experiment, the presented petroleum resin dispersoid plugging agent manifests excellent performance even in the case that the permeability of water‐channeling paths is up to 20 μm2, reaching a water plugging efficiency of over 85%. For water‐channeling fractures with widths of 0.05–0.5 mm, the plugging pressure gradient can exceed 5 MPa m−1. As suggested by combined analysis of injection and plugging performance, the disperse system should be optimized in accordance with the formation condition during field practice. Specifically, the ratio of the resin particle size to the formation pore diameter should be kept lower than 0.35, while the softening point of the petroleum resin should be 10–20 °C lower than the formation temperature.

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High-Density Monomer System for Formation Consolidation/Water Shutoff Applications

Abstract: This paper was prepared for presentation at the International Symposium on Oilfield Chemistry held in Houston, TX, 16-19 February 1999.

Cited by 8 publications

References 3 publications

High-Density Monomer System for Formation Consolidation/Water-Shutoff Applications

High-Density Monomer System for Formation Consolidation/Water-Shutoff Applications

Improved Zonal Isolation Through the Use of Sealants Before Primary Cementing Operations

Seepage Characteristics of Emulsion with Phase Transition Behaviors

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