New Insights into Proppant-Pack Damage Due to Infiltration of Formation Fines

Blauch, Matt; Weaver, Jimmie D.; Parker, Mark A.; Todd, Brad; Glover, M.

doi:10.2118/56833-ms

Cited by 41 publications

(4 citation statements)

References 18 publications

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“…Instead of allowing formation particulates to migrate through the proppant pack, previous studies have shown that fracture conductivity (and hence, well productivity) can be enhanced and extended by effectively preventing these formation fines from invading the proppant pack (Blauch et al 1999;Lehman et al 2003;Dusterhoft et al 2004). Fines migration should be prevented (or stopped) far away from the wellbore, rather than allowing or waiting for the damage of the formation matrix or proppant pack to occur nearer to the wellbore.…”

Section: Discussionmentioning

confidence: 99%

Maintaining Well Productivity Through Controlling Fines Migration and Scale Formation

Stanciu

Nguyen

et al. 2015

Europec 2015

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The intrusion of formation fines and formation sand grains into the proppant pack drastically reduces the conductivity of propped fractures, which can negatively impact well production. This paper describes the development and field treatments using a new form of surface modification agent (SMA) that is a low-tackiness surface modification agent (LTSMA) that can be applied during primary hydraulic fracturing or remedial treatments of propped fractures. Studies were conducted to demonstrate the mechanisms by which this LTSMA controls migration and intrusion of formation sand and fines into the proppant pack, while inhibiting scale formation in the treated pack.Molecular modeling data on the LTSMA suggests that both the polymer backbones and the hydrophobic chains on the polymers are responsible for its reduced tackiness to the treatment equipment and significant scale inhibition ability. Once coated on the proppant as part of hydraulic fracturing treatment, or injected into the proppant pack and formation matrix surrounding the fractures, this LTSMA forms a thin film on the particulates, covering and anchoring the particulates in place. This LTSMA coating also forms a hydrophobic film on the particulate surfaces, inhibiting chemical reactions that lead to scale formation in the pack matrix and subsequent productivity losses.Laboratory experiments using packed beds of proppant, formation sand grains, and various fines were performed to simulate proppant pack conditions and formation fines before and after remedial treatments. Experimental results indicate that treatments with this particular LTSMA effectively control the migration of formation fines into proppant packs and successfully prevent the buildup of scale in various sand packs to maintain the fluid flow paths. No pressure buildup was noticed, opposed to the proppant that was not treated with the LTSMA, for which severe scaling had occurred by 24 hours, leading to an exponential increase in pressure drop across the proppant pack. Examination with scanning electron microscopy analysis clearly demonstrated that no scale was formed in the pore spaces between the treated proppant grains compared to a massive buildup of scale on the proppant particles and in their pore spaces when not coated with the LTSMA.In addition to remedial treatments, LTSMA treatment fluid can be applied while treating formations following an acidizing treatment, during treatment of formations before a high-rate water pack or frac-pack treatment, or as part of a pad fluid to treat the fracture faces before placement of proppant into a fracture and/or a screen annulus.

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Section: Discussionmentioning

confidence: 99%

Maintaining Well Productivity Through Controlling Fines Migration and Scale Formation

Stanciu

Nguyen

et al. 2015

Europec 2015

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“…Instead of allowing formation particulates to migrate through the proppant pack, recent studies have shown that fracture conductivity (and hence, well productivity) can be enhanced and prolonged by effectively preventing these formation fines from invading the proppant pack (Blauch et al 1999;Lehman et al 2003;Dusterhoft et al 2004). Fines migration should be prevented far away from the wellbore, rather than allowing or waiting for the damage of the formation matrix or proppant pack to occur.…”

Section: Discussionmentioning

confidence: 99%

Maintain Well Productivity Through Inhibiting Scale Formation and Controlling Fines Migration

Nguyen

Vasquez

Weaver

et al. 2010

SPE Asia Pacific Oil and Gas Conference and Exhibition

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Migration of fine particulates and/or scale formation is known to plug up etched channels or pore spaces in proppant packs, causing production decline in wells that have been acidized or completed with high-rate water packs or frac-packs. The removal of such damage caused by plugging is only a temporary solution if the source of the plugging material is not mitigated. This paper presents the results of a series of laboratory tests aimed at demonstrating and quantifying the performance of a treatment fluid for stabilizing formation fines, inhibiting scale formation, and keeping flow channels open through damaged proppant packs after production has been restored.Packed beds of proppant and formation sands were used to simulate frac-pack conditions before and after remedial treatments. The treatment fluid was comprised of a salt-free, aqueous-based solution containing an environmental friendly clay-swelling inhibitor and a water-based agglomerating agent (WBAA). The results show that this WBAA system is applicable to most types of formations, including sandstones, carbonates, and coals. Once injected into the proppant pack and formation matrix, WBAA forms a thin film on the particulates, covering and anchoring them in place, without plugging pore throats. This thin coating does not harden, but remains flexible, allowing the treated formation to withstand high shear stress during high production flow rates. WBAA coating forms hydrophobic film-encapsulating particulate surfaces, inhibiting chemical reactions that lead to scale formation in the pack matrix.The experimental results show that WBAA treatments effectively mitigate the buildup of scale in various sand packs and successfully control the migration of formation fines into proppant packs to maintain well production.

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“…In one test, a silica-flour pack was placed against a 20/40-mesh fracturing sand pack (Blauch et al 1999). Water was flowed through the packs to test for fines migration of the silica flour into the proppant pack.…”

Section: Choice Of Fracturing Fluids and Additivesmentioning

confidence: 99%

Viking Stimulation: Case History

Fyten

Taylor

Price

2015

Day 3 Thu, October 22, 2015

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This paper presents case history results documenting the impact of changes to oil and water production in the Viking formation. This body of work applies in general to stimulation of the Viking as well and potentially other formations with high clay content. By understanding which variables have had the most impact on Viking production, it is possible to more effectively design future stimulation treatments. Some areas that previously lagged in production have now become the best producing Viking assets.The areas studied were Red Water, Plato, and Dodsland. The wells studied were drilled horizontally using cemented casing. Hydrajet perforating was used for each fracture stage. The fracturing treatments were pumped through coiled tubing at a typical rate of 1.5 m 3 /min, or less using inflatable packers above and below the desired set of perforations to provide isolation. Typical fracturing treatments used 7 tonnes of 16/30 proppant and were placed using a borate crosslinked guar fluid system.The primary design changes that have led to these improvements in production include the following:

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New Insights into Proppant-Pack Damage Due to Infiltration of Formation Fines

Abstract: This paper was prepared for presentation at the 1999 SPE Annual Technical Conference and Exhibition held in Houston, Texas, 3–6 October 1999.

Cited by 41 publications

References 18 publications

Maintaining Well Productivity Through Controlling Fines Migration and Scale Formation

Maintaining Well Productivity Through Controlling Fines Migration and Scale Formation

Maintain Well Productivity Through Inhibiting Scale Formation and Controlling Fines Migration

Viking Stimulation: Case History

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