Advanced Residue-Free Fracturing Fluid with Improved Friction Reduction and Exceptional Cleanup Properties

Singh, Dipti; Russell, A.P.; Schnoor, Eli; Inyang, Ubong

doi:10.2118/174178-ms

Cited by 6 publications

(1 citation statement)

References 14 publications

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“…7 shows that the addition of surfactant and SA resulted in a 4% decrease in friction reduction. However, 68% friction reduction was still sufficient for the field operations compared to the guar-based fluid used in hydraulic fracturing applications (Singh et al 2015). …”

Section: Friction Reductionmentioning

confidence: 99%

A Research Model for Using Sacrificial Agents to Enhance Surfactant Performance in Liquids Rich Shale Reservoirs

2016

SPE Improved Oil Recovery Conference

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Post-fracturing production data analysis indicates stimulation of some west Texas wells with surfactant additives did not enhance production as high as expected. Analysis of flowback and produced water for surfactant residues revealed 99% of surfactant was retained inside wells (Rane and Xu 2015). This indicates surfactant plating out on rock in the near-wellbore (NWB) region, restricting travel deeper into the reservoir, which compromises well performance. This study presents a sacrificial agent (SA) to cover rock surface near the wellbore, allowing surfactant to penetrate the formation.Literature precedent exists that polyelectrolyte (PET)-based SAs could significantly reduce surfactant adsorption not only onto a variety of outcrop minerals (Carlpool dolomite, calcite, kaolinite, Berea sandstone, Indiana limestone, etc.) and metal oxide nanoparticles, but also unconventional shale formulations in which surface area can be up to 700 m 2 /g. In this study, the adsorptions of surfactant and SA to proppants were first examined. Results indicate no adsorption was observed to proppant for both surfactants and PET-based SAs. SAs (0.5 to 1 gal/1,000 gal (gpt)) were then injected with surfactant (1 to 3 gpt) at an appropriate ratio into column-packed shale formulations (primarily composed of calcite, dolomite, quartz, illite, pyrite, and plagioclase feldspar) to investigate its effectiveness in controlling surfactant retention caused by adsorption. Laboratory testing revealed injection of 3 gpt mixture of surfactant and SA has a similar adsorption profile (surface tension as a function of time) as 3 gpt surfactant alone based on the dynamic surface tension measurement. Notably, the addition of SAs resulted in lower surface tension and enhanced hydrocarbon solubility; and thus, an improved oil recovery by surfactant was achieved as evidenced by the oil recovery tests. Additionally, 68% friction reduction of the fracturing fluid with surfactant and SA was sufficient for the field operation compared to the guar-based fluid used in the hydraulic fracturing applications.As a result of the laboratory findings, field trials were executed on a three well pad in the Permian basin (PB). For the first 30 days oil and gas production appeared to be significantly higher than the average production from offset wells in the same area that were previously fractured with the same surfactant.

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Section: Friction Reductionmentioning

confidence: 99%

A Research Model for Using Sacrificial Agents to Enhance Surfactant Performance in Liquids Rich Shale Reservoirs

2016

SPE Improved Oil Recovery Conference

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Carboxymethylcellulose a Cost Effective Alternative to Guar, CMHPG and Surfactant-Based Fluid Systems

Azizov¹,

Quintero²,

Saxton³

et al. 2015

Day 2 Wed, October 21, 2015

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The first fracture treatment using crosslinked guar was performed in 1969. Since then guar and its derivative polymers have dominated hydraulic fracturing. But because of volatility and supply issues with guar gum that have surfaced during peak activity years, industry has turned to alternatives. One of those is Carboxymethylcellulose (CMC) that just like guar comes from food industry. CMC is also used in pharmaceuticals as a thickening agent, and in the oil and gas industry as an ingredient in drilling mud. Use in hydraulic fracturing is surprisingly limited. The objective of this paper is to demonstrate successful cases of CMC based treatments over traditional guar and surfactant based treatments used in linear and foamed applications. This paper presents several cases from treatments performed on formations such as Cardium, Montney, Belly River, and Dunvegan. Presented production comparison will demonstrate that wells treated with CMC based hydraulic fracturing fluid system yield similar performance when compared to wells treated with guar, its derivatives, and surfactant based fluid systems. Cost savings realized when switching to CMC based fluid systems are also discussed in the paper. Laboratory tests described, performed, and results shared to demonstrate the performance of CMC compared to guar, Carboxymethylhydroxypropyl guar (CMHPG), and surfactant systems. The paper attempts to provide degree of confidence to the operators looking for cleaner alternatives to industry established fluid systems and shows that these can be successfully implemented without additional risk or cost.

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A Comparative Study on Operational Performance of Advanced Low Friction Residue-Free Fracturing Fluid versus Conventional Fluid Systems

Schnoor

Singh

Russell

et al. 2016

SPE International Conference and Exhibition on Formation Damage Control

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This paper compares the operational performance of a newly developed low friction, nearly residue-free (LF-RF) fluid system to a conventional derivatized guar-based fluid system and an existing nearly residue-free (RF) fluid system. The RF system has provided increased well production in numerous applications; however, the system requires lower treating rates due to increased friction. During recent field operations, the LF-RF system surpassed previous treating rates, which were previously unattainable, while maintaining maximum fluid cleanup. The friction responses between the RF, LF-RF, and derivatized guar-based fluids were assessed through quantitative analysis of surface treating pressures. All comparisons between fluid systems were made between wells on the same pad with the same completion method. The wells used in this study were all located in the Denver/Julesburg (DJ) basin and pumped using the same hybrid treatment design. Along with field data, laboratory testing was conducted to compare the viscosity profiles of the LF-RF and derivatized guar-based fluid, which were used in the field. Guar-based fracturing fluids have long been the industry standard. However, these fluids produce insoluble residue on breaking, which can reduce proppant pack conductivity and adversely affect well production. The RF fluid is an ultraclean, proven system, which has been successfully pumped in more than 16,000 stages. This fluid leaves virtually no insoluble residue, which has led to increased production from unconventional reservoirs. Yet, the RF fluid tends to exhibit increased treating pressures compared to guar-based fluids, which might require lower treating rates during operations. Additionally, a higher gel loading is necessary with the RF fluid to achieve comparable viscosities to the guar-based fluids. The new LF-RF fluid system retains all the beneficial cleanup properties of the RF system, while providing improved friction reduction. Intervals pumped with the LF-RF fluid provided lower treating pressures compared to those pumped with RF fluid, even at increased treating rates. With the improved friction reduction verified, the LF-RF fluid was pumped alongside a derivatized guar-based system at 80 bbl/min; a rate well beyond that which the RF fluid is generally pumped. The LF-RF fluid successfully placed all proppant and had similar treating pressures to the derivatized guar-based system toward the heel of the well. The LF-RF fluid was also able to accomplish this using a gel loading comparable to the derivatized guar-based system. Through quantitative analysis of the surface treating pressures, the LF-RF system has demonstrated increased friction reduction compared to the existing RF system. The improved friction reduction allows the LF-RF fluid to be pumped at high rates, expanding the range of possible well and treatment designs which this fluid system can accommodate.

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Advanced Residue-Free Fracturing Fluid with Improved Friction Reduction and Exceptional Cleanup Properties

Cited by 6 publications

References 14 publications

A Research Model for Using Sacrificial Agents to Enhance Surfactant Performance in Liquids Rich Shale Reservoirs

A Research Model for Using Sacrificial Agents to Enhance Surfactant Performance in Liquids Rich Shale Reservoirs

Carboxymethylcellulose a Cost Effective Alternative to Guar, CMHPG and Surfactant-Based Fluid Systems

A Comparative Study on Operational Performance of Advanced Low Friction Residue-Free Fracturing Fluid versus Conventional Fluid Systems

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