Technical Advances in Liquid CO&lt;sub&gt;2&lt;/sub&gt; Fracturing

Tudor, R.; Vozniak, C.; Peters, Wade; Banks, M. L.

doi:10.2118/94-36

Cited by 21 publications

(17 citation statements)

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“…In 1981, pure liquid CO 2 was first used as a proppant carrier and fracturing fluid [81] and this was then extensively used throughout the world, especially in Canada and the USA [33,82]. The most prominent advantage of the use of CO 2 is the avoidance of huge water consumption and wastewater generation.…”

Section: Co 2 As Fracturing Fluid For Hydro Fracturing In Clay-abundamentioning

confidence: 99%

“…As mentioned in Section 2.3, clay-abundant shale plays have a larger number of tiny pores, through which viscous fluids like water cannot penetrate and therefore remain outside these pores. Further, this residual water blocks the small throats, causing difficulties in the extraction of gas from the micro-pores [14,15,33]. According to Figure 17, with the absorbed water content in clay-abundant shale rock increased to around 2%, the air permeability decreased by more than 95%.…”

Section: Minimization Of Issues Related To Residual Fluidsmentioning

confidence: 99%

“…Therefore, it can easily diffuse through bottle-necked pore networks created by tiny pores and the available retained water [106]. the micro-pores [14,15,33]. According to Figure 17, with the absorbed water content in clay-abundant shale rock increased to around 2%, the air permeability decreased by more than 95%.…”

Section: Minimization Of Issues Related To Residual Fluidsmentioning

confidence: 99%

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Characteristics of Clay-Abundant Shale Formations: Use of CO2 for Production Enhancement

et al. 2017

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Clay-abundant shale formations are quite common worldwide shale plays. This particular type of shale play has unique physico-chemical characteristics and therefore responds uniquely to the gas storage and production process. Clay minerals have huge surface areas due to prevailing laminated structures, and the deficiency in positive charges in the combination of tetrahedral and octahedral sheets in clay minerals produces strong cation exchange capacities (CECs), all of which factors create huge gas storage capacity in clay-abundant shale formations. However, the existence of large amounts of tiny clay particles separates the contacts between quartz particles, weakening the shale formation and enhancing its ductile properties. Furthermore, clay minerals' strong affinity for water causes clay-abundant shale formations to have large water contents and therefore reduced gas storage capacities. Clay-water interactions also create significant swelling in shale formations. All of these facts reduce the productivity of these formations. The critical influences of clay mineral-water interaction on the productivity of this particular type of shale plays indicates the inappropriateness of using traditional types of water-based fracturing fluids for production enhancement. Non-water-based fracturing fluids are therefore preferred, and CO 2 is preferable due to its many unique favourable characteristics, including its minor swelling effect, its ability to create long and narrow fractures at low breakdown pressures due to its ultralow viscosity, its contribution to the mitigation of the greenhouse gas effect, rapid clean-up and easy residual water removal capability. The aim of this paper is to obtain comprehensive knowledge of utilizing appropriate production enhancement techniques in clay-abundant shale formations based on a thorough literature review.

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Section: Co 2 As Fracturing Fluid For Hydro Fracturing In Clay-abundamentioning

confidence: 99%

Section: Minimization Of Issues Related To Residual Fluidsmentioning

confidence: 99%

Section: Minimization Of Issues Related To Residual Fluidsmentioning

confidence: 99%

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Characteristics of Clay-Abundant Shale Formations: Use of CO2 for Production Enhancement

et al. 2017

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“…The vast majority of these treatments were performed in North America, primarily in reservoirs that were depleted, undersaturated, and/or water sensitive (Gupta 2011). These foam treatments gained significant popularity in the 1980s, and the reader may refer to the work of Bleakley (1980), Wendorff and Ainley (1981), Grundman and Lord (1983), Gabris and Taylor (1986), Ward (1986), and Harris et al (1991) for more details on the field implementation of CO 2 foams. The first documented attempt to use liquid CO 2 as a sole fracturing fluid goes back to 1981 (Lillies and King 1982).…”

Section: Introductionmentioning

confidence: 99%

Use of a CO2-Hybrid Fracturing Design To Enhance Production From Unpropped-Fracture Networks

Ribeiro

Bryant

2016

SPE Production &Amp; Operations

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This paper introduces an innovative CO 2 -hybrid-fracturing-fluid design that intends to improve production from ultratight reservoirs and reduces freshwater usage. The design consists of injecting pure CO 2 as the pad fluid to generate a complex fracture network and injecting a gelled slurry (water-or foam-based) to generate near-wellbore conductivity. The motivation behind this design is that while current aqueous fluids provide sufficient primary hydraulic-fracture conductivity back to the wellbore, they understimulate the reservoir and leave behind damaged stimulated regions deeper in the fracture network. Much of that (unpropped) stimulated area is ineffective for production because of interfacial-tension effects, fines generation, and/or polymer damage. We present simulation work that demonstrates how CO 2 , with its low viscosity, can extend the bottomhole treating pressure deeper into the reservoir and generate a larger producible surface area. We also present experimental evidence that CO 2 leaves behind higher unpropped-fracture conductivities than slickwater. This paper does not address the many operational and logistical challenges of using CO 2 as a fracturing fluid. Rather, it intends to demonstrate the production-uplift potential of the proposed design, which seems particularly attractive in reservoirs capable of sustaining production from unpropped fractures (e.g., reservoirs with low horizontal-stress anisotropy, high Young's modulus, and a pervasive set of natural fractures).

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“…The system allowed for relatively small treatments as the vessel volume was limited to a capacity of 20 tons and required long downtimes to reload with proppant. 23,24 In 1982, some service companies completed over 40 CO 2 -sand treatments in the U.S. before the equipment was relocated and used extensively in Canada. 12 The technology received commercial acceptance in Canadian oil and gas fields, completing over 1,200 jobs by 1998.…”

Section: Introductionmentioning

confidence: 99%

Water-Free Fracturing: A Case History

Asadi¹,

Scharmach²,

Jones³

et al. 2015

Day 1 Tue, October 20, 2015

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While hydraulic fracturing is primarily used to recover oil and gas from reservoirs, water-free fracturing may soon become the center stage to extract hydrocarbons in certain formations or situations. DryFrac™ waterless fracturing technology, as the name implies, does not use water to create the fracture. Instead, this process uses liquid CO 2 to crack open the formation providing a highly conductive path for hydrocarbons to flow into the well. This technology can provide superior technical advantages over water-based hydraulic fracturing by eliminating the need for water, resulting in formations free from water damage and maintaining the intended proppant pack conductivity with no polymer residue. This paper presents in-depth information on a case history where liquid CO 2 is used to fracture a formation. The presented data includes background, modeling, liquid CO 2 implementation as a fracturing fluid, results and analyses.

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Technical Advances in Liquid CO<sub>2</sub> Fracturing

Cited by 21 publications

References 0 publications

Characteristics of Clay-Abundant Shale Formations: Use of CO2 for Production Enhancement

Characteristics of Clay-Abundant Shale Formations: Use of CO2 for Production Enhancement

Use of a CO2-Hybrid Fracturing Design To Enhance Production From Unpropped-Fracture Networks

Water-Free Fracturing: A Case History

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