Child Well Analysis from Poroelastic Pressure Responses on Parent Wells in the Eagle Ford

Das, Paloma; Solaja, Ola; Cabrera, J.G.; Scofield, Reid; Coenen, Erica; Kashikar, Sudhendu; Kahn, Charles

doi:10.2118/194354-ms

Cited by 5 publications

(1 citation statement)

References 3 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Field observation also notice that planar fracture models with constant matrix permeability are capable of history matching production in most unconventional reservoirs, and rate transient analysis often reveals that productive surface area is much less than the "fracture networks" would imply. And the results from planar fracture propagation models match well with field data on inter-well pressure communication during hydraulic fracturing (Das et al, 2019;Seth et al, 2019). In addition, DFITs in most low permeability formations demonstrate extremely long after-closure linear flow behavior, which can only happen without the pressure interference of adjacent fractures.…”

Section: Fig18 the Analogy Between Multi-fracturing Within A Certaisupporting

confidence: 64%

Hydraulic fracture propagation in naturally fractured reservoirs: Complex fracture or fracture networks

Wang

2019

Journal of Natural Gas Science and Engineering

138

View full text Add to dashboard Cite

All reservoirs are fractured to some degree. Depending on the density, dimension, orientation and the cementation of natural fractures and the location where the hydraulic fracturing is done, pre-existing natural fractures can impact hydraulic fracture propagation and the associated flow capacity. Understanding the interactions between hydraulic fracture and natural fractures is crucial in estimating fracture complexity, stimulated reservoir volume (SRV), drained reservoir volume (DRV) and completion efficiency. However, what hydraulic fracture looks like in the subsurface, especially in unconventional reservoirs, remain elusive, and many times, field observations contradict our common beliefs. In this study, a global cohesive zone model is presented to investigate hydraulic propagation in naturally fractured reservoirs, along with a comprehensive discussion on hydraulic fracture propagation behaviors in naturally fractured reservoirs. The results indicate that in naturally fractured reservoirs, hydraulic fracture can turn, kink, branch and coalesce, and the fracture propagation path is quite complex, but it does not necessarily mean that fracture networks can be created, even under low horizontal stress difference, because of strong stress shadow effect and flow-resistance dependent fluid distribution. Perhaps, 'complex fracture', rather than 'fracture networks', is the norm in most unconventional reservoirs.

show abstract

Section: Fig18 the Analogy Between Multi-fracturing Within A Certaisupporting

confidence: 64%

Hydraulic fracture propagation in naturally fractured reservoirs: Complex fracture or fracture networks

Wang

2019

Journal of Natural Gas Science and Engineering

138

View full text Add to dashboard Cite

show abstract

Utilization of Far Field Diverters to Mitigate Parent and Infill Well Fracture Interaction in Shale Formations

Zhang

Cramer

McEwen

et al. 2019

Day 2 Wed, February 06, 2019

View full text Add to dashboard Cite

Hydraulic fracturing treatments in shale infill wells are often impacted by existing parent well depletion and asymmetrical fracture growth. These phenomena can result in excessive load water production, deposition of proppant and deformation of casing in the parent well, and unbalanced stimulation of infill wells. This study determines the effectiveness of particulate materials for mitigating the above negative outcomes by bridging near the extremities of dominant fracture wings, i.e., far field diverting agents. Fracture propagation was modeled to characterize the width profile at fracture extremities in a depleted stress environment. A slotted-disk device was used to evaluate and optimize particulate blends for bridging slots representative of width near the fracture tip. Rheological tests replicating the downhole environment were used to formulate a system for transporting the diverting materials. Statistical analysis of 511 fracture hits at 30 parent wells was performed on key treatment indicators by the category of diverter type and post-hit parent well condition. Production trends of the influenced wells were compared to area-specific type curves and offset wells without diverter trials. Based on the simulation and testing results, two types of high-graded far field diverter systems were field tested in a shale play: dissolvable, extremely fine particulate mixed with 100 mesh sand, and mixtures of nominal 325 mesh silica flour and 100 mesh sand. Proppant dust collected at the fracturing site was also evaluated for replacing commercial silica flour. High-graded blends of the above diverting systems demonstrated superior frac-hit and productivity metrics as compared to the base case of not applying far field diverters. The silica flour and 100 mesh sand mixture performed on par with the significantly more expensive blend of dissolvable fine particulate and 100 mesh sand. Guar borate crosslinked gel was an effective carrying fluid for transporting diverting materials to the fracture extremities. Statistical analysis of fracture hit events shows that the application of far field diverters did not reduce the magnitude of pressure buildups during fracture hits; however, it significantly increases the post-hit pressure falloff rate at the parent wells. Based on the area-specific type curves, pumping far field diverters increased the P50 EUR by about 6% compared with the base cases of not applying diverters. For all the wells impacted by far field diverters, the infill wells saw larger benefits with an increment of P50 EUR by about 7% compared with the parent wells.

show abstract

Use of Far-Field Diverters To Mitigate Parent- and Infill-Well-Fracture Interactions in Shale Formations

Zhang

Cramer

McEwen

et al. 2019

SPE Production &Amp; Operations

View full text Add to dashboard Cite

Summary Hydraulic-fracturing treatments in shale infill wells are often impacted by existing parent-well depletion and asymmetrical fracture growth. These phenomena can result in excessive load-water production, deposition of proppant and deformation of casing in the parent well, and unbalanced stimulation of infill wells. This study determines the effectiveness of particulate materials (i.e., far-field diverting agents) for mitigating the above negative outcomes by bridging near the extremities of dominant fracture wings. Fracture propagation was modeled to characterize the width profile at fracture extremities in a depleted-stress environment. A slotted-disk device was used to evaluate and optimize particulate blends for bridging slots representative of width near the fracture tip. Rheological tests replicating the downhole environment were used to formulate a system for transporting the diverting materials. Statistical analysis of 511 fracture hits at 30 parent wells was performed on key treatment indicators by the category of diverter type and post-hit parent-well condition. Production trends of the influenced wells were compared to area-specific type curves and offset wells without diverter trials. On the basis of the simulation and testing results, two types of high-graded far-field diverter systems were field-tested in a shale play: dissolvable, extremely fine particulate mixed with a 100-mesh sand, and mixtures of a nominal 325-mesh silica flour and a 100-mesh sand. Proppant dust collected at the fracturing site was also evaluated for replacing commercial silica flour. High-graded blends of the above diverting systems demonstrated superior fracture-hit and productivity metrics as compared to the base case of not applying far-field diverters. The silica flour and 100-mesh-sand mixture performed on a par with the significantly more expensive blend of dissolvable fine particulate and 100-mesh sand. Borate-crosslinked-guar gel was an effective carrying fluid for transporting diverting materials to the fracture extremities. Statistical analysis of fracture-hit events shows that the application of far-field diverters did not reduce the magnitude of pressure buildups during fracture hits; however, it significantly increases the post-hit pressure-falloff rate at the parent wells. On the basis of the area-specific type curves, pumping far-field diverters increased the P50 estimated ultimate recovery (EUR) by approximately 6% compared with the base cases of not applying diverters. For all the wells impacted by far-field diverters, the infill wells saw larger benefits with an increment of P50 EUR by approximately 7% compared with the parent wells.

show abstract

Child Well Analysis from Poroelastic Pressure Responses on Parent Wells in the Eagle Ford

Cited by 5 publications

References 3 publications

Hydraulic fracture propagation in naturally fractured reservoirs: Complex fracture or fracture networks

Hydraulic fracture propagation in naturally fractured reservoirs: Complex fracture or fracture networks

Utilization of Far Field Diverters to Mitigate Parent and Infill Well Fracture Interaction in Shale Formations

Use of Far-Field Diverters To Mitigate Parent- and Infill-Well-Fracture Interactions in Shale Formations

Contact Info

Product

Resources

About