Case History Evaluation of RPMs on Conform Fracturing Applications

Santos, Jose Altamiro Carril Dos; Melo, Ricardo Cesar Bezerra De; Lullo, Gino Francesco Di

doi:10.2118/94352-ms

Cited by 19 publications

(3 citation statements)

References 5 publications

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“…There are systems capable of mitigating the effects of water penetration in areas. They act by incorporating modifiers of permeability to fracturing fluids [15] [16] or the use of proppant systems capable of maintaining open preferably the top of fracture [13] [17].…”

Section: ) Proximity To Oil-water or Gas-oil Contactsmentioning

confidence: 99%

Selecting Oil Wells for Hydraulic Fracturing: A Comparison between Genetic-Fuzzy and Neuro Fuzzy Systems

Filho¹,

Castro²

2014

AJOR

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Hydraulic fracturing is widely used to increase oil well production and to reduce formation damage. Reservoir studies and engineering analyses are carried out to select the wells for this kind of operation. As the reservoir parameters have some diffuse characteristics, Fuzzy Inference Systems (FIS) have been tested for these selection processes in the last few years. This paper compares the performance of a neuro fuzzy system and a genetic fuzzy system used for selecting wells for hydraulic fracturing, with knowledge acquired from an operational data base to set the SIF membership functions. The training data and the validation data used were the same for both systems. We concluded that, despite the genetic fuzzy system being a newer process, it obtained better results than the neuro fuzzy system. Another conclusion was that, as the genetic fuzzy system can work with constraints, the membership functions setting kept the consistency of variable linguistic values.

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Section: ) Proximity To Oil-water or Gas-oil Contactsmentioning

confidence: 99%

Selecting Oil Wells for Hydraulic Fracturing: A Comparison between Genetic-Fuzzy and Neuro Fuzzy Systems

Filho¹,

Castro²

2014

AJOR

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“…This practice started in the late 1990s with the use of low-viscosity RPMs as a preflush before hydraulic fracturing treatments (Brocco et al 1999;Brocco et al 2000). In other cases, the RPM polymer was included as an additive in the conventional fracturing fluids (Dos Santos and de Melo 2005). In these applications, the RPM, usually in the pad or prepad stages, leaks off into fracture faces (predominantly spurt loss in high-permeability formations), reducing the water mobility in the invaded zone and increasing the fracture fluid efficiency (Leal and Gonzalez 2005).…”

Section: Viscosified Disproportionate Permeability Modifiers In Fractmentioning

confidence: 99%

Challenging the Economic Limit in Mature Fields by Hydraulic Fracturing of Wet Producers

Rachid

Milne

Ali

et al. 2014

Day 1 Wed, February 26, 2014

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In Ecuador there are mature subhydrostatic sandstone reservoirs that have lateral water drive or that are located close to the oil/water contact. With time the water saturation has increased and water breakthrough is common in high-permeability streaks, causing the water cut to increase substantially. In these fields the challenge is to increase oil production and recoverable reserves through stimulation without increasing the water cut. For this reason, until recently, hydraulic fracturing was not considered a viable option. Although conventional acid treatments increased oil production, they also increased the water cut, sometimes making the production uneconomical. To overcome this, either acid treatments with diverter stages are used to selectively stimulate the oil-saturated intervals or relative permeability modifiers are used to limit water production. However, these have not proved to be reliable solutions.To hydraulically fracture wet producers, a linear fracturing fluid was introduced. The fluid is formulated with low concentrations of a disproportionate permeability modifier (DPM) or a relative permeability modifier (RPM), and guar polymer creates a pseudoviscoelastic disproportionate permeability modifier (VDPM). The VDPM reduces the effective permeability to water in the fracture faces, and the relatively low viscosity of the fluid limits the net pressure and the risk of fracture height growth, without compromising proppant transport. The viscosity and leakoff control of the fluid can be adjusted as a function of the formation properties, leak-off and stress profile.The first hydraulic fracturing campaign of eight wells using the VDPM fluid was in the Hollin formation, which has a strong aquifer below it and in some cases a lateral aquifer. Typically, the upper section produces oil and the lower section is water saturated; the distance between the two sections is 5 to 25 ft. On average the oil production increased threefold and the water cut was not increased after the fracturing job, in spite of the proximity to the wet zone. While the results of matrix treatments with RPMs in wet producers are notoriously mixed, hydraulic fracturing with a VDPM fluid has proved a reliable means to selectively increase oil production in the presented case. This has had a very positive impact on the economics and reserves recovery in these marginal mature fields.

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“…It is essential that low-damage water-control fluids be developed for tight gas wells to serve as an early pre-pad fluid or pre-pad fluid. As shown in Figure , such a pre-pad fluid is to not only penetrate into both sides of the proppant-supported fracture but also change the relative permeability of gas–water systems around the proppant-supported fracture, controlling a rapid increase in water-cut of gas wells after hydraulic fracturing. , …”

Section: Introductionmentioning

confidence: 99%

Performance Evaluation of Water Control with Nanoemulsion as Pre-pad Fluid in Hydraulically Fracturing Tight Gas Formations

Zhang

Yuan

et al. 2017

Energy Fuels

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Experimental techniques have been developed to evaluate performance of nanoemulsions as pre-pad fluid for reducing water-cut in tight gas formations with multistage hydraulic fractures. More specifically, an aminopolysiloxane nanoemulsion was prepared and formulated in the laboratory for effective and efficient water control. The water-control mechanisms of nanoemulsions as pre-pad fluid in hydraulic fracturing were identified by performing the scanning electron microscopy (SEM), X-ray photoelectron spectroscopy (XPS), spontaneous imbibition tests, and wettability measurements. The SEM and XPS tests confirm that certain changes occur in the element compositions and microstructure of the core surface before and after introducing the prepared nanoemulsions on the reservoir rock surface. Such changes irreversibly alter its wettability, indicated by the measured contact angle from 75°to 128°. During the displacement experiments, there exists a disproportionate permeability reduction on relative permeability of the gas−water systems. Gas relative permeability has only a small decline by less than 20% at different water saturations, while water relative permeability is reduced up to 60%. In addition, effective gas permeability for the core samples treated with nanoemulsions can be rapidly restored by the potential acid hydrolysis. This leads to not only creating new paths for gas flow in hydraulic fractures or invaded zones but also reducing the inertial resistance of gas flow in porous media by nanoemulsion retention.

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Case History Evaluation of RPMs on Conform Fracturing Applications

Cited by 19 publications

References 5 publications

Selecting Oil Wells for Hydraulic Fracturing: A Comparison between Genetic-Fuzzy and Neuro Fuzzy Systems

Selecting Oil Wells for Hydraulic Fracturing: A Comparison between Genetic-Fuzzy and Neuro Fuzzy Systems

Challenging the Economic Limit in Mature Fields by Hydraulic Fracturing of Wet Producers

Performance Evaluation of Water Control with Nanoemulsion as Pre-pad Fluid in Hydraulically Fracturing Tight Gas Formations

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