Innovative Fiber Solution for Wellbore Strengthening

Friedheim, James E.; Arias-Prada, Jorge Enrique; Sanders, Mark; Shursen, Ryan

doi:10.2118/151473-ms

Cited by 20 publications

(7 citation statements)

References 14 publications

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“…The self-developed equipment for the fracturing experiment consisted of three parts: (1) fluid intrusion system, (2) core holding system, and (3) pressure control and measurement system. The fluid intrusion system consists of an outer sleeve pedestal (11), an outer sleeve (12), a piston (13), an outer sleeve head cover (14), an outer sleeve bottom cover (15), and a pressure sensor (16). The outer sleeve bottom cover is fixed on the outer sleeve pedestal.…”

Section: Methodsmentioning

confidence: 99%

“…The strength of mud cakes formed after filtration is very high. In addition, the material has been applied well in wells along the north slope of Alaska, the Grimes of Texas, and offshore Indonesia [13]. Contreras and Nwaoji introduced a method for strengthening the wellbore by adding a mixture of nanomaterials and graphite to the oil-based drilling fluid, which showed good results with respect to wellbore strengthening and improved formation pressure-bearing capacity.…”

Section: Introductionmentioning

confidence: 99%

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Laboratory Study on Core Fracturing Simulations for Wellbore Strengthening

Zhao

et al. 2019

Geofluids

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The lost circulation in a formation is one of the most complicated problems that have existed in drilling engineering for a long time. The key to solving the loss of drilling fluid circulation is to improve the pressure-bearing capacity of the formation. The tendency is to improve the formation pressure-bearing capacity with drilling fluid technology for strengthening the wellbore, either to the low fracture pressure of the formation or to that of the naturally fractured formation. Therefore, a laboratory study focused on core fracturing simulations for the strengthening of wellbores was conducted with self-developed fracture experiment equipment. Experiments were performed to determine the effect of the gradation of plugging materials, kinds of plugging materials, and drilling fluid systems. The results showed that fracture pressure in the presence of drilling fluid was significantly higher than that in the presence of water. The kinds and gradation of drilling fluids had obvious effects on the core fracturing process. In addition, different drilling fluid systems had different effects on the core fracture process. In the same case, the core fracture pressure in the presence of oil-based drilling fluid was less than that in the presence of water-based drilling fluid.

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Section: Methodsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Laboratory Study on Core Fracturing Simulations for Wellbore Strengthening

Zhao

et al. 2019

Geofluids

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“…The bridging location in the fracture for wellbore strengthening varies, depending on the concentration of loss-prevention material (LPM) (Fuh et al 2007). The LPM forms a sealing barrier around the fracture tip at a low LPM concentration (5-10 vol%), and this increases fracture-propagation resistance and prevents fracture propagation.…”

Section: Introductionmentioning

confidence: 99%

“…Wellbore strengthening by use of LCM has been experimentally and numerically studied by many researchers (Aston et al 2004;Dupriest 2005;Song and Rojas 2006;Aston et al 2007;Fuh et al 2007;Wang et al 2007aWang et al , b, 2008Wang et al , 2009Zhang and Standifird 2007;Growcock et al 2009;Barrett et al 2010;Fett et al 2010;Kumar et al 2010;Otutu 2011;Bassey et al 2012;Friedheim et al 2012;Grandis et al 2012;Morita and Fuh 2012;Savari et al 2012;Nwaoji et al 2013). Although various techniques have been used, the several factors affecting wellbore strengthening are not thoroughly understood.…”

Section: Introductionmentioning

confidence: 99%

Finite-Element Studies of Hoop-Stress Enhancement for Wellbore Strengthening

Feng

Arlanoglu

Podnos

et al. 2015

SPE Drilling &Amp; Completion

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In the drilling of deep horizons, the mud-weight window between pore-pressure gradient and fracture gradient often narrows because of rock properties and underground-stress state. Nonproductive-time events such as lost circulation, wellbore instability, kicks, underground crossflow, and pipe sticking are more likely. Such problems greatly increase drilling costs. Bridging pre-existing natural fractures or drilling-induced fractures with lost-circulation materials (LCM) is often performed to increase fracture gradient and widen the mud-weight window. This technique, referred to as wellbore strengthening, includes the stress cage, fracture-closure stress, and fracture-propagation-resistance methods. Although these methods are often used, several aspects of these approaches are still not thoroughly understood.To reduce the risk of lost circulation while drilling in formations with narrow mud-weight windows, such as pressure-depleted reservoirs and deepwater formations, a good understanding of the mechanisms of wellbore strengthening in different downhole scenarios helps engineers to optimize the design of drilling fluids and operational procedures.This paper discusses the mechanism of wellbore strengthening, with a focus on hoop stresses at and near the wellbore, in elastic and poroelastic models, by use of the finite-element method to evaluate wellbore and near-wellbore stresses during fracture creation and propagation, and after plugging fractures with LCM. Factors affecting fracture behavior, such as horizontal-stress anisotropy, LCM-bridging location, initial pore pressure, and fluid leakoff, are investigated. A better understanding of the several interacting events local to the wellbore and near-wellbore regions can result in improved operational practices related to lost-circulation prevention and mitigation. IntroductionThe purpose of wellbore strengthening during the drilling of oil/ gas wells is to widen the mud-weight window. To maintain downhole pressure within the mud-weight window, drilling fluids are designed to provide wellbore-hydrodynamic pressure low enough to prevent downhole lost circulation but high enough to prevent borehole instability or kicking. While drilling in deep horizons or depleted reservoirs, the window between pore-pressure gradient and fracture gradient often narrows because of rock behavior and the near-wellbore-stress state. Nonproductive-time (NPT) events such as lost circulation, wellbore instability, kicks, underground crossflow, and pipe sticking are more likely. Such problems greatly increase drilling costs.To reduce NPT, drilling engineers often use wellbore strengthening to widen the drilling-mud-weight window and increase the fracture gradient in the formations being drilled, thereby preventing lost circulation and its related problems. Although NPT reduction is desirable, it may at times not be the most-important consideration. Sometimes lost-circulation problems determine whether the well can be completed without requiring additional casing strings and associated change...

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“…Different techniques can be applied. Sanders et al (2010) and Friedheim et al (2012) describe a new highfluid-loss high-strength pill system that is designed to defluidize rapidly in permeable zones when differential pressure is applied. The created seal is strong enough to support high differential pressure and mechanical drilling stresses.…”

Section: Introductionmentioning

confidence: 99%

Degradable Fiber Pill for Lost Circulation in Fractured Reservoir Sections

Droger

Eliseeva

Todd

et al. 2014

IADC/SPE Drilling Conference and Exhibition

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Lost circulation is one of the main causes of nonproductive time during drilling and impacts the success of cementing operations. Losses into the reservoir not only impact drilling, they potentially impact the reservoir, due to influx of quantities of drilling fluids that are potentially damaging, or will influence the production rate. Existing solutions are based mainly on particulates, which often are added to drilling fluids to plug fractures or to build up filtercake to cure fluid losses. When particulates are applied for curing losses in reservoir sections, it is desirable that the plugging materials maintain stability for sufficient time to allow well completion but eventually self-degrade to leave undamaged formation for future hydrocarbon production. The main challenges are the design of the lost-circulation material to cure losses into fractures of various widths and to provide plug stability and cleanup within a desired time frame over a broad bottomhole temperature range.Fibers have shown good fracture-plugging behavior. Parameters affecting fiber performance include, but are not limited to, fluid viscosity, fiber concentration, fiber geometry, flow rate, effect of the wall, and fracture width. To effectively apply fibers as lost-circulation applications, a novel, fiber-laden fluid was designed for easy preparation on surface, allowing compatibility with bottomhole assemblies (BHAs). The decrease in velocity inside the fracture enables fibers to bridge and then plug the fracture, thus regaining circulation. The fibers are specially designed to degrade in an adjustable time frame sufficient to ensure plug stability until the well is completed. With time, the plug undergoes further degradation, leading to nondamaged formation for production.This novel degradable solution has been successfully proven during field trials in various drilling scenarios ranging from severe to total losses with effective and efficient loss mitigation, without issues on placement through BHA and bit nozzles, and mitigating further reservoir damage.

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Innovative Fiber Solution for Wellbore Strengthening

Cited by 20 publications

References 14 publications

Laboratory Study on Core Fracturing Simulations for Wellbore Strengthening

Laboratory Study on Core Fracturing Simulations for Wellbore Strengthening

Finite-Element Studies of Hoop-Stress Enhancement for Wellbore Strengthening

Degradable Fiber Pill for Lost Circulation in Fractured Reservoir Sections

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