Hydraulic Fracturing of High-Permeability Formations To Overcome Damage

Parker, M.A.; Vitthal, Sanjay; Al, Rahimi; McGowen, J.M.; Jr., W.E.

doi:10.2523/27378-ms

Cited by 6 publications

(2 citation statements)

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“…Low acid degradability assists with diversion characteristics caused by viscous, non-Newtonian fluid invasion. 20 Gravel diverter slurries are normally 5 to 7 bbl total volume containing 1.2-to 1.5-lbm/gal gravel. Total gravel volume mixed in the diverter slurries is approximately 66 to 82 lbm/m (0.20 to 0.25 ft 3 /ft) of perforations.…”

Section: Advantagesmentioning

confidence: 99%

A Review of Completions and Gravel-Pack Techniques of the Xijiang Development

Rodgers¹,

Bennett

Grigsby

et al. 1997

SPE Drilling &Amp; Completion

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The first gravel-packed completions have been run in the Pearl River mouth basin of the South China Sea in the Xijiang fields. The reservoirs in these fields are characterized by unconsolidated, friable, high-permeability sandstones, and, as such, presented many challenges. This paper addresses the development of these fields and how reservoir characteristics and parameters and unexpected deviations were experienced by the operator, as well as the impact these deviations had on completion designs. Important considerations included the need for sand control, zonal isolation, high-rate production, and reduced completion durations. Finally, the practical application and evaluation of pregravelpack stimulation techniques, gravel-pack carrier consideration, fluid-loss controls, and general completion procedures are presented, along with the innovative completion designs developed to manage these needs.

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Section: Advantagesmentioning

confidence: 99%

A Review of Completions and Gravel-Pack Techniques of the Xijiang Development

Rodgers¹,

Bennett

Grigsby

et al. 1997

SPE Drilling &Amp; Completion

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“…More proppant and higher concentration of proppant are place in the fractures. However, gelled fracturing fluids may cause potential formation damage to the reservoirs and therefore lead to decreased productivity [6][7][8][9]. This paper presents a comprehensive analysis of the formation damage issues caused by borate fracturing fluids and various damage evaluation methods were also discussed.…”

Section: Introductionmentioning

confidence: 99%

New Insights of Formation Damage Caused by Borate Crosslinker Fracturing Fluids

Xiao¹,

Wang²,

Sun³

2017

Oil Gas Res

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Hydraulic fracturing has substantially increased the productivity of unconventional reservoirs. The most widely used one is the cross-linked fracturing fluids. Therefore this study analyzed the formation damage issues caused by borate cross-linked fracturing fluids. Results shows that permeability of formation and proppant pack conductivity are greatly affected by reside left behind. The unbroken polymer chains may be cross-linked again if favor conditions present. The residue will ultimately reduce the conductivity of sand pack and only a small amount of guar residue can be displaced with production. To minimize the formation damage problems caused by polymer residue, the concentration of breaker needs to be the optimum value. To help analyze the degradation extent of fracturing fluids, flow-back fluids can be analyzed through various chemical analysis methods, taking into account the dilution effect of produced water.

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Development and Use of High Density Fracturing Fluid in Deep Water Gulf of Mexico Frac and Packs

Rivas

Navaira

Bourgeois

et al. 2008

SPE Annual Technical Conference and Exhibition

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In the Gulf of Mexico, there has been an increase in the number of wells drilled to depths greater than 20,000 ft with bottomhole pressures exceeding 20,000 psi. These deeper wells present drilling and completion challenges to the industry. Two of these challenges include fracture stimulation for low permeability and frac and pack sand control for higher permeability. Because of the high fracture gradient and friction in the wellbore tubulars, a conventional 1.0 to 1.04 SG fracturing fluid would require surface treating pressures greater than 15,000 psi. In the offshore marine environment, 15,000 psi pressure is the current limit of the flexible treatment line that transmits fluid from the stimulation equipment on the marine vessel to the wellhead on the rig.To solve this limitation, a borate-crosslinked high-density fracturing (HDF) fluid with of up to 1.38 was developed to harnesses the power of gravity and reduce the amount of surface treating pressure required to achieve adequate bottomhole fracturing pressure without exceeding the safety limits of the surface equipment. In numerous wells, a minimum of 20% reduction in surface treating pressure over the conventional 1.04 SG was recorded.This paper summarizes the well conditions, extensive fluid qualification testing, procedures, and selected job results along with final completion performance indicators.The HDF fluid enables treatment of these deep offshore wells by lowering surface treating pressure. Conventional 15,000 psi equipment could be used, less horsepower was required, and creating a safer work environment was achieved.

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Hydraulic Fracturing of High-Permeability Formations To Overcome Damage

Cited by 6 publications

References 0 publications

A Review of Completions and Gravel-Pack Techniques of the Xijiang Development

A Review of Completions and Gravel-Pack Techniques of the Xijiang Development

New Insights of Formation Damage Caused by Borate Crosslinker Fracturing Fluids

Development and Use of High Density Fracturing Fluid in Deep Water Gulf of Mexico Frac and Packs

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