Coiled-Tubing Deployment of Hydrajet-Fracturing Technique Enhances Safety and Flexibility, Reduces Job Time

McDaniel, B.W.; Willett, Ron; East, Loyd E.; Rosato, Jeff; Surjaatmadja, Jim Basuki

doi:10.2118/90543-ms

Cited by 18 publications

(7 citation statements)

References 17 publications

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“…23 The process has been applied to openhole horizontals, horizontal slotted liners, and cemented-cased horizontal wellbores. The technique is essentially a combination of three processes: (1) hydrajetting to perforate, (2) through-tubing hydraulic fracturing while jetting, and (3) a separate fluid injection system down the annulus.…”

Section: Hydrajet Fracturing Techniquementioning

confidence: 99%

Correlations To Predict Frictional Pressure of Hydraulic Fracturing Slurry in Coiled Tubing

Shah¹,

Zhou²,

Bailey³

et al. 2006

Proceedings of International Oil &Amp; Gas Conference and Exhibition in China

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractCompared with conventional tubing fracturing, coiled tubing (CT) fracturing has several advantages. CT fracturing has become an effective stimulation technique for multi-zone oil and gas wells. CT fracturing is also attractive production enhancement method for multi-seam coalbed methane wells as well as wells with bypassed zones. The excessive frictional pressure loss through CT has been a concern for CT fracturing. CT strings have small diameter and this limits the cross-sectional area open to flow. Furthermore, the tubing curvature causes secondary flow and hence results in extra flow resistance. This increased friction pressure results in high surface pumping pressure. The maximum possible pump rate and sand concentration, therefore, have to be reduced. To properly design a CT fracturing job, it is, therefore, essential to be able to predict the frictional pressure loss through CT accurately.This paper presents two correlations for the prediction of frictional pressure of fracturing slurries in coiled tubing. One is developed based on full-scale slurry flow tests with 1-1/2in. coiled tubing and slurries prepared with 35 lb/Mgal guar gel. The extensive experiments were conducted at the fullscale coiled tubing flow test facility. The other correlation is derived from the Srinivasan's friction factor correlation of Newtonian fluid in coiled pipes. The Srinivasan correlation is modified for the non-Newtonian fluids and it further requires an inclusion of the relative slurry viscosities which have been thoroughly evaluated in this study. The proposed correlations have been verified with the experimental data and actual field CT fracturing data. Case studies of wells recently fractured using CT are provided to demonstrate the application of the correlations. The correlations will be useful to the CT engineers in their hydraulics design calculations.

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Section: Hydrajet Fracturing Techniquementioning

confidence: 99%

Correlations To Predict Frictional Pressure of Hydraulic Fracturing Slurry in Coiled Tubing

Shah¹,

Zhou²,

Bailey³

et al. 2006

Proceedings of International Oil &Amp; Gas Conference and Exhibition in China

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“…Hydrajet Fracturing Technique. The multistage fracture-stimulation method known as hydrajet fracturing has proved to be very successful for fracture stimulating horizontal wells (McDaniel et al 2004). The process has been applied to openhole horizontals, horizontal slotted liners, and cemented-casing horizontal wellbores.…”

Section: Field-data Analysis and Resultsmentioning

confidence: 99%

Correlations To Predict Frictional Pressure Loss of Hydraulic-Fracturing Slurry in Coiled Tubing

Shah

Zhou

Bailey

et al. 2009

SPE Production &Amp; Operations

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Compared with conventional-tubing fracturing, coiled-tubing (CT) fracturing has several advantages. CT fracturing has become an effective stimulation technique for multizone oil and gas wells. It is also an attractive production-enhancement method for multiseam coalbed-methane wells, and wells with bypassed zones. The excessive frictional pressure loss through CT has been a concern in fracturing. The small diameter of the string limits the cross-sectional area open to flow. Furthermore, the tubing curvature causes secondary flow and results in extra flow resistance. This increased frictional pressure loss results in high surface pumping pressure. The maximum possible pump rate and sand concentration, therefore, have to be reduced. To design a CT fracturing job properly, it is essential to predict the frictional pressure loss through the tubing accurately.This paper presents correlations for the prediction of frictional pressure loss of fracturing slurries in straight tubing and CT. They are developed on the basis of full-scale slurry-flow tests with 1½-in. CT and slurries prepared with 35 lbm/1,000 gal of guar gel. The extensive experiments were conducted at the full-scale CT-flow test facility. The proposed correlations have been verified with the experimental data and actual field CT-fracturing data. Case studies of wells recently fractured are provided to demonstrate the application of the correlations. The correlations will be useful to the CT engineers in their hydraulics design calculations.

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“…[8][9][10][11][12][13] Often referred to as hydrajet-assisted fracturing (HJAF), the process has also been shown to effectively stimulate long openhole sections of a wellbore and multi-lateral wellbores. [8][9][10][11][12][13] Often referred to as hydrajet-assisted fracturing (HJAF), the process has also been shown to effectively stimulate long openhole sections of a wellbore and multi-lateral wellbores.…”

Section: Horizontal Well Fracturing Processmentioning

confidence: 99%

Fracturing Horizontal Wells to Offset Water Breakthrough in Naturally Fractured Reservoirs

2007

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractHorizontal drainholes in thick, high-permeability reservoirs have been used effectively to produce many reservoirs in the Middle East. Many of these bottom-water-drive reservoirs have natural fractures intersecting the wellbore that connect through the oil-water contact. Therefore, they are susceptible to water encroachment through natural fractures when high drawdowns are applied. The resulting water production leads to a number of well maintenance problems and reduces the efficiency of the completion.Hydraulically fracturing these horizontal drainholes can offer a number of benefits including reduced water influx. The placement of several small and/or a few large hydraulic fractures at pre-designed intervals in the horizontal wellbore would significantly improve the deliverability of the reservoir and thus reduce the drawdown necessary to achieve optimum production. It is of course necessary to keep the fractures from penetrating into the water-bearing formation. Since most of these wellbores are uncased, openhole completions, a special fracturing technique has been used that allows precise placement of these fractures without the need for mechanical isolation of intervals during the fracturing operation.Production modeling of a horizontal completion in reservoirs with bottomwater encroachment through natural fractures will be compared to a hydraulically fractured completion with the same conditions. Modeling will also illustrate the potential of using hydraulic fracturing as a remediation technique for water production problems. It will also illustrate its effect on completions with current water production. The openhole fracturing technique will be illustrated with a case history from the Hanifa formation in Saudi Arabia.

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Coiled-Tubing Deployment of Hydrajet-Fracturing Technique Enhances Safety and Flexibility, Reduces Job Time

Cited by 18 publications

References 17 publications

Correlations To Predict Frictional Pressure of Hydraulic Fracturing Slurry in Coiled Tubing

Correlations To Predict Frictional Pressure of Hydraulic Fracturing Slurry in Coiled Tubing

Correlations To Predict Frictional Pressure Loss of Hydraulic-Fracturing Slurry in Coiled Tubing

Fracturing Horizontal Wells to Offset Water Breakthrough in Naturally Fractured Reservoirs

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