Effects of Size on Three-Cone Bit Performance In Laboratory Drilled Shale
- Alan D. Black | Gordon A. Tibbitts | John L. Sandstrom | Bennie G. DiBona
- Document ID
- Society of Petroleum Engineers
- Society of Petroleum Engineers Journal
- Publication Date
- August 1985
- Document Type
- Journal Paper
- 473 - 481
- 1985. Society of Petroleum Engineers
- 4.3.4 Scale, 5.8.2 Shale Gas, 1.11 Drilling Fluids and Materials, 1.5.1 Bit Design, 1.2.3 Rock properties, 1.5 Drill Bits, 1.6 Drilling Operations, 1.5.4 Bit hydraulics, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 4.2 Pipelines, Flowlines and Risers
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The effects of size on the performance of three-cone bits were measured during laboratory drilling tests in shale at simulated downhole conditions. Four Reed HP-SM three-cone bits with diameters of 6, 7 7/8, 9, and 11 in. [165, 200, 241, and 279 mm] were used to drill Mancos shale with water-based mud. The tests were conducted at constant borehole pressure, two conditions of hydraulic horsepower per square inch of bit area, three conditions of rotary speed, and four conditions of weight-on-bit (WOB) per inch of bit diameter. The resulting rates of penetration (ROP's) and torques were measured. penetration (ROP's) and torques were measured. Statistical techniques were used to analyze the data.
Drill bit manufacturers generally recommend WOB operating ranges for their bits in terms of pounds-force per inch of bit diameter. The practice of normalizing the per inch of bit diameter. The practice of normalizing the effect of bit size by expressing it in these terms has been widely used and often accepted as a "rule of thumb" in the drilling industry. Many have suspected that this rule of thumb may be an oversimplification because bit design tends to vary widely with size even in the same models, and hydraulic cleaning of the bit and bottom of the hole becomes much more difficult as size increases. A better understanding of the effects of size on bit performance and the validity of the WOB per inch of bit performance and the validity of the WOB per inch of bit diameter rule of thumb was sought by performing drilling tests with various-size bits under controlled laboratory conditions. Drilling tests were performed with four Reed HP-SM three-cone bits with diameters of 6, 7 7/8, 9, and 11 in. [165, 200, 241, and 279 mm]. As many variables as possible were held constant during the drilling tests, including rock type; confining pressure and overburden stress on the rock; mud type, properties, and temperature; and borehole pressure. Nozzle sizes and flow rates were selected so that each bit was tested at approximately the same conditions of hydraulic horsepower per square inch of bit area. Three rotary-speed conditions per square inch of bit area. Three rotary-speed conditions and four WOB per inch of diameter conditions were run. The resulting ROP's and torques were measured at each condition. A detailed statistical analysis was performed on me dam to determine the relationship between the independent variables of bit size, WOB, rotary speed, and hydraulic horsepower per square inch of bit area and the dependent variables of ROP, torque, and mechanical horsepower expended at the bit.
Drill Bit, Rock, Mud, and Nozzle Selection
Four new Reed HP-SM bits with diameters of 6, 7 7/8, 9, and 11 in. [165, 200, 241, and 279 mm] were provided by Reed Rock Bit Co. for the tests. The provided by Reed Rock Bit Co. for the tests. The HP-SM bit is specified in the IADC code under four classifications (537, 547, 617, and 627). The manufacturer recommends the HP-SM bit for both soft formations containing streaks of harder materials and medium-strength formations. The HP-SM bits have conical inserts except for the chisel-shaped inserts on the gauge row. The manufacturer's recommended operating ranges for WOB per inch of bit diameter and rotary speed are 3,000 to 6,000 lbf [525 to 1051 N/mm] per inch of bit diameter and 45 to 140 rev/min, respectively. Fig. 1 is a photograph of the HP-SM bits. The number of inserts, average insert diameter, and average insert length were measured and are listed in Table 1. The rock formation samples drilled were Mancos shale. Mancos shale is a Cretaceous, gray to black, shale/siltstone formation containing 10% clay composed of illite and chlorite. Samples 15 in. [394 mm] in diameter by 36 in. [914 mm] long were used for the 6 -, 7 7/8-, and 9 -in.- [165-, 200-, and 241-mm]-diameter bit tests. A sample 17 in. [445 mm] in diameter by 36 in. [914 mm] long was used for the 11-in.-[279-mm]-diameter bit test. All samples were originally cored from a massive surface outcropping located in central Utah and preserved for the drilling tests. Mancos shale has an unconfined compressive strength of 9,000 psi [62 053 kPa] and a permeability less than 1 d. Detailed rock properties permeability less than 1 d. Detailed rock properties and a comparison of laboratory and field shale drilling have been given previously. A "standard" water-based mud with properties listed in Table 2 was selected for the tests. To compare the performance of different-size bits, it was felt that hydraulic horsepower per square inch of bit area (HSI) should be held constant during the tests. It was also felt that similar pressure drops across the bit should be run if possible. Calculations were made to determine the nozzle diameters that would create approximately the same pressure drop at constant HSI conditions.
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