Hydraulics Calculation
2
??? ??? 99-10-22 ????? ???? 3500 409 7200 8 1/8 25 . Gravity of Cuttings 6000 4 1/2 10.00 7 7/8 3 5/6 50 Surface Equipment Type 1 780 30 5 4 1/2 16 12 110 2 7/9 3 12 0 42 12 270 8.00 Working Pumps Number 1 pump 6 1/4 15.00 3000 2 1/4 12.00 0.3313 185 96 3.80 1864 943 JET SELECTION 366 50.6 0.2314 Buoyancy Factor 0.847 566 0.2693 43.67 325 0.2503 0.073 3.06 Strokes 8.01 336.60 Mud to reach the bit 3973 95.17 11.8 1298 193 12552 298.86 37.3 4102 140 16525 393.46 49.1 5400 57 33703 802.46 100 11014 68 Bottom Sample Up 51 5653 10.22 232 0.43 10.05 10.27 9.815 7.328 9.815 7.714 6678 17.143 D.C. Section H. Wt. Section D.P. O.H. Section D.P. Casing Section 7 7/8 7 7/8 7 7/8 8 1/8 0.7365 6 1/4 4 1/2 4 1/2 4 1/2 0.4776 2 1/4 2 7/9 3 5/6 3 5/6 1.5513 Poise 270 780 2650 3500 4.1581 Poise In Pipe Annular In Pipe Annular In Pipe Annular In Pipe Annular 0.20655 0.936499 0.31306 1.70406 0.59725 1.70406 0.59725 1.8441 0.00492 0.022298 0.00745 0.04057 0.01422 0.04057 0.01422 0.04391 55.8 252.9 244.2 1329.2 1582.7 4515.8 2090.4 6454.4 1.33 6.02 5.81 31.65 37.68 107.52 49.77 153.68 1630 359 1075 198 564 198 564 183 27.16 5.99 17.92 3.29 9.39 3.29 9.39 3.04 248 197 197 4.13 3.28 3.28 232 336 336 77.79 77.79 77.79 21.87 282 120 120 161 78 61 61 88 1.0 6.5 22.1 21.8 25.75 18.20 30.35 36.44 39.18 36.44 39.18 39.22 Reynolds Number 22020 4965 15176 2830 8512 2830 8512 2584 flow type Turbulent Turbulent TurbulentTransitional Turbulent Transitional Turbulent Laminar Friction Factor 0.0052 0.00582 0.0057 0.00849 0.0067 0.00849 0.0067 0.00929 177 13 200 8 158 28 208 32 HYDRAULIC CALCULATIONS Well Name: Rig: Date: Engineer: Location: Last Csg TD Set ft Mud Tanks Volume BBLs Lag Time Calculati Well M.T.D. ft Csg ID in ROP ft/hr Well T.V.D. ft Drill Pipe O.D. in Mud Density ppg ckness of Cuttings in Hole (Bit) Size in Drill Pipe I.D. in Fan RPM 600 Width of Cuttings in Wt. D.Pipe Length ft Fan RPM 300 Jet / Nozzle Size In Pump Liner Size in . Drill Pipe O.D. in Fan RPM 100 ozzle 1 , 2 Pump Speed strokes/min . Drill Pipe I.D. in Fan RPM 3 ozzle 3 , 4 Size of Pump Rod in Wt. D.P. Mass Lbs/ft Desilter / Desander Input ozzle 5 , 6 Pump Stroke Length in ll Collars Length ft Suction Rate bbl/min ozzle 7 , 8 Drill Collar O.D. in nderflow Density ppg ozzle 9 ,10 ax Operating Press psi Drill Collar I.D. in Underflow Rate gpm zzle 11 ,12 BUOYANCY, WOB & BIT HYDRAULICS Total Nozzle Area TFA in 2 Bit Hydraulic HP rface Press. Losses psi Bit HHP per in 2 or HSI Stand Pipe Pressure psi it Pressure Drop psi Minimum Mud Pump HP t Pressure Drop Fr. % Recommended TFA to maximize HHP in 2 et Impact force, lbf ommended TFA to maximize Impact Force in 2 Available WOB klbs zzle Velocity ft/sec imum TFA for Maximum HHP & Impact Force in 2 VOLUMES, PRESSURES & HOLE CLEANING Pump Output bbl/stroke r g/stroke gallons Volume BBLs Time (min) Pump Output bbl/min or gpm erage Annular Mud Velocity ft/min Bottoms up (Annular Volume) erage Velocity of Cuttings ft/min m Suction to Surface (Hole Volume) ud to displace String for POOH bbl Circulation (total mud system) Minimum Trip Margin to POOH kPa ective Circulating Mud Density (Mud Wt. + Ann. Press Losses) ppg Total Hole Volume (no Pipe in) bbl Maximum ROP for a 4% by volume Cutting Concentration ft/hr Mud Pressure Gradient psi/ft The present Cutting Concentration in the Annulus is (by volume) % ydrostatic Pressure (pump off) at TVD psi OP the Effective Mud Density in the Annulus (without the pressure losses) becomes ppg .Press (drilling) psi e Effective Circulating Mud Density with the above Cuttings Concentration becomes ppg crease in BHP by psi SOLIDS REMOVAL, DESILTER or DESANDER Overflow Mud Density ppg Solids Volume Removed bbl/hr Mud Removed bbl/hr P.V. Cps Overflow Rate bbl/min Solids Mass Removed Lbs/hr nderflow Rate bbl/hr Y.P.Lb/100ft 2 CAPACITIES, VELOCITIES, RHEOLOGIES and PRESSURE LOSSES Per SECTION Hole Size in np Pipe O.D. in na Pipe I.D. in Kp Length ft Ka Capacities in gal/ft Capacities in bbl/ft Section Capacity in gal Section Capacity in bbl Mud Velocity ft/min Mud Velocity ft/sec Critical Velocity ft/min Critical Velocity ft/sec Critical Flow Rate gpm Slip Velocity ft/min Velocity of Cuttings ft/min Transport Efficiency % Lag (Transport) Time min Effective Viscosity m cps Pressure Drop psi
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Hydraulics Calculation
Transcript of Hydraulics Calculation
??? ??? 99-10-22 ????????? 3500 409
7200 8 1/8 25 S. Gravity of Cuttings 2.66000 4 1/2 10.00 2/167 7/8 3 5/6 50 2/16
Surface Equipment Type 1 780 305 4 1/2 16 12 12110 2 7/9 3 120 4212 270 8.00
Working Pumps Number 1 pump 6 1/4 15.003000 2 1/4 12.00
0.3313 18596 3.80
1864 943 JET SELECTION Nozzle Sz
366 50.6 0.2314 10/10/10Buoyancy Factor 0.847 566 0.2693 11/11/10
43.67 325 0.2503 10/11/10
0.073 3.06 Strokes
8.01 336.60 Mud to reach the bit 3973 95.17 11.8 1298193 12552 298.86 37.3 4102140 16525 393.46 49.1 540057 33703 802.46 100 1101468 Bottom Sample Up 51 5653
10.22 450232 0.5200.43 3120
10.05 320410.27 84
9.815 7.328 9.815 207.714 6678 17.143 10
D.C. Section H. Wt. Section D.P. O.H. Section D.P. Casing Section
7 7/8 7 7/8 7 7/8 8 1/80.7365 6 1/4 4 1/2 4 1/2 4 1/20.4776 2 1/4 2 7/9 3 5/6 3 5/61.5513 Poise 270 780 2650 35004.1581 Poise In Pipe Annular In Pipe Annular In Pipe Annular In Pipe Annular
0.20655 0.9365 0.31306 1.70406 0.59725 1.70406 0.59725 1.84410.00492 0.0223 0.00745 0.04057 0.01422 0.04057 0.01422 0.04391
55.8 252.9 244.2 1329.2 1582.7 4515.8 2090.4 6454.41.33 6.02 5.81 31.65 37.68 107.52 49.77 153.681630 359 1075 198 564 198 564 18327.16 5.99 17.92 3.29 9.39 3.29 9.39 3.04
248 197 1974.13 3.28 3.28232 336 336
77.79 77.79 77.79 21.87282 120 120 16178 61 61 881.0 6.5 22.1 21.8
25.75 18.20 30.35 36.44 39.18 36.44 39.18 39.22Reynolds Number 22020 4965 15176 2830 8512 2830 8512 2584
flow type Turbulent Turbulent Turbulent Transitional Turbulent Transitional Turbulent Laminar
Friction Factor 0.0052 0.00582 0.0057 0.00849 0.0067 0.00849 0.0067 0.00929177 13 200 8 158 28 208 32
HYDRAULIC CALCULATIONSWell Name: Rig: Date: Engineer:
Location: Last Csg TD Set ft Mud Tanks Volume BBLs Lag Time Calculation InputWell M.T.D. ft Csg ID in ROP ft/hr
Well T.V.D. ft Drill Pipe O.D. in Mud Density ppg Thickness of Cuttings in
Hole (Bit) Size in Drill Pipe I.D. in Fan RPM 600 Width of Cuttings in
H.Wt. D.Pipe Length ft Fan RPM 300 Jet / Nozzle Size Input in 32sPump Liner Size in H.Wt. Drill Pipe O.D. in Fan RPM 100 Nozzle 1, 2
Pump Speed strokes/min H.Wt. Drill Pipe I.D. in Fan RPM 3 Nozzle 3, 4
Size of Pump Rod in H.Wt. D.P. Mass Lbs/ft Desilter / Desander InputNozzle 5, 6
Pump Stroke Length in Drill Collars Length ft Suction Rate bbl/min Nozzle 7, 8
Drill Collar O.D. in Underflow Density ppg Nozzle 9,10Max Operating Press psi Drill Collar I.D. in Underflow Rate gpm Nozzle 11,12
BUOYANCY, WOB & BIT HYDRAULICSTotal Nozzle Area TFA in2 Bit Hydraulic HP
Surface Press. Losses psi Bit HHP per in2 or HSI
Stand Pipe Pressure psi Bit Pressure Drop psi
Minimum Mud Pump HP Bit Pressure Drop Fr. % Recommended TFA to maximize HHP in2
Jet Impact force, lbf Recommended TFA to maximize Impact Force in2
Available WOB klbs Nozzle Velocity ft/sec Optimum TFA for Maximum HHP & Impact Force in2
VOLUMES, PRESSURES & HOLE CLEANINGPump Output bbl/stroke or g/stroke gallons Volume BBLs Time (min)
Pump Output bbl/min or gpm
Average Annular Mud Velocity ft/min Bottoms up (Annular Volume)
Average Velocity of Cuttings ft/min From Suction to Surface (Hole Volume)
Est. Mud to displace String for POOH bbl Total Circulation (total mud system)
Minimum Trip Margin to POOH kPa
Effective Circulating Mud Density (Mud Wt. + Ann. Press Losses) ppg Total Hole Volume (no Pipe in) bbl
Maximum ROP for a 4% by volume Cutting Concentration ft/hr Mud Pressure Gradient psi/ft
The present Cutting Concentration in the Annulus is (by volume) % Hydrostatic Pressure (pump off) at TVD psi
at this ROP the Effective Mud Density in the Annulus (without the pressure losses) becomes ppg Eff.H.Press (drilling) psi
and the Effective Circulating Mud Density with the above Cuttings Concentration becomes ppg Increase in BHP by psi
SOLIDS REMOVAL, DESILTER or DESANDEROverflow Mud Density ppg Solids Volume Removed bbl/hr Mud Removed bbl/hr P.V. Cps
Overflow Rate bbl/min Solids Mass Removed Lbs/hr Underflow Rate bbl/hr Y.P.Lb/100ft2
CAPACITIES, VELOCITIES, RHEOLOGIES and PRESSURE LOSSES Per SECTION
Hole Size innp Pipe O.D. inna Pipe I.D. inKp Length ftKa
Capacities in gal/ft
Capacities in bbl/ft
Section Capacity in gal
Section Capacity in bbl
Mud Velocity ft/min
Mud Velocity ft/sec
Critical Velocity ft/min
Critical Velocity ft/sec
Critical Flow Rate gpm
Slip Velocity ft/min
Velocity of Cuttings ft/min
Transport Efficiency %
Lag (Transport) Time min
Effective Viscosity m cps
Pressure Drop psi
H5
Jet Sizes 32s mm 7 5.6 8 6.4 9 7.1 10 7.9 11 8.7 12 9.5 13 10.3 14 11.1 15 11.9 16 12.7 18 14.3 20 15.9 22 17.5 24 19.1 26 20.6 28 22.2 30 23.8 32 25.4 36 28.6 40 31.8 Note: 36 = 1.125" or = 11/8" 40 = 1.25" or = 11/4" To obtain the size of any jet in 32s, multiply its size in inches by 32. Example: 1.125" x 32 = 36 or 0.75" x 32 = 24
K5
Jet Sizes 32s mm 7 5.6 8 6.4 9 7.1 10 7.9 11 8.7 12 9.5 13 10.3 14 11.1 15 11.9 16 12.7 18 14.3 20 15.9 22 17.5 24 19.1 26 20.6 28 22.2 30 23.8 32 25.4 36 28.6 40 31.8 Note: 36 = 1.125" or = 11/8" 40 = 1.25" or = 11/4" To obtain the size of any jet in 32s, multiply its size in inches by 32. Example: 1.125" x 32 = 36 or 0.75" x 32 = 24
E6
Jet Sizes 32s mm 7 5.6 8 6.4 9 7.1 10 7.9 11 8.7 12 9.5 13 10.3 14 11.1 15 11.9 16 12.7 18 14.3 20 15.9 22 17.5 24 19.1 26 20.6 28 22.2 30 23.8 32 25.4 36 28.6 40 31.8 Note: 36 = 1.125" or = 11/8" 40 = 1.25" or = 11/4" To obtain the size of any jet in 32s, multiply its size in inches by 32. Example: 1.125" x 32 = 36 or 0.75" x 32 = 24
N6
The average S.G. of the drilling cuttings is 2.6. The Specific Gravity Range for some formations is: Anhydrite..... 2.9 Limestone..... 2.7 - 2.9 Clays.......... 2.5 - 2.7 Dolomite...... 2.86 Salt............ 2.2 Pyrite......... 5.02 Quartz........ 2.65 Sand / SS..... 2.1 - 2.7 Shale.......... 2.2 - 2.9 Slate........... 2.7 - 2.8
E7
Measured T.D. of last Casing String.
N7
If cuttings are round enter same value as below.
E9
Jet Sizes 32s mm 7 5.6 8 6.4 9 7.1 10 7.9 11 8.7 12 9.5 13 10.3 14 11.1 15 11.9 16 12.7 18 14.3 20 15.9 22 17.5 24 19.1 26 20.6 28 22.2 30 23.8 32 25.4 36 28.6 40 31.8 Note: 36 = 1.125" or = 11/8" 40 = 1.25" or = 11/4" To obtain the size of any jet in 32s, multiply its size in inches by 32. Example: 1.125" x 32 = 36 or 0.75" x 32 = 24
H9
If no Heavy Weight Drill Pipe is used, you can enter here half the length of the Drill Pipe in the O.H. Annulus or you can enter 0. (If you do enter in this section regular Drill Pipe values PLEASE DO remember to enter 0 in the Mass cell or else the calculated Available WOB will be WRONG!)
M9
Jet Sizes 32s mm 32s mm 7 5.6 18 14.3 8 6.4 20 15.9 9 7.1 22 17.5 10 7.9 24 19.1 11 8.7 26 20.6 12 9.5 28 22.2 13 10.3 30 23.8 14 11.1 32 25.4 15 11.9 36 28.6 16 12.7 40 31.8 Note: 36 = 1.125" or = 11/8" 40 = 1.25" or = 11/4" To obtain the size of any jet in 32s, multiply its size in inches by 32. Example: 1.125" x 32 = 36 or 0.75" x 32 = 24
E10
Volumetric Efficiency used: Triplex pumps 100% Duplex pumps 90%
E12
For Triplex Pump rod size enter 0.
H12
Heavy Weight Drill Pipe Size & Mass O.D. in I.D.in lbs/ft 3.5…………2.08..….…. 26.0 4.0…………2.58…...…. 28.0 4.5…………2.77…...…. 42.0 5.0…………3.02…….... 50.0
K13
To maintain a healthy mud system, free of fine low gravity solids, the flow rate of the Solids Control Equipment (desilters and desanders) should be around 150% of the drilling flow rate (for centrifuges 110% to 120% is sufficient).
E14
The number of (the same as above) pumps to be used 1 , 2 or 3 ...
H18
Recommendations for main hole drilling (without mud motor): in water based mud systems use 3 - 8 HSI, (most wells require only 3 - 4 HSI) for PDC bits use 3 - 6 HSI In oil based mud systems use 3 - 6 HSI.
E19
After entering (in the Jet section) the sizes of Jets suggested and the Stand Pipe Pressure exceeds the Max. Operating Press, this due to: the Pump OutPut EXCEEDS the Critical Flowrate (see its value below).
N19
For tricone bits, use any number (1 or 2 or 3 or even 4) of jets you like or required with an equal to recommended or to optimum TFA. For PDC bits, use the size combination and the number of jets you need (usually, the larger jets go on the bottom and the smaller ones on the sides of the cutting face) with an equal to recommended or optimum TFA. NOTE: The above recommendations do not apply to drilling with mud motor.
O19
Enter the Nozzle Sizes suggested below to the Nozzle Input table above to improve the Hydraulics of your choice.
E20
Minimum Net Pump Engine Power Requirements to produce the Pump Output and the Pressure needed.
H20
The Bit PD fraction recommended for main hole drilling (without mud motor) is 55 - 65 %.
H22
Recommended jet velocities to drill main hole (without mud motor): in water based mud systems use 350 / 500 ft/sec in oil based mud systems use 250 / 450 ft/sec. Table with Recommended Jets Velocities Formation Type Jet Velocities ft/sec Soft, Gummy..............275 - 315 Fractured, Faulted & Rubble.....295 - 345 Medium to Hard..............330 - 380 Hard..............380 - 480
F29
Calculated for TVD effect on BHP. On vertical wells this value of the Trip Margin is equal to the Annular Frictional Losses during circulating (clean annulus, assuming hole was circulated clean and a flow check contacted). You can also use for Trip Margin the value of Losses during drilling (with cuttings in the annulus adding to the BH pressure) found in CELL O34.
L29
For an accurate calculation of the sample's Lag Time enter the values of Specific Gravity, Thickness of Cuttings and Width of Cuttings as close to actual as possible. (Cuttings are only what the geologist collects, the rest, is just debris from cave-ins and sloughing from higher up the hole).
I32
Try keep it to less than 4% or 5%.
N32
After the annulus is circulated clean.
N33
Adjusted for TVD. To view Effective (or Acting) Hydrostatic pressure while circulating enter 0 for Penetration Rate (ROP).
N36
The increase of the Plastic Viscosity value between mud-checks indicates the accumulation of Low Gravity solids and the need for treatment with water dilution, centrifuge or both.
