Drilling Formulas Calculation Sheet Verson 1.5
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Transcript of Drilling Formulas Calculation Sheet Verson 1.5
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Applied Drilling Formulas
Basic Drilling Formulas
Directional Drilling Calculation
Drilling Fluid Formulas
Engineering Formulas
Hydraulic Formulas
Well Control Formulas
Drill Collar WeightEquivalent Circulating Density (ECD) Using Yield Point for MW less than or equal to 13 ppgEquivalent Circulating Density (ECD) Using Yield Point for MW more than 13 ppgLag timeLight weight spot fill to balance formation pressureLoss of hydrostatic pressure due to filling water into annulus in case of lost returnMargine of OverpullPipe Elongation Due to TemperaturePressure required to break circulationPump out (both duplex and triplex pump)Pump Pressure and Pump Stroke Relationship Stuck Pipe CalculationTon Miles CalculationAccumulator capacityAmount of cuttings drilled per foot of hole drilledAnnular Capacity Annular Velocity (AV)Buoyancy Factor (BF)Convert Temperature UnitConverting Pressure into Mud WeightDepth of washoutD-Exponent and D-Exponent CorrectedDisplacement of plain pipe such as casing, tubing, etc.Drilling Cost Per FootEquivalent Circulating Density (ECD)Formation Integrity Test (FIT)Formation TemperatureHow many feet of drill pipe pulled to lose certain amount of hydrostatic pressure (psi)Hydrostatic Pressure (HP)Hydrostatic Pressure (HP) Decrease When POOHInner Capacity of open hole, inside cylindrical objects Leak Off Test (LOT)Pressure and ForcePressure GradientSlug CalculationSpecific Gravity (SG)Total Bit Revolution in Mud MotorDirectional Survey - Angle Averaging MethodDirectional Survey - Radius of Curvature MethodDirectional Survey - Balanced Tangential MethodDirectional Survey - Minimum Curvature MethodDirectional Survey - Tangential MethodDogleg Severity Calculation based on Radius of Curvature MethodDogleg Severity Calculation based on Tangential MethodBulk Density of Cuttings by using Mud BalanceDecrease oil water ratioDetermine oil water ratio from a retort analysisDetermine the density of oil/water mixture Dilution to control LGSIncrease mud weight by adding BariteIncrease mud weight by adding Calcium CarbonateIncrease mud weight by adding HematiteIncrease oil water ratioMixing Fluids of Different Densities with Pit Space LimitationMixing Fluids of Different Densities without Pit Space LimitationPlastic Viscosity (PV) and Yield Point (YP) from mud testReduce mud weight by dilutionAnnular Pressure LossCritical RPMCalculate Equivalent Circulating Density with Engineering FormulaCritical Flow RateCutting Carrying IndexCutting Slip Velocity Method#1Cutting Slip Velocity Method#2Effective ViscosityHydraulic Horse Power (HPP)Optimum Flow Rate for basic systemPower Law ConstantPressure Loss AnnulusPressure Loss Annulus With Tool Joint CorrectionPressure Loss DrillstringPressure Loss Drillstring With Tool Joint CorrectionPressure Loss in Surface EquipmentReynold NumberSurge and Swab Pressure Method#1Surge and Swab Pressure Method#2Total Flow Area TableActual gas migration rate in a shut in wellAdjusted maximum allowable shut-in casing pressure for new mud weightCalculate Influx HeightEstimate gas migration rate with an empirical equationEstimate type of influxFormation pressure from kick analysisHydrostatic Pressure Loss Due to Gas Cut MudKick Tolerance (Surface Stack and Vertical Well)Kick tolerance factor (KTF)Kill Weight MudMaximum formation pressure (FP)Maximum influx heightMaximum Initial Shut-In Casing Pressure (MISICP)Maximum pit gain from gas kick in water based mudMaximum Surface Pressure from Gas Influx in Water Based MudMaximum surface pressure from kick tolerance informationTrip margin
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Riser Margin
Air Gap 60 ft Input CellsWater Depth 1,600 ft Calculated CellMud Weight 9.30 ppg
Sea Water Weight 8.60 ppgDepth (TVD) 3,000 ftRiser Margin 1.25 ppg
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New Pressure Loss With New Mud (psi)
Original Pressure Loss 1,400 psi Input CellsMud Weight#1 11.50 ppg Calculated CellMud Weight#2 12.50 ppg
New Pressure Loss 1,522 psiBack to the first page
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New Pump Pressure With New Strokes (psi)
Current Pressure 1,600 psi Input CellsSPM 1 70 strks. Calculated CellSPM 2 110 strks.
New Pump Pressure 3,951 psiBack to the first page
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Initial Circulating Pressure (psi)Input Cells
SCR Pressure 450 psi Calculated CellKill Mud Weight 12.00 ppg
Original Mud Weight 10.00 ppgFCP 540 psi
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Initial Circulating Pressure (psi)Input Cells
SCR Pressure 400 psi Calculated CellSIDPP 500 psi
ICP 900 psiBack to the first page
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Tensile Capacity of Drillpipe
OD 5 inch Input CellsNorminal ID 4.276 inch Calculated CellPipe Yield Strenght 135,000 psiWall Thickness (New pipe) 0.362 inch80% wall thickness (Premium Class) 0.290 inchCross Sectional Area of New Pipe 5.275 square inchCross Sectional Area of Premium Pipe 4.154 square inch
712,070 lb 560,764 lb
0.78751186
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Tensile Capacity of New PipeTensile Capacity of Premium Class Pipe
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Plastic Viscosity and Yield Point
Reading at 600 56 Input CellsReading at 300 35 Calculated CellPlastic Viscosity (PV) 21 CPYield Point (YP) 14 lb/100 ft2.
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Kick Tolerance (Surface Stack and Vertical Well)
Previous Casing Shoe MD/TVD 5,500 ftTD depth MD/TVD 9,500 ftPredicted Formation Pressure @ TD 12.0 ppgPore pressure uncertainty 0.5 ppgPlanned MW @ TD 12.0 ppgGas gradient 0.11 psi/ftLeak Off Test at casing shoe 14.7 ppgHole size 12.3 inchDrill pipe size 5.0 inchAverage BHA size 6.5 inchBHA length 850.0 ftAnnular capacity between hole and BHA 0.1047 bbl/ftAnnular capacity between hole and DP 0.1215 bbl/ftMaximum anticipated pressure 12.5 ppgMaximum allowable shut in casing pressur 772.2 psiKick intensity 0.50 ppgUnderbalance 247 psiKick Height 1,021.79 ft1st case: Gas at the bottom 109.89 bbl2nd case: Gas at the shoe 84.52 bblKick Telerance 84.52 bbl
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Input CellsCalculated Cell
Reference
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http://www.drillingformulas.com/kick-tolerance-concept-and-calculation-for-well-design/
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http://www.drillingformulas.com/kick-tolerance-concept-and-calculation-for-well-design/
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Drill Collar WeightInput Cells
Maximum Allowable Tensile Strenght 300 Klb Calculated CellHook Load 100 KlbMargin of Overpull 200 ppgSafety Factor 3.0
Reference
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http://www.drillingformulas.com/margin-of-overpull-in-drillstring/
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Drill Collar Weight Calculation To Prevent Drill Pipe Buckling
Vertical Well Input CellsCalculated Cell
WOB required 50,000 lbSafety Factor 25 %Mud Weight 12 ppgBuoyancy Factor 0.82Drill Collar Weight 76,519 lb
Deviated Well
WOB required 50,000 lbSafety Factor 25 %Mud Weight 12 ppg ReferenceInclination 30 degreeBuoyancy Factor 0.82Drill Collar Weight 88,356 lb
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Pipe Elongation Due to Temperature
Pipe Length 10,000 ft Input CellsSurface Temperature 80 F Calculated CellBottom Hole Temperature 375 FAverage Temperature 227.5 FTemperature Difference 147.5 F ReferencePipe Elongation 122.43 inch
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Equivalent Circulating Density (ECD) Using Yield Point for MW more than 13 ppg
Mud weight 13.5 ppg Input CellsReading at 300 25 Calculated CellReading at 600 40Hole ID 6.2 inchPipe OD 4 inch ReferenceFlow rate 200 ppg http://www.drillingformulas.com/equivalent-circulating-density-ecd-using-yield-point-for-mw-more-than-13-ppg/AV 218.4 ft/minPV 15.0YP 10 CPEquivalent Circulating Density (ECD) 14.2 ppg
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Equivalent Circulating Density (ECD) Using Yield Point for MW less than 13 ppg
Mud weight 9.2 ppg Input CellsReading at 300 25 Calculated CellReading at 600 40Hole ID 6.2 inchPipe OD 4 inch ReferenceYP 10 CPEquivalent Circulating Density (ECD) 9.7 ppg
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Total Bit Revolution in Mud Motor
Rotor rpm 0.2 rev/gpmFlow rate 300 gpmRotary rpm 200 rpmTotal Bit Revolution in Mud Motor 260 rpm
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Input CellsCalculated CellBack to the first page
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Pressure Drop Across a BitFlow rate 800 gpmMud Weight 9 ppg
0.3728Pressure Drop Across a Bit 3446 psiTotal Flow Area in2
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Input CellsCalculated Cell
Reference
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Optimum Flow Rate - Optimzed at The End of The Run
Hole Size 8.500 inchDepth at TD 6000 ftMaxium Surface Pressure 4500 psiMud properties at TD
MW 9.5 ppgPV 14YP 113 rpm 3300 rpm 30600 rpm 33 inchDrill pipe OD 5 inchDrill pipe ID 4.2 inchTool Joint OD 6.5 inchTool Joint ID 3.5 inchDrill collar OD 6.75 inchDrill collar ID 3.5 inchLength of Drill Collar 800 See the table =>Cse (select) 5Cpb 0.006243486B 2.4Cpa 0.003082686Cp 0.009326172Ccb 0.016337Cca 0.016559829Cc 0.032896Vf 1.055788Optimum flow rateMaximum hydraulic horsepower 702 gpmMaximum Impact Force 868 gpm
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Input CellsCalculated Cell
Reference
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http://www.drillingformulas.com/determine-optimum-drilling-flow-rate-for-basic-system-drilling-hydraulics/
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Critical Flow Rate
0.516.63
Mud Weight 10 ppgHole Diameter (Dh) 12.25 inOD of pipe/collar (Do) 5 inCritical Annular Velocity 3.82 ft/secCritical Flow Rate 1172 gpm
Power Law Constant, nPower Law Constant, K
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Input CellsCalculated Cell
Reference
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Cutting Carrying Index
Mud Weight 9.2 ppgAnnular Velocity 140 ft/minPlastic viscosity 17 cpYield Point 15 lbs/100 sq ftn 0.61472K 353.71CCI 1.14Hole cleaning Good Hole Cleaning
If CCI = 1 or greater, the hole cleaning is excellent.If CCI = 0.5 or less poor hole cleaning (expect hole problems).
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Input CellsCalculated Cell
Reference
If CCI = 0.5 or less poor hole cleaning (expect hole problems).
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Reynold Number
Annular Velocity 6 ft/secHole Diameter 8.5 inchDrill pipe OD 5 inchMud Weight 9.5 ppgEffective viscosity 42.53 centipoisePower Law Constan 0.514Reynold Number 3,781
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Input CellsCalculated Cell
Reference
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Power Law Constant
Reading at 300 rpm 32Reading at 3 rpm 3na 0.514Ka 6.628
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Input CellsCalculated Cell
Reference
Back to Critical Flow Rate CalculationBack to the first page
http://www.drillingformulas.com/power-law-constants-n-and-k-calculation/
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Effective Viscosity
Ka 6.629 poisena 0.514Dh 8.5 inchDo 5 inchFlow rate 800 gpmAnnular Velocity 7 ft/secEffective viscosity 42.53 centipoise
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Input CellsCalculated Cell
Reference
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Pressure loss through surface equipmentGeneral coefficient for surface equipment (Cse) 8 See =>Mud Weight 9.5 ppgPlastic Viscosity 12 centipoiseFlow rate 600 gpmPressure loss through surface equipment 155.0 psi
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Input CellsCalculated CellBack to the first page
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Pressure loss in annulus with corrected coefficient
Length of drill pipe 2500 ftOD of drill pipe 5 inchOD of drill pipe tool joint 6 inchLength of drill collar 500 ftOD of drill collar 5 inchHole size 9 inchMud Weight 9.5 ppgPlastic Viscosity 12 centipoiseFlow rate 600 gpm
2.4
0.001733
0.001645
63 psi
12 psi
Total Pressure loss in the annulus 74 psi
B parameter (see the table)
Coefficient for annulus around drillpipe and tool joint
Coefficient for annulus around drill collar
Pressure loss in the annulus around drill pipe
Pressure loss in the annulus around drill collar
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Input CellsCalculated CellBack to the first page
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Pressure loss in annulus
Length of drill pipe/drill collar 2500 ftOD of drill pipe/drill collar 5 inchHole size 8.835 inchMud Weight 9.5 ppgPlastic Viscosity 12 centipoiseFlow rate 600 gpm
2.4General coefficient 0.001912Pressure loss in the annulus 69 psi
B parameter (see the table)
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Input CellsCalculated CellBack to the first page
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Pressure loss through the drill string with tool joint coefficient
Length of drill pipe 5000 ftID of drill pipe 3.34 inchTool joint ID of drill pipe 2.563 inchLength of drill collar 500 ftID of drill collar 2.8 inchMud Weight 9.5 ppgPlastic Viscosity 12 centipoiseFlow rate 600 gpmGeneral coefficient for drill pipe 0.0204General coefficient for drill collar 0.0483Pressure loss through the drill pipe 1473 psiPressure loss through the drill collar 349 psiTotal pressure in drill string 1821 psi
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Input CellsCalculated CellBack to the first page
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Pressure loss through the drill string
Length of drill pipe 5000 ftID of drill pipe 3.34 inchLength of drill collar 500 ftID of drill collar 2.8 inchMud Weight 9.5 ppgPlastic Viscosity 12 centipoiseFlow rate 600 gpmGeneral coefficient for drill pipe 0.0174General coefficient for drill collar 0.0409Pressure loss through the drill pipe 1254 psiPressure loss through the drill collar 295 psiTotal pressure in drill string 1549 psi
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Input CellsCalculated CellBack to the first page
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Nozzle size (x/32)7 0.0376 0.0752 0.1127 0.1503 0.1879 0.22558 0.0491 0.0982 0.1473 0.1963 0.2454 0.29459 0.0621 0.1243 0.1864 0.2485 0.3106 0.3728
10 0.0767 0.1534 0.2301 0.3068 0.3835 0.460211 0.0928 0.1856 0.2784 0.3712 0.4640 0.556812 0.1104 0.2209 0.3313 0.4418 0.5522 0.662713 0.1296 0.2592 0.3889 0.5185 0.6481 0.777714 0.1503 0.3007 0.4510 0.6013 0.7517 0.902015 0.1726 0.3451 0.5177 0.6903 0.8629 1.035416 0.1963 0.3927 0.5890 0.7854 0.9817 1.178117 0.2217 0.4433 0.6650 0.8866 1.1083 1.330018 0.2485 0.4970 0.7455 0.9940 1.2425 1.491019 0.2769 0.5538 0.8307 1.1075 1.3844 1.661320 0.3068 0.6136 0.9204 1.2272 1.5340 1.840821 0.3382 0.6765 1.0147 1.3530 1.6912 2.029522 0.3712 0.7424 1.1137 1.4849 1.8561 2.227323 0.4057 0.8115 1.2172 1.6230 2.0287 2.434424 0.4418 0.8836 1.3254 1.7671 2.2089 2.650725 0.4794 0.9587 1.4381 1.9175 2.3968 2.876226 0.5185 1.0370 1.5555 2.0739 2.5924 3.110927 0.5591 1.1183 1.6774 2.2365 2.7957 3.354828 0.6013 1.2026 1.8040 2.4053 3.0066 3.607929 0.6450 1.2901 1.9351 2.5802 3.2252 3.870230 0.6903 1.3806 2.0709 2.7612 3.4515 4.1417
1Nozzle
2Nozzles
3Nozzles
4Nozzles
5Nozzles
6Nozzles
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0.2631 0.3007 0.33820.3436 0.3927 0.44180.4349 0.4970 0.55910.5369 0.6136 0.69030.6496 0.7424 0.83530.7731 0.8836 0.99400.9073 1.0370 1.16661.0523 1.2026 1.35301.2080 1.3806 1.55321.3744 1.5708 1.76711.5516 1.7733 1.99491.7395 1.9880 2.23651.9382 2.2151 2.49202.1476 2.4544 2.76122.3677 2.7059 3.04422.5986 2.9698 3.34102.8402 3.2459 3.65163.0925 3.5343 3.97613.3556 3.8350 4.31433.6294 4.1479 4.66643.9140 4.4731 5.03224.2092 4.8106 5.41194.5153 5.1603 5.80544.8320 5.5223 6.2126
7Nozzles
8Nozzles
9Nozzles
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Surge and swab pressure method#2
θ300 85θ600 130Hole diameter 9.000 inchDrillpipe diameter 5 inchDrill collar diameter 6.25 inchAverage pipe running or pulling speed 250 ft/minDrill Pipe Length 12000 ftDrill collar length 800 ftCurrent Mud Weight 12.5 ppgWell TVD 9000 ft
PV 45n 0.613K 1.863Fluid Velocity (Closed Ended Pipe) around drill pipe 224.1 ft/minMaximum pipe velocity around drill pipe 336.2 ft/minShear rate of mud around drill pipe (Ym) 201.7Shear stress of mud around drill pipe (T) 48.1Fluid Velocity (Closed Ended Pipe) around drill collar 345.4 ft/minMaximum pipe velocity around drill collar 518.0 ft/minEquivalent flow rate around drill collar 886.8 gpmPressure lose around drill pipe 480.5 psiPressure loss around drill collar 71.8 psiTotal Pressure Loss 552.2 psi
6402.2 psi13.7 ppg
5297.8 psi11.3 ppg
Surge: Bottom Hole PressureSurge: Bottom Hole Pressure in ppgSwab: Bottom Hole PressureSwab: Bottom Hole Pressure in ppg
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Surge and swab pressure method#1
θ300 47θ600 80Hole diameter 6.35 inchDrill Collar 5 inchID of drill collar 2.25 inchDrillpipe diameter 4 inchID of drill pipe 3.34 inchAverage pipe running or pulling speed 20 ft/minDrill Pipe Length 12270 ftDrill Collar Length 100 ftCurrent Mud Weight 13.2 ppgWell TVD 9972 ftSelect Criteria ---> Open Ended Pipe
n 0.767K 0.394
Fluid volocity around drill pipe (Open ended pipe) 11.7 ft/minMaximum pipe velocity around drill pipe 17.6 ft/minPressure Loss around drill pipe 67.6 psi
Fluid volocity around drill collar (Open ended pipe) 28.6 ft/minMaximum pipe velocity around drill collar 42.8 ft/minPressure Loss around drill collar 2.9 psiTotal pressure loss 70.5 psi
6915.3 psi13.3 ppg
6774.3 psi13.1 ppg
Surge: Bottom Hole PressureSurge: Bottom Hole Pressure in ppgSwab: Bottom Hole PressureSwab: Bottom Hole Pressure in ppg
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Cutting Slip Velocity Method#2
θ300 32θ600 49Flow rate 600 gpmHole diameter 11.50 inchDrillpipe Diameter 5 inchDiameter of cutting 0.75 inchDensity of cutting 21.5 ppgMud Weight 9.2 ppg
n 0.614K 0.694Viscosity 82.40 cpAnnular Velocity 137.1 ft/min Moving UpCutting Slip Velocity 76.93 ft/min Falling DownNet cutting rise velocity 60.1 ft/min Good
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Cutting Slip Velocity Method#1Flow rate 600 gpmHole Diameter 11.5 inchDrillpipe OD 5 inchPV 17 cpsMW 9.2 ppgDiameter of cutting 0.75 inchDensity of cutting 21.5 ppg
Annular Velocity 137.1 ft/min Moving UpCutting Slip Velocity 85.34 ft/min Falling DownNet cutting rise velocity 51.7 ft/min Good
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Maximum pit gain from gas kick in water based mud
3620 psiPit volume gain 20 bbl
14.5 ppg0.1215 bbl/ft
Maximum pit gain 98.5 bbl
Expected formation pressure
Kill Weight MudAnnular Capacity
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Maximum Surface Pressure from Gas Influx in Water Based Mud
6378 psiPit volume gain 25 bbl
13 ppg0.0459 bbl/ft
Maximum Surface Pressure 1344 psi
Expected formation pressure
Kill Weight MudAnnular Capacity
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Hydrostatic Pressure Loss Due to Gas Cut
Mud weight 12 ppg0.0352 bbl/ft
Pit volume gain 15 bblHydrostatic Pressure Loss Due to Gas Cut 266 ft
Annular Capacity
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Calculate Influx Height
Pit volume gain 12 bblAnnular Capacity 0.0459 bbl/ftInflux height 261 ft
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Kill Mud Weight
Shut in Drillpipe Pressure 500 psiCurrent Mud Weight 9.5 ppgHole TVD 9000 ftKill Mud Weight 10.6 ppg
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Acutal gas migration rate
Increase in pressure 200 psi/hrMud Weight 12 ppgAcutal gas migration rate 321 ft/hr
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Estimate gas migration rate with an empirical equation.
Current Mud Weight 12 ppgVg 0.14 ft/secVg 510 ft/hr
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Estimate Type of Influx (kick)
Shut in casing pressure 1050 psiShut in drill pipe pressure 750 psiHeight of influx 450 ftCurrent Mud Weight 14 ppgInflux weight 1.2 ppgType of influx Gas Influx
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Formation Pressure from Kick Analysis
Shut in drill pipe pressure 550 psiHole TVD 6000 ftCurrent Mud Weight 10.2 ppgFormation Pressure 3732 psi
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Adjusted maximum allowable shut-in casing pressure for new mud weight
Leak off test pressure 1000 psiCasing shoe TVD 4500 ftOriginal Mud Weight 9.5 ppgCurrent Mud Weight 12 ppgNew MASICP 415 psi
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Adjusted maximum allowable shut-in casing pressure for new mud weight
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Maximum possible influx height when equal to maximum allowable shut in casing pressure
Maximum Allowable Shut-In Casing Pressure (MASICP) 874 psiMud gradient 0.52 psi/ftInflux gradient 0.12 psi/ftMaximum possible influx height 2185 ft
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Maximum possible influx height when equal to maximum allowable shut in casing pressure
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Maximum Initial Shut-In Casing Pressure (MISICP)
Leak off test pressure 15 ppgCurrent mud weight 12.2 ppgCasing shoe depth 4000 ftMaximum allowable shut in casing pressure 582.4 psi
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Maximum formation pressure that can wistand when shut in the well.
Kick tolerance factor 1.68 ppgMud weight 10 ppgHole TVD 10000 ftMaximum formation pressure 6,074 psi
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Maximum formation pressure that can wistand when shut in the well.
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Maximum surface pressure from kick tolerance information
Kick tolerance factor 1.68 ppgBottom hole, TVD 10000 ftMaximum pressure 873.6 psi
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Maximum surface pressure from kick tolerance information
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Kick tolerance factor (KTF)
Casing shoe TVD 4000 ftWell depth TVD 10000 ftMaximum allowable mud weight 14.2 ppgCurrent mud weight 10 ppgKick tolerance factor (KTF) 1.68 ppg
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Trip margin calculation
Mud Yield Point 10 lb/100 sq ftHole Diameter 8.5 inDrillpipe Diameter 4.5 inTrip Margin 0.2 ppg
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Lag Time CalculationPump speed 300 GPMPump Output 0.102 bbl/strokeAnnular Volume 250 bblLag time in minutes 35 minutesLag time in strokes 2451 strokes
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Ton Mile Calculation
Round-trip ton-mileMud Weight 10 ppgMeasured depth (D) 5500 ftDrillpipe weight 13.3 lb/ftdrill collar weight 85 lb/ftdrill collar length 120 ftHWDP weight 49 lb/ftHWDP length 450 ftBHA weight in air 8300 lbLength of BHA 94 ftBlock weight (Wb) 95000 lbAverage length of one stand (Lp) 94 ftBuoyancy factor 0.847Buoyed weight of drill pipe (Wp) 11.27 lb/ft
26,876.24 lb258.75 Ton mile
Drilling or Connection Ton-miles
230 ton-miles
195 ton-milesTon-miles for drilling (Td) 105.00 ton-miles
Ton-miles for Coring Operation
200 ton-miles
190 ton-milesTon-miles for drilling (TC) 20.00 ton-miles
Ton-Miles for Setting CasingMud weight 10 ppgCasing weight 25 lb/ftDepht of casing set 5200 ftTravelling block weight 95000 lbLength of one joint of casing 42 ftBuoyancy factor 0.847Ton-Miles for Setting Casing 50.73 ton-miles
Ton-Miles for Short Trip
200 ton-miles
190 ton-milesTon-miles for drilling (TC) 10.00 ton-miles
Buoyed weight of BHA (drill collar + heavy weight drill pipe + BHA) in mud minus the buoyed weight of the same length of drill pipe (Wc)Round-trip ton-mile (RT TM)
Ton-miles for one round trip of last depth before coming out of hole. (T2)
Ton-miles for one round trip of first depth that drilling is started. (T1)
Ton-miles for one round trip at depth where coring operation stopped before coming out of hole (T4)
Ton-miles for one round trip at depth where coring get started (T3)
Ton-miles for one round trip at the deeper depth(T6)
Ton-miles for one round trip at the shallower depth (T5)
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“d” ExponentRate of penetration (R) 90 f/hrRotary drilling speed (N) 110 rpmWeight on bit (W) 20 klbBit Diameter (D) 8.5 inchD-exponent, dimensionless 1.20
“d” Exponent CorrectedRate of penetration (R) 90 f/hrRotary drilling speed (N) 110 rpmWeight on bit (W) 20 klbBit Diameter (D) 8.5 inchInitial mud weight in ppg (MW1) 9 ppgActual mud weight in ppg (MW2) 12 ppgD-exponent, dimensionless 0.90
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http://www.drillingformulas.com/corrected-d-exponent/
http://www.drillingformulas.com/
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Dilution to Control LGS
1st case: Dilution by adding base fluid or water
Total barrels of mud in circulating system 1000Percent low gravity solids in system 6Percent total low gravity solids desired 4Barrels of dilution water or base fluid 500.0
2nd case: Dilution by adding drilling fluid
Total barrels of mud in circulating system 2000Percent low gravity solids in system 7Percent total low gravity solids desired 3.5
2Barrels of dilution water or base fluid 4666.7
Percent low gravity solids bentonite and/or chemicals added in mud
![Page 107: Drilling Formulas Calculation Sheet Verson 1.5](https://reader036.fdocuments.us/reader036/viewer/2022062321/55cf9723550346d0338fe84b/html5/thumbnails/107.jpg)
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http://www.drillingformulas.com/dilution-of-mud-system-to-control-low-gravity-solid-by-adding-mud/
http://www.drillingformulas.com/
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Decrease oil water ratio% by volume oil 56% by volume water 14% by volume solids 30Total mud volume, bbl 300
80%20%
7030
10.00 bblTotal volume of water added into the system 30.00 bbl
% original oil in liquid phase% original water in liquid phase% new oil in liquip phase% new water in liquid phaseWater added per 100 bbl of original mud
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Increase oil water ratio% by volume oil 51% by volume water 17% by volume solids 32
75%25%
8020
Oil added per 100 bbl of original mud 17.00 bbl
% original oil in liquid phase% original water in liquid phase% new oil in liquip phase% new water in liquid phase
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Determine oil water ratio from a retort analysis
% by volume oil 56% by volume water 14% by volume solids 30% oil in liquid phase 80%% water in liquid phase 20%Oil/Water ratio 80/20
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Determine the density of oil/water mixture
Percentage of oil 80Percentage of water 20Density of oil 7 ppgDensity of water 8.33 ppgFinal density 7.27 ppg
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Mud Weight#1 10 ppgMud Weight#2 14 ppgVolume of Mud#1 200 bblVolume of Mud#2 300 bblTotal volume 500 bblFinal Mud Weight 12.4 ppg
Mix different fluid density: Case#2 unlimit space
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Mud Weight#1 10 ppgMud Weight#2 14 ppgFinal Mud Weight 12 ppgFinal Volume 300 bblVolume of Mud#1 150 bblVolume of Mud#2 150 bbl
Mix different fluid density: Case#1 limit space
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Reduce mud weight (dilution)
Strating volume (V1) in bbl 200 bblStart drilling fluid weight in ppg (W1) 13.8 ppgFinal drilling fluid weight in ppg (W2) 10 ppgDensity of light weight fluid in ppg (Dw) 7.2 ppgLight weight fluid required in bbl 271.4 bbl
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Current Mud Weight, ppg 10.0 ppgNew Mud Weight, ppg 13.0 ppgTotal mud in the system 500.0 bblSacks of Barite per 100 bbl of mud 186.7 sacksTotal sacks of barite required 933.3 sacks
Current Mud Weight, ppg 10.0 ppgNew Mud Weight, ppg 13.0 ppgTotal mud in the system 500.0 bblVolume in bbl increase per 100 bbl of mud 11.11 bblTotal volume increase in bbl 55.56 bbl
Current Mud Weight in ppg 10.0 ppgNew Mud Weight in ppg 13.0 ppgFinal volume in bbl 100.0 bblStarting volume in bbl 90.00 bbl
Increase Mud Density by adding Hematite
Volume of mud in bbl increase due to mud weight increase by adding Hematite
Starting volume in bbl of original mud weight required to achieve a predetermined final volume of desired mud weight with
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Starting volume in bbl of original mud weight required to achieve a predetermined final volume of desired mud weight with Hematite
http://www.drillingformulas.com/starting-volume-weight-up-with-hematite/
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Current Mud Weight, ppg 10.0 ppgNew Mud Weight, ppg 13.0 ppgTotal mud in the system 500.0 bblSacks of Barite per 100 bbl of mud 298 sacksTotal sacks of barite required 1492 sacks
Current Mud Weight, ppg 10.0 ppgNew Mud Weight, ppg 13.0 ppgTotal mud in the system 500.0 bblVolume in bbl increase per 100 bbl of mud 31.58 bblTotal volume increase in bbl 157.89 bbl
Current Mud Weight in ppg 10.0 ppgNew Mud Weight in ppg 13.0 ppgFinal volume in bbl 100.0 bblStarting volume in bbl 76.00 bbl
Increase Mud Density by adding Carbonate
Volume of mud in bbl increase due to mud weight increase by adding Carbonate
Starting volume in bbl of original mud weight required to achieve a predetermined final volume of desired mud weight with
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Starting volume in bbl of original mud weight required to achieve a predetermined final volume of desired mud weight with Carbonate
http://www.drillingformulas.com/starting-volume-of-original-mud-weight-up-with-calcium-carbonate/
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Current Mud Weight, ppg 10.1 ppgNew Mud Weight, ppg 11.1 ppgTotal mud in the system 1000.0 bblSacks of Barite per 100 bbl of mud 61.5 sacksTotal sacks of barite required 615.1 sacks
Current Mud Weight, ppg 9.2 ppgNew Mud Weight, ppg 10.1 ppgTotal mud in the system 650.0 bblVolume in bbl increase per 100 bbl of mud 3.61 bblTotal volume increase in bbl 23.49 bbl
Current Mud Weight in ppg 10.0 ppgNew Mud Weight in ppg 13.0 ppgFinal volume in bbl 100.0 bblStarting volume in bbl 88.00 bbl
Increase Mud Density by adding Barite
Volume of mud in bbl increase due to mud weight increase by adding Barite
Starting volume in bbl of original mud weight required to achieve a predetermined final volume of desired mud weight with
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http://www.drillingformulas.com/volume-of-mud-increase-due-to-mud-weight-increase-by-adding-barite/
Starting volume in bbl of original mud weight required to achieve a predetermined final volume of desired mud weight with Barite
http://www.drillingformulas.com/starting-volume-of-original-mud-weight-up-with-barite/
http://www.drillingformulas.com/
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Pressure required to break circulation
10 min get strenght of mud, lb/100 sq ft 12 lb/100 sq ftInside diameter of drill pipe in inch 3.32 inLength of drill string in ft 11500 ftPressure required to break circulation inside drill string 138.6 psi
10 min get strenght of mud, lb/100 sq ft 12 lb/100 sq ftOutside diameter of drill pipe in inch 4 inHole diameter in inch 6.5 inLength of drill string in ft 11500 ftPressure required to break circulation inside drill string 184.0 psi
Pressure required overcoming the mud’s gel strength inside the drill string.
Pressure required overcoming the mud’s gel strength in the annulus.
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Light weight spot fill to balance formation pressure
Current mud weight, ppg 13 ppgOverblance with current mud weight, psi 300 psiWeigth of light weight pill, ppg 8.3 ppgHeight of light weight pill, ft, in annulus 1227 ft
You must ensure than height of light weight pill in the annulus must less than 1227 ft in order to prevent wellcontrol situation.
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You must ensure than height of light weight pill in the annulus must less than 1227 ft in order to prevent wellcontrol situation.
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Loss of hydrostatic pressure due to filling water into annulus in case of lost return
Current Mud Weight in ppg 13 ppgWater Weight in ppg 8.6 ppgTVD in ft 6000 ftAnnular Capacity in bbl/ft 0.1422 bbl/ftWater filled into annulus in bbl 140 bblFeet of water in annuls 984.5 ftHydrostaic Pressure decrease 225.3 psiEquivalent Mud Weigth at TD 12.3 ppg
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Loss of hydrostatic pressure due to filling water into annulus in case of lost return
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Displacment of plain pipe such as casing, tubing, etc.
OD 9.625 inchID 8.835 inchDisplacment in bbl/ft 0.01417 bbl/ft
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Stuck Pipe Calculation
Stretch in inch 5 inchFree point constant 28634.51Pull force in Klb 100 KlbDepth of stuck pipe 1431.73 ft
Free Point Constant (FPC) calculationOutside Diameter 9.625 inchInside Diameter 8.835 inchFPC 28634.51
Sutck Pipe Calculation (in case of not know Free Point Constant (FPC))
Stretch in inch 5 inchPull force in Klb 100 KlbOutside Diameter 9.625 inchInside Diameter 8.835 inchDepth of stuck pipe 1431.73 ft
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Sutck Pipe Calculation (in case of not know Free Point Constant (FPC))Reference
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Accumulator Capacity
Suface ApplicationVolume per bottle 10 galPre-charge pressure 1000 psiMinimum System Pressure 1200 psiOperating Pressure 3000 psiUsable Volume per bottle 5.00 gal
Subsea ApplicationVolume per bottle 10 galPre-charge pressure 1000 psiMinimum System Pressure 1200 psiOperating Pressure 3000 psiPressure gradient of hydraulic fluid 0.445 psi/ftWater depth 1500 ftUsable Volume per bottle 4.38 gal
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Calculate inner capacity of open hole, inside cylindrical objects such as tubulars, drill pipe, drill collars, tubing, casing etc
Hole size, Casing ID, Tubing ID, etc 6.1250.0364
Hole size, Casing ID, Tubing ID, etc 6.12527.4392
Hole size, Casing ID, Tubing ID, etc 6.1251.5306
Hole size, Casing ID, Tubing ID, etc 6.1250.6533
Calculate capacity in bbl/ft
Capacity in bbl/ft
Calculate capacity in ft/bbl
Capacity in ft/bbl
Calculate capacity in gal/ft
Capacity in gal/ft
Calculate capacity in ft/gal
Capacity in ft/gal
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Calculate inner capacity of open hole, inside cylindrical objects such as tubulars, drill pipe, drill collars, tubing, casing etc
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Annular capacity between casing or hole and drill pipe, tubing, or casing.
Hole size, casing ID in inch 8.5Drill pipe size, DC size or casing/tubing OD 5
0.04590
Hole size, casing ID in inch 6.125Drill pipe size, DC size or casing/tubing OD 3.5
40.743
Hole size, casing ID in inch 6.125Drill pipe size, DC size or casing/tubing OD 3.5
1.031
Hole size, casing ID in inch 6.125Drill pipe size, DC size or casing/tubing OD 3.5
0.970
Calculate annular capacity in bbl/ft
Annular capacity, bbl/ft
Calculate annular capacity in ft/bbl
Annular capacity, ft/bbl
Calculate annular capacity in gal/ft
Annular capacity, gal/ft
Calculate annular capacity in ft/gal
Annular capacity, ft/gal
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Annular capacity between casing or hole and drill pipe, tubing, or casing.
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Cost Per Foot Calculation
Bit cost (B), $ 27000Rig cost (CR), $/hr 3500Rotating time (t), hrs 50Round trip time (T), hrs 12Footage per bit (F), ft 5000Cost per foot , $/ft 48.80
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Pump Pressure and Pump Stroke Relationship
Basic Calculation
Current Circulating Pressure, psi 2500Old Pump Rate, SPM 40New Pump Rate, SPM 25New Circulating Pressure, psi 976.6
Advanced calculation (Determine factor)
Pressure 1, psi 2700Flow rate1, gpm 320Pressure 2, psi 500Flow rate2, gpm 130Factor 1.872Current Circulating Pressure, psi 2500Old Pump Rate, SPM 40New Pump Rate, SPM 25New Circulating Pressure, psi 1037.0
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Hydraulic Horse Power (HPP)
Circulating Pressure, psi 3500Flow rate, GPM 800Hydraulic Horse Power (HPP) 1633.61
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Formation Temperature
Surface Temperature, F 90Temperature Gradient, F/ft 0.015Formation Depth in TVD, ft 12000Formation Temperature, F 270
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Critical RPM to prevent pipe failure due to high vibrationJust rough estimate 15% accurate
Length of one joint of drill pipe, ft 32OD of drill pipe, inch 4ID of drill pipe, inch 3.5Critical RPM 172
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Input cellscalculated cells
Reference
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Calculate Equivalent Circulating Density with Engineering Formula
Mud weight 13.2Reading at 300 47Reading at 600 80PV 33Pump rate, gpm 165Hole diameter, in 6.35Drill pipe OD, in 4Drill pipe length, ft 12276Drill collar OD, in 5Drill collar length, ft 100TVD, ft 10000
n 0.767K 0.394Annular velocity around DP, ft/min 166.2 Lamina FlowCritical velocity around DP, ft/min 327.9Annular velocity around DC, ft/min 263.8 Lamina FlowCritical velocity around DC, ft/min 462.9Pressure loss around DP 378.5Pressure loss around DC 8.2Total annular pressure loss 386.7
ECD at 10000' TVD in ppg 13.94
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http://www.drillingformulas.com/calculate-equivalent-circulation-density-ecd-with-complex-engineering-equations/
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Annular Pressure Loss
Mud Weight in ppg 13.0 Input cellsLength in ft 8000.0 calculated cellsFlow rate in GPM 320.0Dh, in 6.50Dp, in 4.00 Referencevelocity, ft/min 298.7P loss annular in psi 531.65 Website
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Direcional Survey CalculationAngle Averaging Method
Survey1 Survey2Depth (ft) 7482 7782Inclination (degree) 4 8Azimuth (degree) 10 35
North 28.97 ftEast 12.00 ftVertical 298.36 ft
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Direcional Survey CalculationRadius of Curvature Method
Survey1 Survey2Depth (ft) 7482 7782Inclination (degree) 4 8Azimuth (degree) 10 35
North 28.74 ftEast 11.90 ftVertical 298.30 ft
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Direcional Survey CalculationBalanced Tangential Method
Survey1 Survey2Depth (ft) 3500 3600Inclination (degree) 15 25Azimuth (degree) 20 45
North 27.10 ftEast 19.37 ftVertical 93.61 ft
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Direcional Survey CalculationMinimum Curvature Method
Survey1 Survey2Depth (ft) 3500 3600Inclination (degree) 15.00 25.00Azimuth (degree) 20.00 45.00
β 0.22605 radiansRF 1.00428North 27.22 ftEast 19.45 ftVertical 94.01 ft
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Direcional Survey CalculationTangential Method
Survey1 Survey2Depth (ft) 3500 3600Inclination (degree) 15.00 25.00Azimuth (degree) 20.00 45.00
North 29.88 ftEast 29.88 ftVertical 90.63 ft
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Survey1 Survey2Depth (ft) 4231 4262Inclination (degree) 13.5 14.7Azimuth (degree) 10 19
Dogleg severity 8.05 degree/100 ft
Calculate dogleg severity between 2 survey points based on
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Input cellscalculated cells
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Calculate dogleg severity between 2 survey points based on Radius of Curvature Method
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Survey1 Survey2Depth (ft) 4231 4262Inclination (degree) 13.5 14.7Azimuth (degree) 10 19
Dogleg severity 3.23 degree/100 ft
Calculate dogleg severity between 2 survey points based on
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Calculate dogleg severity between 2 survey points based on tangential method
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Determine force with given pressure and areaPressure 500 psi
Area 3Force 1500 lb
orDetermine force with given pressure and diameterPressure 500 psiDiameter 3 inForce 3534.3 lb
in2
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Input cells
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Leak Off Test Pressure Converted to Equivalent Mud Weight (LOT)
LOT pressure (psi) 1600 psiMud Weight (ppg) 9.2 ppgShoe Depth (TVD) 4000 ftLOT equivalent mud weight 16.9 ppg
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Leak Off Test Pressure Converted to Equivalent Mud Weight (LOT)
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Pressure Required Formation Integrity Test (FIT)FIT required (ppg) 14.5 ppgMud Weight (ppg) 9.2 ppgShoe Depth (TVD) 4000 ftPressure required (psi) 1102.4
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Equivalent Circulating Density (ECD), ppgAnnular pressure loss(psi) 400 psiMud weight (ppg) 10 ppgTVD (ft) 8000 ftECD 11.0 PPG
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Specific Gravity (SG)Specific gravity using mud weight, ppgMud weight (ppg) 13 ppgSG 1.56
Specific gravity using pressure gradient, psi/ftPressure gradient (psi/ft) 0.50 psi/ftSG 1.15
Mud weight (lb/ft3) 90.00 lb/ft3SG 1.44
Convert specific gravity to mud weight, ppgSG 1.50MW (ppg) 12.50 ppg
Convert specific gravity to pressure gradient, psi/ftSG 1.50Pressure Gradient (psi/ft) 0.650 psi/ft
SG 1.50Mud weight (lb/ft3) 93.600 lb/ft3
Specific gravity using mud weight, lb/ft3
Convert specific gravity to mud weight, lb/ft3
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Converting Pressure into Mud WeightConvert pressure, psi, into mud weight, ppg using feet as the unit of measurePressure (psi) 5000 psiTVD (ft) 8000 ftMW (ppg) 12.0 PPG
Convert pressure, psi, into mud weight, ppg using meters as the unit of measurePressure (psi) 5000 psiTVD (m) 2500 mMW (ppg) 11.7 PPG
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Barrels of slug required for a desired length of dry pipe
Desired length of dry pipe (ft) 400 ftDrill pipe capacity (bbl/ft) 0.015 bbl/ftCurrent MW (PPG) 11.5 ppgSlug Weight (PPG) 12.5 ppg
Hydrostatic pressure required to give desired drop inside drill pipe 239.2 psiDifference in pressure gradient bw slug and current MW 0.052 psi/ftLength of slug in drill pipe (ft) 4600 ftSlug Volume 69.00 bbl
Weight of slug required for a desired length of dry pipe with a set volume of slug
Desired length of dry pipe (ft) 400 ftSlug Volume (bbl) 30 bblDrill pipe capacity (bbl/ft) 0.015 bbl/ftCurrent MW (PPG) 11.5 ppg
Slug length (ft) 2000.0 ftHydrostatic Pressure required (psi) 239.2 psiWeight of slug (PPG) 13.8 ppg
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Hydrostatic Pressure (HP)Hydrostatic pressure using ppg and feet as the units of measureMud weight 12 ppgTVD (ft) 10000 ftHydrostatic Pressure (psi) 6240.0 psi
Hydrostatic pressure, psi, using pressure gradient, psi/ftPressure gradient (psi/ft) 0.5 psi/ftTVD (ft) 10000 ftHydrostatic Pressure (psi) 5000.0 psi
Mud weight (lb/ft3) 80 lb/ft3TVD (ft) 10000 ftHydrostatic Pressure (psi) 5555.2 psi
Hydrostatic pressure, psi, using meters as unit of depthMud weight 12 ppgTVD (m) 5000 mHydrostatic Pressure (psi) 10236.7 psi
Hydrostatic pressure, psi, using mud weight, lb/ft3
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Hydrostatic pressure using ppg and feet as the units of measureInput cellscalculated cells
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Annular Velocity (AV) in ft/minFormula 1: AV = pump output, bbl/min ÷ annular capacity, bbl/ftPump out put (bbl/min) 10 bbl/minAnnular capacity (bbl/ft) 0.13 bbl/ftAnnular Velocity (AV) 76.92 ft/minFormula 2: Flow rate in gpm and diameter between 2 diametersFlow rate (gpm) 800 gpmBigger diameter (in) 10 in such as hole size, casing ID, etcSmaller diameter (in) 5 in such as drill pipe OD, tubing OD, etcAnnular Velocity (AV) 261.33 ft/minFormula 3: flow rate in bbl/min and diameterFlow rate (bbl/min) 13 bbl/minBigger diameter (in) 10 in such as hole size, casing ID, etcSmaller diameter (in) 5 in such as drill pipe OD, tubing OD, etcAnnular Velocity (AV) 178.43 ft/min
Annular velocity (AV), ft/secFormula 1: Flow rate in bbl/min and diameter between 2 diametersFlow rate (bbl/min) 13 bbl/minBigger diameter (in) 10 inSmaller diameter (in) 5 inAnnular Velocity (AV) 2.97 ft/secPump output in gpm required for a desired annular velocity, ft/mimAnnular Velocity (ft/min) 120 ft/minBigger diameter (in) 10 inSmaller diameter (in) 5 inRequired pump rate (gpm) 367.35 gpmStrokes per minute (SPM) required for a given annular velocityAnnular Velocity (ft/min) 150 ft/minBigger diameter (in) 10 inSmaller diameter (in) 5 inPump out put (bbl/stk) 0.1 bbl/stkSPM required 109.29 spm
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Pump outTriplex Pump, bbl/stkefficiency (%) 97Liner diameter (in) 6 inStroke length (in) 12 inPO (bbl/stk) 0.10183 bbl/stk
Duplex Pump , bbl/stkefficiency (%) 85Liner diameter (in) 6 inRod diameter (in) 2 inStroke length (in) 12 inPO (bbl/stk) 0.11236 bbl/stk
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Buoyancy Factor (BF)
Buoyancy factor using mud weight, PPGMW (PPG) 13BF 0.802
MW (lb/ft3) 100BF 0.796
Buoyancy factor using mud weight, lb/ft3
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Amount of cuttings drilled per foot of hole drilled
a) BARRELS of cuttings drilled per foot of hole drilled:Porosity(%) 25Hole diameter (in) 6.125
BBL/ft 0.027333 bbl/footage drilledb) CUBIC FEET of cuttings drilled per foot of hole drilled:Porosity(%) 25Hole diameter (in) 6.125
cu-ft/ft 0.153462 cu.ft/footage drilledc) Total solids generated:Hole diameter (in) 6.125Hole capacity (bbl/ft) 0.036444Footage drilled (ft) 100Porosity(%) 25Cutting Density (gm/cc) 2.2Solid generated(pounds) 2104.651 pound
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Pressure Gradient CalculationPressure gradient, psi/ft, using mud weight, ppgMW (ppg) 9 PPGPressure gradient (psi/ft) 0.468 psi/ft
MW (lb/ft3) 80 lb/ft3Pressure gradient (psi/ft) 0.556 psi/ft
Pressure gradient, psi/ft, using mud weight, specific gravity (SG)MW sg 2Pressure gradient (psi/ft) 0.866 psi/ft
Convert pressure gradient, psi/ft, to mud weight, ppgPressure gradient (psi/ft) 0.5 psi/ftMW (ppg) 9.62 PPG
Convert pressure gradient, psi/ft, to mud weight, lb/ft3Pressure gradient (psi/ft) 0.5 psi/ftMW (ppg) 72.00 lb/ft3
Convert pressure gradient, psi/ft, to mud weight specific gravity (SG)Pressure gradient (psi/ft) 0.5 psi/ftSpecific Gravity 1.155
Pressure gradient, psi/ft, using mud weight, lb/ft3
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Convert temperature, °Fahrenheit (F) to °Celsius (C)F 347C 175.0
Convert temperature, °Celsius (C) to °FahrenheitC 26.667F 80.0
Convert temperature, ° Celsius (C) to °Kelvin (K)C 23K 296.2
Convert temperature, °Fahrenheit (F) to °Rankine (R)F 150R 609.7
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Accumulator Pre-charge Pressure
P start 3000P final 2000Volume removed 25Volume total 200Average pre charge pressure 750
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Bulk Density of Cuttings by using Mud BalanceProcedure to obtain RW:1. Cuttings must be washed free of mud. In oil base mud, diesel oil can be used instead of water.2. Set mud balance at 8.33 ppg.3. Fill the mud balance with cuttings until a balance is obtained with the lid in place.4. Remove lid, fill cup with water (cuttings included), replace lid, and dry outside of mud balance.
RW, ppg 14SG 3.12
5. Move counterweight to obtain new balance. This value is “Rw” = resulting weight with cuttings plus water, ppg.
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Reference
Website
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This value is “Rw” = resulting weight with cuttings plus water, ppg. http://www.drillingformulas.com/bulk-density-cuttings-using-mud-balance/
http://www.drillingformulas.com/
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Hydrostatic pressure to lose 200 psiCasing capacity 0.0873 bbl/ftPipe displacement 0.01876 bbl/ftMud weight 12 PPGFeet of drill pipe pulled 1171 ft
% of volume in drill pipe out of hole 100 %Hydrostatic pressure to lose 200 psiPipe displacement 0.0055 bbl/ftPipe capacity 0.01876 bbl/ftCasing capacity 0.0873 bbl/ftMud Weight 12 PPGFeet of drill pipe pulled 833 ft
How many feet of drill pipe pulled to lose certain amount of hydrostatic pressure (psi) when
How many feet of drill pipe pulled to lose certain amount of hydrostatic pressure (psi) when
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Referencehttp://www.drillingformulas.com/drill-pipe-pulled-to-lose-hydrostatic-pressure/Website
How many feet of drill pipe pulled to lose certain amount of hydrostatic pressure (psi) when pull dry.
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How many feet of drill pipe pulled to lose certain amount of hydrostatic pressure (psi) when pull wet.
http://www.drillingformulas.com/
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Hydrostatic Pressure (HP) Decrease When POOHWhen pulling DRY pipeStands pulled 10 standsLength per stand 91 ftPipe displacement 0.0055 bbl/ftCasing capacity 0.0873 bbl/ftMud Weight 12 PPGBBL displace 5.01 bblHP decrease (psi) 38.18 psi
When pulling WET pipe
100Stands pulled 10 standsLength per stand 91 ftPipe displacement 0.0055 bbl/ftPipe capacity 0.01876 bbl/ftCasing capacity 0.0873 bbl/ftMud Weight 12.0 PPGBBL displace 22.08 bblHP decrease (psi) 218.52 Psi
% of volume in drill pipe out of hole
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Referencehttp://www.drillingformulas.com/hydrostatic-pressure-decrease-when-pooh/Website
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http://www.drillingformulas.com/
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Depth of washout
Method 1:
Strokes pumped till pressure increase 400 strokesInternal capacity of drill pipe 0.00742 bbl/ftPump output 0.0855 bbl/stkDepth of washout 4609 ft
Method 2:
Strokes pumped till material seen 2500 strokesInternal capacity of drill pipe 0.00742 bbl/ftAnnulus capacity 0.0455 bbl/ftPump output 0.0855 bbl/stkVolume from bell nipple to shale shakers 10 bblDepth of washout 3850 ft
The concept of this method is to pump plugging material to plug the wash out. We will know how many stroks pump till pressure increase then we can calculate back where the washout is.
The concept of this method is to pump material that can be easily observed from drill pipe pass through wash out into annulus and over the surface. We can calculate the depth of washout bases on the combination volume of internal drill pipe volume and annulus volume.
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Input cellscalculated cells
Referencehttp://www.drillingformulas.com/depth-of-washout/Website
The concept of this method is to pump plugging material to plug the wash out. We will know how many stroks pump till pressure increase then we can calculate back where the washout is.
Back to the first pageDo you want to have a good oilfield resume? Click Here !!!
The concept of this method is to pump material that can be easily observed from drill pipe pass through wash out into annulus and over the surface. We can calculate the depth of washout bases on the combination volume of internal drill pipe volume and annulus volume.
http://www.drillingformulas.com/
![Page 212: Drilling Formulas Calculation Sheet Verson 1.5](https://reader036.fdocuments.us/reader036/viewer/2022062321/55cf9723550346d0338fe84b/html5/thumbnails/212.jpg)
The concept of this method is to pump plugging material to plug the wash out. We will know how many stroks pump till pressure increase then we can
The concept of this method is to pump material that can be easily observed from drill pipe pass through wash out into annulus and over the surface. We can