drilling formulas calculation sheet verson 1.4

Applied Drilling Formulas

Basic Drilling Formulas

Directional Drilling Calculation

Drilling Fluid Formulas

Engineering Formulas

Hydraulic Formulas

Well Control Formulas

Lag timeLight weight spot fill to balance formation pressureLoss of hydrostatic pressure due to filling water into annulus in case of lost returnPressure required to break circulationPump out (both duplex and triplex pump)Pump Pressure and Pump Stroke Relationship Stuck Pipe CalculationTon Miles CalculationEquivalent 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 ppgAccumulator 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 LimitationReduce 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 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 kick tolerance informationMaximum Surface Pressure from Gas Influx in Water Based MudTrip margin

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


http://www.drillingformulas.com/equivalent-circulating-density-ecd-using-yield-point-for-mw-less-than-13-ppg/




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

Input CellsCalculated CellBack to the first page



Pressure Drop Across a BitFlow rate 800 gpmMud Weight 9 ppg

0.3728Pressure Drop Across a Bit 3446 psiTotal Flow Area in2

Input CellsCalculated Cell

Reference


http://www.drillingformulas.com/pressure-drop-across-a-bit/


http://www.drillingformulas.com/pressure-drop-across-a-bit/


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


Reference


http://www.drillingformulas.com/determine-optimum-drilling-flow-rate-for-basic-system-drilling-hydraulics/




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


Reference


http://www.drillingformulas.com/critical-flow-rate-drilling-hydraulics/


http://www.drillingformulas.com/critical-flow-rate-drilling-hydraulics/


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).


Reference

If CCI = 0.5 or less poor hole cleaning (expect hole problems).


http://www.drillingformulas.com/cutting-carrying-index-simple-tool-to-determine-hole-cleaning/


http://www.drillingformulas.com/cutting-carrying-index-simple-tool-to-determine-hole-cleaning/


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


Reference


http://www.drillingformulas.com/reynold-number-for-drilling-hydraulics/


http://www.drillingformulas.com/reynold-number-for-drilling-hydraulics/


Power Law Constant

Reading at 300 rpm 32Reading at 3 rpm 3na 0.514Ka 6.628


Reference

Back to Critical Flow Rate CalculationBack to the first page

http://www.drillingformulas.com/power-law-constants-n-and-k-calculation/


http://www.drillingformulas.com/power-law-constants-n-and-k-calculation/


Effective Viscosity

Ka 6.629 poisena 0.514Dh 8.5 inchDo 5 inchFlow rate 800 gpmAnnular Velocity 7 ft/secEffective viscosity 42.53 centipoise


Reference


http://www.drillingformulas.com/effective-viscosity-calculation/


http://www.drillingformulas.com/effective-viscosity-calculation/


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

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

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)

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

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

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

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

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


Reference

Website


http://www.drillingformulas.com/determine-surge-and-swab-pressure-method-2/

http://www.drillingformulas.com/


http://www.drillingformulas.com/determine-surge-and-swab-pressure-method-2/



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


Reference

Website


http://www.drillingformulas.com/surge-and-swab-calculation-method-1/



http://www.drillingformulas.com/surge-and-swab-calculation-method-1/



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


Reference

Website


http://www.drillingformulas.com/cutting-slip-velocity-calculation-method-2/






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


Reference

Website








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


Reference

Website


http://www.drillingformulas.com/maximum-pit-gain-from-gas-kick-in-water-based-mud/



http://www.drillingformulas.com/maximum-pit-gain-from-gas-kick-in-water-based-mud/



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


Reference

Website


http://www.drillingformulas.com/maximum-surf3ace-pressure-from-gas-influx-in-water-based-mud/



http://www.drillingformulas.com/maximum-surf3ace-pressure-from-gas-influx-in-water-based-mud/



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


Reference

Website


http://www.drillingformulas.com/hydrostatic-pressure-loss-due-to-gas-cut-mud/



http://www.drillingformulas.com/hydrostatic-pressure-loss-due-to-gas-cut-mud/



Calculate Influx Height

Pit volume gain 12 bblAnnular Capacity 0.0459 bbl/ftInflux height 261 ft


Reference

Website


http://www.drillingformulas.com/calculate-influx-height/



http://www.drillingformulas.com/calculate-influx-height/



Kill Mud Weight

Shut in Drillpipe Pressure 500 psiCurrent Mud Weight 9.5 ppgHole TVD 9000 ftKill Mud Weight 10.6 ppg


Reference

Website


http://www.drillingformulas.com/shut-down-pumps-weight-up-mud/



http://www.drillingformulas.com/shut-down-pumps-weight-up-mud/



Acutal gas migration rate

Increase in pressure 200 psi/hrMud Weight 12 ppgAcutal gas migration rate 321 ft/hr


Reference

Website


http://www.drillingformulas.com/determine-the-actual-gas-migration-rate/



http://www.drillingformulas.com/determine-the-actual-gas-migration-rate/



Estimate gas migration rate with an empirical equation.

Current Mud Weight 12 ppgVg 0.14 ft/secVg 510 ft/hr

Input cellsCalculated cells

Reference

Website


http://www.drillingformulas.com/estimate-gas-migration-rate-in-a-shut-in-well/



http://www.drillingformulas.com/estimate-gas-migration-rate-in-a-shut-in-well/



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


Referencehttp://www.drillingformulas.com/estimate-type-of-influx-kick/Website






Formation Pressure from Kick Analysis

Shut in drill pipe pressure 550 psiHole TVD 6000 ftCurrent Mud Weight 10.2 ppgFormation Pressure 3732 psi


Reference

Website


http://www.drillingformulas.com/formation-pressure-from-kick-analysis/



http://www.drillingformulas.com/formation-pressure-from-kick-analysis/



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

Adjusted maximum allowable shut-in casing pressure for new mud weight


Reference

Website


http://www.drillingformulas.com/adjusted-maximum-allowable-shut-in-casing-pressure/



http://www.drillingformulas.com/adjusted-maximum-allowable-shut-in-casing-pressure/



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

Maximum possible influx height when equal to maximum allowable shut in casing pressure


Reference

Website


http://www.drillingformulas.com/maximum-influx-height-to-equal-the-maximum-allowable-shut-in-casing-pressure/






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


Reference

Website


http://www.drillingformulas.com/maximum-initial-shut-in-casing-pressure-misicp/



http://www.drillingformulas.com/maximum-initial-shut-in-casing-pressure-misicp/



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

Maximum formation pressure that can wistand when shut in the well.


Reference

Website


http://www.drillingformulas.com/maximum-formation-pressure-that-can-be-controlled-when-we-shut-the-well-in/






Maximum surface pressure from kick tolerance information

Kick tolerance factor 1.68 ppgBottom hole, TVD 10000 ftMaximum pressure 873.6 psi

Maximum surface pressure from kick tolerance information


Reference

Website


http://www.drillingformulas.com/maximum-surface-pressure-from-kick-tolerance-factor/



http://www.drillingformulas.com/maximum-surface-pressure-from-kick-tolerance-factor/



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


Reference

Website


http://www.drillingformulas.com/kick-tolerance-factor-calculation/



http://www.drillingformulas.com/kick-tolerance-factor-calculation/



Trip margin calculation

Mud Yield Point 10 lb/100 sq ftHole Diameter 8.5 inDrillpipe Diameter 4.5 inTrip Margin 0.2 ppg


Reference

Website


http://www.drillingformulas.com/trip-margin-calculation/



http://www.drillingformulas.com/trip-margin-calculation/



Lag Time CalculationPump speed 300 GPMPump Output 0.102 bbl/strokeAnnular Volume 250 bblLag time in minutes 35 minutesLag time in strokes 2451 strokes


Reference

Website


http://www.drillingformulas.com/lag-time-for-drilling-business-and-how-to-calculate-theoretical-lag-time/



http://www.drillingformulas.com/lag-time-for-drilling-business-and-how-to-calculate-theoretical-lag-time/



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)


Website

Reference

Reference

Reference

Reference

Reference

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http://www.drillingformulas.com/ton-miles-for-setting-casing/

http://www.drillingformulas.com/ton-miles-while-making-short-trip/



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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


Reference

Reference

Website


http://www.drillingformulas.com/d-exponent-calculation/

http://www.drillingformulas.com/corrected-d-exponent/



http://www.drillingformulas.com/d-exponent-calculation/

http://www.drillingformulas.com/corrected-d-exponent/



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


Reference

Reference

Website


http://www.drillingformulas.com/dilution-of-mud-system-to-control-low-gravity-solid/

http://www.drillingformulas.com/dilution-of-mud-system-to-control-low-gravity-solid-by-adding-mud/



http://www.drillingformulas.com/dilution-of-mud-system-to-control-low-gravity-solid/

http://www.drillingformulas.com/dilution-of-mud-system-to-control-low-gravity-solid-by-adding-mud/


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


Reference

Website


http://www.drillingformulas.com/decrease-oil-water-ratio/



http://www.drillingformulas.com/decrease-oil-water-ratio/



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


Reference

Website


http://www.drillingformulas.com/increase-oil-water-ratio/



http://www.drillingformulas.com/increase-oil-water-ratio/



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


Referencehttp://www.drillingformulas.com/calculate-oil-water-ratio-from-retort-data/Website






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


Referencehttp://www.drillingformulas.com/determine-the-density-of-oil-and-water-mixture/Website






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


Reference

Website


http://www.drillingformulas.com/mixing-fluids-of-different-densities-without-pit-space-limitation/



http://www.drillingformulas.com/mixing-fluids-of-different-densities-without-pit-space-limitation/



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


Reference

Website


http://www.drillingformulas.com/mixing-fluids-of-different-densities-pit-space-limitation/



http://www.drillingformulas.com/mixing-fluids-of-different-densities-pit-space-limitation/



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


Reference

Website


http://www.drillingformulas.com/reduce-mud-weight-by-dilution/



http://www.drillingformulas.com/reduce-mud-weight-by-dilution/



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


Reference

Reference

Reference


http://www.drillingformulas.com/increase-mud-weight-by-adding-hematite/

http://www.drillingformulas.com/volume-of-mud-increases-due-to-adding-hematite/

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/


http://www.drillingformulas.com/increase-mud-weight-by-adding-hematite/

http://www.drillingformulas.com/volume-of-mud-increases-due-to-adding-hematite/

http://www.drillingformulas.com/starting-volume-weight-up-with-hematite/

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



Increase Mud Density by adding Carbonate

Volume of mud in bbl increase due to mud weight increase by adding Carbonate



Reference

Reference

Reference


http://www.drillingformulas.com/increase-mud-weight-by-adding-calcium-carbonate/

http://www.drillingformulas.com/volume-of-mud-increase-due-to-adding-calcium-carbonate/

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/


http://www.drillingformulas.com/increase-mud-weight-by-adding-calcium-carbonate/

http://www.drillingformulas.com/volume-of-mud-increase-due-to-adding-calcium-carbonate/

http://www.drillingformulas.com/starting-volume-of-original-mud-weight-up-with-calcium-carbonate/

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



Increase Mud Density by adding Barite

Volume of mud in bbl increase due to mud weight increase by adding Barite



Reference

Reference

Reference

Website


http://www.drillingformulas.com/increase-mud-weight-by-adding-barite/

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/increase-mud-weight-by-adding-barite/

http://www.drillingformulas.com/volume-of-mud-increase-due-to-mud-weight-increase-by-adding-barite/

http://www.drillingformulas.com/starting-volume-of-original-mud-weight-up-with-barite/


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.


Reference

Reference

Website


http://www.drillingformulas.com/pressure-required-to-break-circulation-inside-drillstring/

http://www.drillingformulas.com/pressure-required-to-break-circulation-in-annlus/



http://www.drillingformulas.com/pressure-required-to-break-circulation-inside-drillstring/

http://www.drillingformulas.com/pressure-required-to-break-circulation-in-annlus/


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.


Reference

Website

You must ensure than height of light weight pill in the annulus must less than 1227 ft in order to prevent wellcontrol situation.


http://www.drillingformulas.com/determine-height-of-light-weight-spot-pill-to-balance-formation-pressure/



http://www.drillingformulas.com/determine-height-of-light-weight-spot-pill-to-balance-formation-pressure/



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

Loss of hydrostatic pressure due to filling water into annulus in case of lost return


Reference

Website


http://www.drillingformulas.com/loss-of-hydrostatic-pressure-due-to-lost-return/



http://www.drillingformulas.com/loss-of-hydrostatic-pressure-due-to-lost-return/


Displacment of plain pipe such as casing, tubing, etc.

OD 9.625 inchID 8.835 inchDisplacment in bbl/ft 0.01417 bbl/ft

Input cellscalculated cells

Referencehttp://www.drillingformulas.com/pipe-displacement-calculation/Website





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


Sutck Pipe Calculation (in case of not know Free Point Constant (FPC))Reference



http://www.drillingformulas.com/determine-how-many-feet-of-free-pipe/http://www.drillingformulas.com/determine-free-point-constant-fpc/http://www.drillingformulas.com/determine-how-many-feet-of-free-pipe-without-free-pipe-constant-table/


http://www.drillingformulas.com/determine-how-many-feet-of-free-pipe/

http://www.drillingformulas.com/determine-free-point-constant-fpc/

http://www.drillingformulas.com/determine-how-many-feet-of-free-pipe-without-free-pipe-constant-table/

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


Reference

Reference

Website


http://www.drillingformulas.com/accumulator-capacity-usable-volume-per-bottle-calculation-surface-stack/

http://www.drillingformulas.com/accumulator-capacity-usable-volume-per-bottle-calculation-for-subsea-bop/



http://www.drillingformulas.com/accumulator-capacity-usable-volume-per-bottle-calculation-surface-stack/

http://www.drillingformulas.com/accumulator-capacity-usable-volume-per-bottle-calculation-for-subsea-bop/


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




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

Calculate inner capacity of open hole, inside cylindrical objects such as tubulars, drill pipe, drill collars, tubing, casing etc


Reference

Website


http://www.drillingformulas.com/calculate-inner-capacity-of-open-holeinside-cylindrical-objects/



http://www.drillingformulas.com/calculate-inner-capacity-of-open-holeinside-cylindrical-objects/


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


1.031


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

Annular capacity between casing or hole and drill pipe, tubing, or casing.


Reference

Website


http://www.drillingformulas.com/calculate-annular-capacity



http://www.drillingformulas.com/calculate-annular-capacity


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


Reference

Website


http://www.drillingformulas.com/drilling-cost-per-foot/



http://www.drillingformulas.com/drilling-cost-per-foot/


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


Reference

Website


http://www.drillingformulas.com/pump-pressure-and-pump-stroke-relationship/



http://www.drillingformulas.com/pump-pressure-and-pump-stroke-relationship/


Hydraulic Horse Power (HPP)

Circulating Pressure, psi 3500Flow rate, GPM 800Hydraulic Horse Power (HPP) 1633.61


Reference

Website


http://www.drillingformulas.com/hydraulic-horse-power-calculatin/



http://www.drillingformulas.com/hydraulic-horse-power-calculatin/


Formation Temperature

Surface Temperature, F 90Temperature Gradient, F/ft 0.015Formation Depth in TVD, ft 12000Formation Temperature, F 270


Reference

Website


http://www.drillingformulas.com/formation-temperature/



http://www.drillingformulas.com/formation-temperature/


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


Reference

Website


http://www.drillingformulas.com/critical-rpm-to-avoid-excessive-vibration/



http://www.drillingformulas.com/critical-rpm-to-avoid-excessive-vibration/


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


Reference

Website


http://www.drillingformulas.com/calculate-equivalent-circulation-density-ecd-with-complex-engineering-equations/





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


http://www.drillingformulas.com/calcuate-annular-pressure-loss/




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


Reference

Website


http://www.drillingformulas.com/angle-averaging-method-in-directional-drilling-calculation/



http://www.drillingformulas.com/angle-averaging-method-in-directional-drilling-calculation/


Direcional Survey CalculationRadius of Curvature Method




Reference

Website


http://www.drillingformulas.com/radius-of-curvature-method/



http://www.drillingformulas.com/radius-of-curvature-method/


Direcional Survey CalculationBalanced Tangential Method




Reference

Website


http://www.drillingformulas.com/balanced-tangential-method-calculation/



http://www.drillingformulas.com/balanced-tangential-method-calculation/


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


Reference

Website


http://www.drillingformulas.com/minimum-curvature-method/



http://www.drillingformulas.com/minimum-curvature-method/


Direcional Survey CalculationTangential Method

Survey1 Survey2Depth (ft) 3500 3600Inclination (degree) 15.00 25.00Azimuth (degree) 20.00 45.00



Referencehttp://www.drillingformulas.com/tangential-method-calculation/Website





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


Reference

Website

Calculate dogleg severity between 2 survey points based on Radius of Curvature Method


http://www.drillingformulas.com/dogleg-severity-calculationbased-on-radius-of-curvature-method/



http://www.drillingformulas.com/dogleg-severity-calculationbased-on-radius-of-curvature-method/


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


Reference

Website

Calculate dogleg severity between 2 survey points based on tangential method


http://www.drillingformulas.com/dogleg-severity-calculation-based-on-tangential-method/



http://www.drillingformulas.com/dogleg-severity-calculation-based-on-tangential-method/


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

Input cells

calculated cells

Reference

Website


http://www.drillingformulas.com/pressure-and-force-relationship-and-applications/



http://www.drillingformulas.com/pressure-and-force-relationship-and-applications/


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

Leak Off Test Pressure Converted to Equivalent Mud Weight (LOT)


Reference

Website


http://www.drillingformulas.com/leak-off-test-procedures-and-calcuation-2/



http://www.drillingformulas.com/leak-off-test-procedures-and-calcuation-2/


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


Reference

Website


http://www.drillingformulas.com/formation-integrity-test-fit/



http://www.drillingformulas.com/formation-integrity-test-fit/


Equivalent Circulating Density (ECD), ppgAnnular pressure loss(psi) 400 psiMud weight (ppg) 10 ppgTVD (ft) 8000 ftECD 11.0 PPG


Reference

Website


http://www.drillingformulas.com/equivalent-circulating-density-ecd-in-ppg/



http://www.drillingformulas.com/equivalent-circulating-density-ecd-in-ppg/


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


Website

Reference

Reference




http://www.drillingformulas.com/calculate-specific-gravity-sg-in-oilfield-unit/

http://www.drillingformulas.com/convert-specific-gravity-to-mud-weight-ppg-and-lbft3-and-pressure-gradient-psift/



http://www.drillingformulas.com/calculate-specific-gravity-sg-in-oilfield-unit/


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


Reference

Website


http://www.drillingformulas.com/convert-pressure-into-equivalent-mud-weight/



http://www.drillingformulas.com/convert-pressure-into-equivalent-mud-weight/


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


Website

Referencehttp://www.drillingformulas.com/barrels-of-slug-required-for-desired-length-of-dry-pipe/

Reference



http://www.drillingformulas.com/weight-of-slug-required-for-desired-length-of-dry-pipe-with-set-volume-of-slug/



http://www.drillingformulas.com/weight-of-slug-required-for-desired-length-of-dry-pipe-with-set-volume-of-slug/

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

Hydrostatic pressure using ppg and feet as the units of measureInput cellscalculated cells

Referencehttp://www.drillingformulas.com/hydrostatic-pressure-calculation/Website






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


Reference

Website


http://www.drillingformulas.com/annular-velocity-calculation/



http://www.drillingformulas.com/annular-velocity-calculation/


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


Reference

Website


http://www.drillingformulas.com/pump-output-calculation-for-duplex-pump-and-triplex-pump/



http://www.drillingformulas.com/pump-output-calculation-for-duplex-pump-and-triplex-pump/


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


Reference

Website


http://www.drillingformulas.com/buoyancy-factor-calculation/



http://www.drillingformulas.com/buoyancy-factor-calculation/


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


Reference

Website



http://www.drillingformulas.com/amount-of-cuttings-total-solid-generated/



http://www.drillingformulas.com/amount-of-cuttings-total-solid-generated/


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


Reference

Website


http://www.drillingformulas.com/calculate-pressure-gradient/



http://www.drillingformulas.com/calculate-pressure-gradient/


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


Reference

Website



http://www.drillingformulas.com/temperature-conversion-formulas/



http://www.drillingformulas.com/temperature-conversion-formulas/


Accumulator Pre-charge Pressure

P start 3000P final 2000Volume removed 25Volume total 200Average pre charge pressure 750

Input cellscalculated cellsBack to the first pageDo you want to have a good oilfield resume? Click Here !!!


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.


Reference

Website


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/bulk-density-cuttings-using-mud-balance/


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


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.


How many feet of drill pipe pulled to lose certain amount of hydrostatic pressure (psi) when pull wet.




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


Referencehttp://www.drillingformulas.com/hydrostatic-pressure-decrease-when-pooh/Website





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.


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.


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.




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

drilling formulas calculation sheet verson 1.4

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