76257792 drilling formulas calculation sheet v1 2
TRANSCRIPT
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 CalculationAccumulator capacityAmount of cuttings drilled per foot of hole drilledAnnular Capacity Annular Velocity (AV)Buoyancy Factor (BF)Convert Temperature UnitConverting Pressure into Mud WeightDrilling Cost Per FootD-Exponent and D-Exponent CorrectedDepth of washoutDisplacement of plain pipe such as casing, tubing, etc.Equivalent Circulating Density (ECD)Formation Integrity Test (FIT)Leak Off Test (LOT)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 Pressure and ForcePressure GradientSlug CalculationSpecific Gravity (SG)Directional 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 FormulaHydraulic Horse Power (HPP)Cutting Slip Velocity Method#1Cutting Slip Velocity Method#2Surge 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
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
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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
Input CellsCalculated Cell
Reference
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http://www.drillingformulas.com/determine-surge-and-swab-pressure-method-2/
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Surge and swab pressure method#1
θ300 85θ600 130Hole diameter 9 inchDrill Collar 6.25 inchID of drill collar 2.5 inchDrillpipe diameter 5 inchID of drill pipe 3.5 inchAverage pipe running or pulling speed 250 ft/minDrill Pipe Length 12000 ftDrill Collar Length 800 ftCurrent Mud Weight 12.5 ppgWell TVD 9000 ftSelect Criteria ---> Closed Ended Pipe
n 0.613K 1.863Fluid volocity around drill pipe (Closed ended pipe (plugged flow)) 224.1 ft/min
Maximum pipe velocity around drill pipe 336.2 ft/minPressure Loss around drill pipe 540.7 psiFluid volocity around drill collar (Closed ended pipe (plugged flow)) 345.4 ft/min
Maximum pipe velocity around drill collar 518.0 ft/minPressure Loss around drill collar 86.0 psiTotal pressure loss 626.7 psi
6476.7 psi13.8 ppg
5223.3 psi11.2 ppg
Surge: Bottom Hole PressureSurge: Bottom Hole Pressure in ppgSwab: Bottom Hole PressureSwab: Bottom Hole Pressure in ppg
Input CellsCalculated Cell
Reference
Website
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http://www.drillingformulas.com/surge-and-swab-calculation-method-1/
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Cutting Slip Velocity Method#2
θ300 32 Input Cellsθ600 49 Calculated CellFlow rate 600 gpmHole diameter 11.50 inchDrillpipe Diameter 5 inch ReferenceDiameter of cutting 0.75 inchDensity of cutting 21.5 ppg WebsiteMud 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 gpm Input CellsHole Diameter 11.5 inch Calculated CellDrillpipe OD 5 inchPV 17 cpsMW 9.2 ppg ReferenceDiameter of cutting 0.75 inchDensity of cutting 21.5 ppg Website
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
Input CellsCalculated Cell
Reference
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http://www.drillingformulas.com/maximum-pit-gain-from-gas-kick-in-water-based-mud/
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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
Input CellsCalculated Cell
Reference
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http://www.drillingformulas.com/maximum-surf3ace-pressure-from-gas-influx-in-water-based-mud/
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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
Input CellsCalculated Cell
Reference
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http://www.drillingformulas.com/hydrostatic-pressure-loss-due-to-gas-cut-mud/
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Calculate Influx Height
Pit volume gain 12 bblAnnular Capacity 0.0459 bbl/ftInflux height 261 ft
Input CellsCalculated Cell
Reference
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http://www.drillingformulas.com/calculate-influx-height/
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Kill Mud Weight
Shut in Drillpipe Pressure 500 psi Input CellsCurrent Mud Weight 9.5 ppg Calculated CellHole TVD 9000 ftKill Mud Weight 10.6 ppg
Reference
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Acutal gas migration rateInput Cells
Increase in pressure 200 psi/hr Calculated CellMud Weight 12 ppgAcutal gas migration rate 321 ft/hr
Reference
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Estimate gas migration rate with an empirical equation.
Current Mud Weight 12 ppg Input cellsVg 0.14 ft/sec Calculated cellsVg 510 ft/hr
Reference
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http://www.drillingformulas.com/estimate-gas-migration-rate-in-a-shut-in-well/
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Estimate Type of Influx (kick)
Shut in casing pressure 1050 psi Input cellsShut in drill pipe pressure 750 psi Calculated cellsHeight of influx 450 ftCurrent Mud Weight 14 ppgInflux weight 1.2 ppg ReferenceType of influx Gas Influx http://www.drillingformulas.com/estimate-type-of-influx-kick/
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Formation Pressure from Kick Analysis
Shut in drill pipe pressure 550 psi Input cellsHole TVD 6000 ft Calculated cellsCurrent Mud Weight 10.2 ppgFormation Pressure 3732 psi
Reference
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Adjusted maximum allowable shut-in casing pressure for new mud weight
Leak off test pressure 1000 psi Input cellsCasing shoe TVD 4500 ft Calculated cellsOriginal Mud Weight 9.5 ppgCurrent Mud Weight 12 ppgNew MASICP 415 psi Reference
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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
Maximum possible influx height when equal to maximum allowable shut in casing pressure
Input cellsCalculated cells
Reference
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Maximum Initial Shut-In Casing Pressure (MISICP)
Leak off test pressure 15 ppg Input cellsCurrent mud weight 12.2 ppg Calculated cellsCasing shoe depth 4000 ftMaximum allowable shut in casing pressure 582.4 psi
Reference
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Maximum formation pressure that can wistand when shut in the well.
Kick tolerance factor 1.68 ppg Input cellsMud weight 10 ppg Calculated cellsHole TVD 10000 ftMaximum formation pressure 6,074 psi
Reference
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Maximum surface pressure from kick tolerance information
Kick tolerance factor 1.68 ppg Input cellsBottom hole, TVD 10000 ft Calculated cellsMaximum pressure 873.6 psi
Reference
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Kick tolerance factor (KTF)
Casing shoe TVD 4000 ft Input cellsWell depth TVD 10000 ft Calculated cellsMaximum allowable mud weight 14.2 ppgCurrent mud weight 10 ppgKick tolerance factor (KTF) 1.68 ppg Reference
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Trip margin calculation
Mud Yield Point 10 lb/100 sq ft Input cellsHole Diameter 8.5 in Calculated cellsDrillpipe Diameter 4.5 inTrip Margin 0.2 ppg
Reference
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Lag Time CalculationPump speed 300 GPM Input cellsPump Output 0.102 bbl/stroke Calculated cellsAnnular Volume 250 bblLag time in minutes 35 minutesLag time in strokes 2451 strokes Reference
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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)
Input cellsCalculated cells
Website
Reference
Reference
Reference
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“d” ExponentRate of penetration (R) 90 f/hr Input cellsRotary drilling speed (N) 110 rpm Calculated cellsWeight on bit (W) 20 klbBit Diameter (D) 8.5 inch ReferenceD-exponent, dimensionless 1.20
“d” Exponent CorrectedRate of penetration (R) 90 f/hr ReferenceRotary drilling speed (N) 110 rpmWeight on bit (W) 20 klb WebsiteBit 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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Dilution to Control LGS
1st case: Dilution by adding base fluid or water Input cellsCalculated cells
Total barrels of mud in circulating system 1000Percent low gravity solids in system 6Percent total low gravity solids desired 4 ReferenceBarrels of dilution water or base fluid 500.0
2nd case: Dilution by adding drilling fluid
Total barrels of mud in circulating system 2000 ReferencePercent low gravity solids in system 7Percent total low gravity solids desired 3.5
2 WebsiteBarrels of dilution water or base fluid 4666.7
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Percent low gravity solids bentonite and/or chemicals added in mud
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Decrease oil water ratio% by volume oil 56 Input cells% by volume water 14 Calculated cells% by volume solids 30Total mud volume, bbl 300
80% Reference20%
70 Website30
10.00 bblTotal volume of water added into the system 30.00 bbl
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% original oil in liquid phase% original water in liquid phase http://www.drillingformulas.com/decrease-oil-water-ratio/% new oil in liquip phase% new water in liquid phase http://www.drillingformulas.com/Water added per 100 bbl of original mud
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Increase oil water ratio% by volume oil 51 Input cells% by volume water 17 Calculated cells% by volume solids 32
75%25% Reference
8020 Website
Oil added per 100 bbl of original mud 17.00 bbl
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Determine oil water ratio from a retort analysis
% by volume oil 56 Input cells% by volume water 14 Calculated cells% by volume solids 30% oil in liquid phase 80%% water in liquid phase 20% ReferenceOil/Water ratio 80/20 http://www.drillingformulas.com/calculate-oil-water-ratio-from-retort-data/
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Determine the density of oil/water mixture
Percentage of oil 80 Input cellsPercentage of water 20 Calculated cellsDensity of oil 7 ppgDensity of water 8.33 ppgFinal density 7.27 ppg Reference
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Input cellsMud Weight#1 10 ppg Calculated cellsMud Weight#2 14 ppgVolume of Mud#1 200 bblVolume of Mud#2 300 bbl ReferenceTotal volume 500 bblFinal Mud Weight 12.4 ppg Website
Mix different fluid density: Case#2 unlimit space
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Mud Weight#1 10 ppg Input cellsMud Weight#2 14 ppg Calculated cellsFinal Mud Weight 12 ppgFinal Volume 300 bblVolume of Mud#1 150 bbl ReferenceVolume of Mud#2 150 bbl
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Mix different fluid density: Case#1 limit space
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Reduce mud weight (dilution)
Strating volume (V1) in bbl 200 bbl Input cellsStart drilling fluid weight in ppg (W1) 13.8 ppg Calculated cellsFinal 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
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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
Input cellsCalculated cells
Reference
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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
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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
Input cellsCalculated cells
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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
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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 200.5 sacksTotal sacks of barite required 1002.3 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 13.64 bblTotal volume increase in bbl 68.18 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
Input cellsCalculated cells
Reference
Reference
Reference
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http://www.drillingformulas.com/increase-mud-weight-by-adding-barite/
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Starting volume in bbl of original mud weight required to achieve a predetermined final volume of desired mud weight with Barite
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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.
Input cellsCalculated cells
Reference
Reference
Website
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http://www.drillingformulas.com/pressure-required-to-break-circulation-inside-drillstring/
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Light weight spot fill to balance formation pressureInput cells
Current mud weight, ppg 13 ppg Calculated cellsOverblance with current mud weight, psi 300 psiWeigth of light weight pill, ppg 8.3 ppg ReferenceHeight of light weight pill, ft, in annulus 1227 ft
Website
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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http://www.drillingformulas.com/determine-height-of-light-weight-spot-pill-to-balance-formation-pressure/
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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.
http://www.drillingformulas.com/determine-height-of-light-weight-spot-pill-to-balance-formation-pressure/
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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 ppg Input cellsWater Weight in ppg 8.6 ppg Calculated cellsTVD 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 ft ReferenceHydrostaic Pressure decrease 225.3 psiEquivalent Mud Weigth at TD 12.3 ppg Website
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http://www.drillingformulas.com/loss-of-hydrostatic-pressure-due-to-lost-return/
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Displacment of plain pipe such as casing, tubing, etc.
OD 9.625 inch Input cellsID 8.835 inch calculated cellsDisplacment in bbl/ft 0.01417 bbl/ft
Referencehttp://www.drillingformulas.com/pipe-displacement-calculation/Website
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Stuck Pipe Calculation
Stretch in inch 5 inch Input cellsFree point constant 28634.51 calculated cellsPull 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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Accumulator Capacity
Suface Application Input cellsVolume per bottle 10 gal calculated cellsPre-charge pressure 1000 psiMinimum System Pressure 1200 psiOperating Pressure 3000 psi ReferenceUsable Volume per bottle 5.00 gal
Subsea ApplicationVolume per bottle 10 galPre-charge pressure 1000 psiMinimum System Pressure 1200 psiOperating Pressure 3000 psi ReferencePressure gradient of hydraulic fluid 0.445 psi/ftWater depth 1500 ft WebsiteUsable Volume per bottle 4.38 gal
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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/
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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/
Input cellsHole size, Casing ID, Tubing ID, etc 6.125 calculated cells
0.0364
Hole size, Casing ID, Tubing ID, etc 6.125 Reference27.4392
Website
Hole size, Casing ID, Tubing ID, etc 6.1251.5306
Hole size, Casing ID, Tubing ID, etc 6.1250.6533
Calculate inner capacity of open hole, inside cylindrical objects such as tubulars, drill pipe, drill collars, tubing, casing etc
Calculate capacity in bbl/ft
Capacity in bbl/ft Back to the first page
Calculate capacity in ft/bbl
Capacity in ft/bbl http://www.drillingformulas.com/calculate-inner-capacity-of-open-holeinside-cylindrical-objects/
Calculate capacity in gal/ft http://www.drillingformulas.com/
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
http://www.drillingformulas.com/calculate-inner-capacity-of-open-holeinside-cylindrical-objects/
Annular capacity between casing or hole and drill pipe, tubing, or casing.
Input cellsHole size, casing ID in inch 8.5 calculated cellsDrill pipe size, DC size or casing/tubing OD 5
0.04590
Hole size, casing ID in inch 6.125 ReferenceDrill pipe size, DC size or casing/tubing OD 3.5
40.743 Website
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
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Calculate annular capacity in ft/bbl
http://www.drillingformulas.com/calculate-annular-capacityAnnular capacity, ft/bbl
http://www.drillingformulas.com/Calculate annular capacity in gal/ft
Annular capacity, gal/ft
Calculate annular capacity in ft/gal
Annular capacity, ft/gal
http://www.drillingformulas.com/calculate-annular-capacity
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Cost Per Foot CalculationInput cells
Bit cost (B), $ 27000 calculated cellsRig cost (CR), $/hr 3500Rotating time (t), hrs 50Round trip time (T), hrs 12 ReferenceFootage per bit (F), ft 5000Cost per foot , $/ft 48.80 Website
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http://www.drillingformulas.com/drilling-cost-per-footdrilling-cost-per-foot/
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Pump Pressure and Pump Stroke Relationship
Basic Calculation Input cellscalculated cells
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 2500 ReferenceOld Pump Rate, SPM 40New Pump Rate, SPM 25 WebsiteNew Circulating Pressure, psi 1037.0
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http://www.drillingformulas.com/pump-pressure-and-pump-stroke-relationship/
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Hydraulic Horse Power (HPP)
Circulating Pressure, psi 3500 Input cellsFlow rate, GPM 800 calculated cellsHydraulic Horse Power (HPP) 1633.61
Reference
Website
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http://www.drillingformulas.com/hydraulic-horse-power-calculatin/
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Formation TemperatureInput cells
Surface Temperature, F 90 calculated cellsTemperature Gradient, F/ft 0.015Formation Depth in TVD, ft 12000Formation Temperature, F 270 Reference
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http://www.drillingformulas.com/formation-temperature/
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Critical RPM to prevent pipe failure due to high vibrationJust rough estimate 15% accurate Input cells
calculated cellsLength of one joint of drill pipe, ft 32OD of drill pipe, inch 4ID of drill pipe, inch 3.5 ReferenceCritical RPM 172
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http://www.drillingformulas.com/critical-rpm-to-avoid-excessive-vibration/
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Calculate Equivalent Circulating Density with Engineering Formula
Mud weight 12.8 Input cellsReading at 300 44 calculated cellsReading at 600 74PV 30Pump rate, gpm 200Hole diameter, in 6.35Drill pipe OD, in 4Drill pipe length, ft 11913Drill collar OD, in 5Drill collar length, ft 100TVD, ft 10000
n 0.750K 0.410Annular velocity around DP, ft/min 201.5 Lamina FlowCritical velocity around DP, ft/min 322.0Annular velocity around DC, ft/min 319.8 Lamina FlowCritical velocity around DC, ft/min 448.9Pressure loss around DP 406.9 ReferencePressure loss around DC 9.0Total annular pressure loss 415.9 Website
ECD at 10000' TVD in ppg 13.60
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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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http://www.drillingformulas.com/calcuate-annular-pressure-loss/
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Direcional Survey CalculationAngle Averaging Method
Survey1 Survey2Depth (ft) 7482 7782 Input cellsInclination (degree) 4 8 calculated cellsAzimuth (degree) 10 35
North 28.97 ft ReferenceEast 12.00 ftVertical 298.36 ft Website
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http://www.drillingformulas.com/angle-averaging-method-in-directional-drilling-calculation/
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Direcional Survey CalculationRadius of Curvature Method
Input cellsSurvey1 Survey2 calculated cells
Depth (ft) 7482 7782Inclination (degree) 4 8Azimuth (degree) 10 35
ReferenceNorth 28.74 ftEast 11.90 ft WebsiteVertical 298.30 ft
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http://www.drillingformulas.com/radius-of-curvature-method/
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Direcional Survey CalculationBalanced Tangential Method
Input cellsSurvey1 Survey2 calculated cells
Depth (ft) 3500 3600Inclination (degree) 15 25Azimuth (degree) 20 45
ReferenceNorth 27.10 ftEast 19.37 ft WebsiteVertical 93.61 ft
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http://www.drillingformulas.com/balanced-tangential-method-calculation/
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Direcional Survey CalculationMinimum Curvature Method Input cells
calculated cellsSurvey1 Survey2
Depth (ft) 3500 3600Inclination (degree) 15.00 25.00Azimuth (degree) 20.00 45.00
β 0.22605 radians ReferenceRF 1.00428North 27.22 ft WebsiteEast 19.45 ftVertical 94.01 ft
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http://www.drillingformulas.com/minimum-curvature-method/
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Direcional Survey CalculationTangential Method
Input cellsSurvey1 Survey2 calculated cells
Depth (ft) 3500 3600Inclination (degree) 15.00 25.00Azimuth (degree) 20.00 45.00
ReferenceNorth 29.88 ft http://www.drillingformulas.com/tangential-method-calculation/East 29.88 ft WebsiteVertical 90.63 ft
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Survey1 Survey2Depth (ft) 4231 4262 Input cellsInclination (degree) 13.5 14.7 calculated cellsAzimuth (degree) 10 19
Dogleg severity 8.05 degree/100 ft Reference
Website
Calculate dogleg severity between 2 survey points based on Radius of Curvature Method
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http://www.drillingformulas.com/dogleg-severity-calculationbased-on-radius-of-curvature-method/
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Radius of Curvature Method
http://www.drillingformulas.com/dogleg-severity-calculationbased-on-radius-of-curvature-method/
Survey1 Survey2 Input cellsDepth (ft) 4231 4262 calculated cellsInclination (degree) 13.5 14.7Azimuth (degree) 10 19
ReferenceDogleg severity 3.23 degree/100 ft
Website
Calculate dogleg severity between 2 survey points based on tangential method
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http://www.drillingformulas.com/dogleg-severity-calculation-based-on-tangential-method/
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Determine force with given pressure and areaPressure 500 psi Input cells
Area 3 calculated cellsForce 1500 lb
orDetermine force with given pressure and diameter ReferencePressure 500 psiDiameter 3 in WebsiteForce 3534.3 lb
in2
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http://www.drillingformulas.com/pressure-and-force-relationship-and-applications/
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Leak Off Test Pressure Converted to Equivalent Mud Weight (LOT)
LOT pressure (psi) 1600 psi Input cellsMud Weight (ppg) 9.2 ppg calculated cellsShoe Depth (TVD) 4000 ftLOT equivalent mud weight 16.9 ppg
Reference
Website
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http://www.drillingformulas.com/leak-off-test-procedures-and-calcuation-2/
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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
Input cellscalculated cells
Reference
Website
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http://www.drillingformulas.com/formation-integrity-test-fit/
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Equivalent Circulating Density (ECD), ppgAnnular pressure loss(psi) 400 psi Input cellsMud weight (ppg) 10 ppg calculated cellsTVD (ft) 8000 ftECD 11.0 PPG
Reference
Website
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http://www.drillingformulas.com/equivalent-circulating-density-ecd-in-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
Input cellscalculated cells
Website
Reference
Reference
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http://www.drillingformulas.com/
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/convert-specific-gravity-to-mud-weight-ppg-and-lbft3-and-pressure-gradient-psift/
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
Input cellscalculated cells
Reference
Website
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http://www.drillingformulas.com/convert-pressure-into-equivalent-mud-weight/
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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
Input cellscalculated cells
Website
Referencehttp://www.drillingformulas.com/barrels-of-slug-required-for-desired-length-of-dry-pipe/
Reference
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Hydrostatic Pressure (HP)Hydrostatic pressure using ppg and feet as the units of measureMud weight 12 ppg Input cellsTVD (ft) 10000 ft calculated cellsHydrostatic Pressure (psi) 6240.0 psi
Hydrostatic pressure, psi, using pressure gradient, psi/ftPressure gradient (psi/ft) 0.5 psi/ft ReferenceTVD (ft) 10000 ft http://www.drillingformulas.com/hydrostatic-pressure-calculation/Hydrostatic Pressure (psi) 5000.0 psi Website
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
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Hydrostatic pressure, psi, using mud weight, lb/ft3 http://www.drillingformulas.com/
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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
Input cellscalculated cells
Reference
Website
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http://www.drillingformulas.com/annular-velocity-calculation/
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Pump outTriplex Pump, bbl/stk Input cellsefficiency (%) 97 calculated cellsLiner diameter (in) 6 inStroke length (in) 12 inPO (bbl/stk) 0.10183 bbl/stk
Duplex Pump , bbl/stkefficiency (%) 85Liner diameter (in) 6 in ReferenceRod diameter (in) 2 inStroke length (in) 12 in WebsitePO (bbl/stk) 0.11236 bbl/stk
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Buoyancy Factor (BF)
Buoyancy factor using mud weight, PPG Input cellsMW (PPG) 13 calculated cellsBF 0.802
ReferenceMW (lb/ft3) 100BF 0.796 Website
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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
Input cellscalculated cells
Reference
Website
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http://www.drillingformulas.com/amount-of-cuttings-total-solid-generated/
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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
Input cellscalculated cells
Reference
Website
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http://www.drillingformulas.com/calculate-pressure-gradient/
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Convert temperature, °Fahrenheit (F) to °Celsius (C)F 347 Input cellsC 175.0 calculated cells
Convert temperature, °Celsius (C) to °FahrenheitC 26.667F 80.0 Reference
Convert temperature, ° Celsius (C) to °Kelvin (K) WebsiteC 23K 296.2
Convert temperature, °Fahrenheit (F) to °Rankine (R)F 150R 609.7
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http://www.drillingformulas.com/temperature-conversion-formulas/
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Accumulator Pre-charge Pressure
P start 3000 Input cellsP final 2000 calculated cellsVolume 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.
Input cellscalculated cells
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/
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Hydrostatic pressure to lose 200 psiCasing capacity 0.0873 bbl/ft Input cellsPipe displacement 0.01876 bbl/ft calculated cellsMud 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/ft ReferencePipe capacity 0.01876 bbl/ft http://www.drillingformulas.com/drill-pipe-pulled-to-lose-hydrostatic-pressure/Casing capacity 0.0873 bbl/ft WebsiteMud 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
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How many feet of drill pipe pulled to lose certain amount of hydrostatic pressure (psi) when
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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 pipe Input cellsStands pulled 10 stands calculated cellsLength per stand 91 ftPipe displacement 0.0055 bbl/ftCasing capacity 0.0873 bbl/ftMud Weight 12 PPG ReferenceBBL displace 5.01 bbl http://www.drillingformulas.com/hydrostatic-pressure-decrease-when-pooh/HP decrease (psi) 38.18 psi Website
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
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% of volume in drill pipe out of hole
http://www.drillingformulas.com/hydrostatic-pressure-decrease-when-pooh/
http://www.drillingformulas.com/
Depth of washout
Method 1:
Strokes pumped till pressure increase 400 strokes Input cellsInternal capacity of drill pipe 0.00742 bbl/ft calculated cellsPump 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/ft ReferencePump output 0.0855 bbl/stk http://www.drillingformulas.com/depth-of-washout/Volume from bell nipple to shale shakers 10 bbl WebsiteDepth 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.
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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/
http://www.drillingformulas.com/depth-of-washout/
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.
http://www.drillingformulas.com/