Applied Drilling Formulas Basic Drilling Formulas Directional Drilling Calculat Drilling Fluid Formulas Engineering Formulas Hydraulic Formulas Well Control Formulas Lag time Light weight spot fill to balance formation pressure Loss of hydrostatic pressure due to filling water into annulus in case of Pressure required to break circulation Pump out (both duplex and triplex pump) Pump Pressure and Pump Stroke Relationship Stuck Pipe Calculation Ton Miles Calculation Accumulator capacity Amount of cuttings drilled per foot of hole drilled Annular Capacity Annular Velocity (AV) Buoyancy Factor (BF) Convert Temperature Unit Converting Pressure into Mud Weight Drilling Cost Per Foot D-Exponent and D-Exponent Corrected Depth of washout Displacement of plain pipe such as casing, tubing, etc. Equivalent Circulating Density (ECD) Formation Integrity Test (FIT) Leak Off Test (LOT) Formation Temperature How many feet of drill pipe pulled to lose certain amount of hydrostatic Hydrostatic Pressure (HP) Hydrostatic Pressure (HP) Decrease When POOH Inner Capacity of open hole, inside cylindrical objects Pressure and Force Pressure Gradient Slug Calculation Specific Gravity (SG) Directional Survey - Angle Averaging Method Directional Survey - Radius of Curvature Method Directional Survey - Balanced Tangential Method Directional Survey - Minimum Curvature Method Directional Survey - Tangential Method Dogleg Severity Calculation based on Radius of Curvature Method Dogleg Severity Calculation based on Tangential Method Bulk Density of Cuttings by using Mud Balance Decrease oil water ratio Determine oil water ratio from a retort analysis Determine the density of oil/water mixture Dilution to control LGS Increase mud weight by adding Barite Increase mud weight by adding Calcium Carbonate Increase mud weight by adding Hematite Increase oil water ratio Mixing Fluids of Different Densities with Pit Space Limitation Mixing Fluids of Different Densities without Pit Space Limitation Reduce mud weight by dilution Annular Pressure Loss Critical RPM Calculate Equivalent Circulating Density with Engineering Formula Hydraulic Horse Power (HPP) Cutting Slip Velocity Method#1 Cutting Slip Velocity Method#2 Surge and Swab Pressure Method#1 Surge and Swab Pressure Method#2 Total Flow Area Table Actual gas migration rate in a shut in well Adjusted maximum allowable shut-in casing pressure for new mud weight Calculate Influx Height Estimate gas migration rate with an empirical equation Estimate type of influx Formation pressure from kick analysis Hydrostatic Pressure Loss Due to Gas Cut Mud Kick tolerance factor (KTF) Kill Weight Mud Maximum formation pressure (FP) Maximum influx height Maximum Initial Shut-In Casing Pressure (MISICP) Maximum pit gain from gas kick in water based mud Maximum surface pressure from kick tolerance information Maximum Surface Pressure from Gas Influx in Water Based Mud Trip margin
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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
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
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
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)
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
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
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
Back to the first page% original oil in liquid phase% original water in liquid phase% new oil in liquip phase http://www.drillingformulas.com/increase-oil-water-ratio/% new water in liquid phase
% 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/
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
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
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
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.
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.
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
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
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
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
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
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
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
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/
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.
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.