Well Control Formulas Drillingformulas Com v1 2

Pump

FIT/LOT

Weight Up

Surge and Swab

Pump out (both duplex and triplex pump)Pump Pressure and Pump Stroke Relationship Formation Integrity Test (FIT)Leak Off Test (LOT)Increase mud weight by adding BariteIncrease mud weight by adding Calcium CarbonateIncrease mud weight by adding Hematite

Equivalent Circulating

Density

Equivalent Circulating Density (ECD)Equivalent 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 ppgCalculate Equivalent Circulating Density with Engineering FormulaSurge and Swab Pressure Method#1Surge and Swab Pressure Method#2

Well Control Formulas

Accumulator capacityActual gas migration rate in a shut in wellAdjusted maximum allowable shut-in casing pressure for new mud weightBottle Capacity Required in AccumulatorCalculate Influx HeightEstimate gas migration rate with an empirical equationEstimate type of influxFinal Circulating Pressure (FCP)Formation pressure from kick analysisHydrostatic Pressure Loss Due to Gas Cut MudIncrease in Casing Pressure due to Kick PenetrationInitial Circulating Pressure (ICP)Kick tolerance factor (KTF)Kill Weight Mud (KWM)Lube IncrementMaximum formation pressure (FP)

Bottle Capacity Required in Accumulator

Volume of usable fluid required (gal) 5.0Pre-charge pressure (psi) 1,000 Minimum system pressure (psi) 1,200 Operating pressure (psi) 3,000 Usable volume per bottle (gal) 10.00

Input cellscalculated cellsBack to the first page

Time to petentrate the kick

Depth of top of kick (ft) 8,974.0Bit depth (ft) 6,500.0Gas Kick Migration Rate (ft/hr) 262.0Stripping Speed (ft/hr) 200.0Time to petentrate the kick (hr) 5.4

Mud Increment (MI)

Pressure Increment (psi) 100.0Casing ID (inch) 12.50Drillstring OD (inch) 5.00Mud Weight (ppg) 11.0Annular Capacity Factor (bbl/ft) 0.1275Mud Increment (bbl) 22.3

Lube Increment (MI)

Pressure Increment (psi) 100.0Casing ID (inch) 12.50Drillstring OD (inch) 5.00Mud Weight (ppg) 11.0Annular Capacity Factor (bbl/ft) 0.1275Lube Increment (bbl) 22.3

Increase in casing pressure due to kick penetrationAssumption - vertical wellPit gain (bbl) 30.0Mud Density (ppg) 11.0Kick Density (ppg) 2.0Hole size 12.25BHA OD (inch) 6.50BHA length (ft) 800Drilstring OD (inch) 5.00Hole capacity (bbl/ft) 0.1458Annular capacity between hole and BHA (bbl/ft) 0.1047Annular capacity between hole and Drillstring (bbl/ft) 0.1215Kick Height in Hole (ft) 205.8Kick Height in Annulus (ft) 286.4Increase in casing pressure due to kick penetration (psi) 37.7

Riser Margin

Air Gap 60 ft Input CellsWater Depth 1,600 ft Calculated CellMud Weight 9.30 ppg

Sea Water Weight 8.60 ppgDepth (TVD) 3,000 ft Ref

Riser Margin 1.25 ppg

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New Pump Pressure With New Strokes (psi)

Current Pressure 1,600 psi Input CellsSPM 1 70 strks. Calculated CellSPM 2 110 strks.

New Pump Pressure 3,951 psiBack to the first page

New Pressure Loss With New Mud (psi)

Original Pressure Loss 1,400 psi Input CellsMud Weight#1 11.50 ppg Calculated CellMud Weight#2 12.50 ppg

New Pressure Loss 1,522 psiBack to the first page

Initial Circulating Pressure (psi)Input Cells

SCR Pressure 450 psi Calculated CellKill Mud Weight 12.00 ppg

Original Mud Weight 10.00 ppgFCP 540 psi


Initial Circulating Pressure (psi)Input Cells

SCR Pressure 400 psi Calculated CellSIDPP 500 psi

ICP 900 psiBack to the first page

Kick Tolerance (Surface Stack and Vertical Well)

Previous Casing Shoe MD/TVD 5,500 ftTD depth MD/TVD 9,500 ftPredicted Formation Pressure @ TD 12.0 ppgPore pressure uncertainty 0.5 ppgPlanned MW @ TD 12.0 ppgGas gradient 0.11 psi/ftLeak Off Test at casing shoe 14.7 ppgHole size 12.3 inchDrill pipe size 5.0 inchAverage BHA size 6.5 inchBHA length 850.0 ftAnnular capacity between hole and BHA 0.1047 bbl/ftAnnular capacity between hole and DP 0.1215 bbl/ftMaximum anticipated pressure 12.5 ppgMaximum allowable shut in casing pressur 772.2 psiKick intensity 0.50 ppgUnderbalance 247 psiKick Height 1,021.79 ft1st case: Gas at the bottom 109.89 bbl2nd case: Gas at the shoe 84.52 bblKick Telerance 84.52 bbl

Input CellsCalculated Cell

Reference


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http://www.drillingformulas.com/kick-tolerance-concept-and-calculation-for-well-design/

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Equivalent Circulating Density (ECD) Using Yield Point for MW more than 13 ppg

Mud weight 13.5 ppg Input CellsReading at 300 25 Calculated CellReading at 600 40Hole ID 6.2 inchPipe OD 4 inch ReferenceFlow rate 200 ppg http://www.drillingformulas.com/equivalent-circulating-density-ecd-using-yield-point-for-mw-more-than-13-ppg/AV 218.4 ft/minPV 15.0YP 10 CPEquivalent Circulating Density (ECD) 14.2 ppg




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



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/




Pressure Drop Across a BitFlow rate 800 gpmMud Weight 9 ppg

0.3728Pressure Drop Across a Bit 3446 psiTotal Flow Area in2


Reference


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


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


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/

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Surge and swab pressure method#1

θ300 47θ600 80Hole diameter 6.35 inchDrill Collar 5 inchID of drill collar 2.25 inchDrillpipe diameter 4 inchID of drill pipe 3.34 inchAverage pipe running or pulling speed 20 ft/minDrill Pipe Length 12270 ftDrill Collar Length 100 ftCurrent Mud Weight 13.2 ppgWell TVD 9972 ftSelect Criteria ---> Open Ended Pipe

n 0.767K 0.394

Fluid volocity around drill pipe (Open ended pipe) 11.7 ft/minMaximum pipe velocity around drill pipe 17.6 ft/minPressure Loss around drill pipe 67.6 psi

Fluid volocity around drill collar (Open ended pipe) 28.6 ft/minMaximum pipe velocity around drill collar 42.8 ft/minPressure Loss around drill collar 2.9 psiTotal pressure loss 70.5 psi

6915.3 psi13.3 ppg

6774.3 psi13.1 ppg

Surge: Bottom Hole PressureSurge: Bottom Hole Pressure in ppgSwab: Bottom Hole PressureSwab: Bottom Hole Pressure in ppg


Reference

Website


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



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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


Reference

Website


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


Reference

Website


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


Reference

Website


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


Reference

Website


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



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Kill Mud Weight

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


Reference

Website


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



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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/



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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/



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

Leak off test pressure 1000 psiCasing shoe TVD 4500 ftOriginal Mud Weight 9.5 ppgCurrent Mud Weight 12 ppgNew MASICP 415 psi

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


Reference

Website


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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


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/



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

Kick tolerance factor 1.68 ppgMud weight 10 ppgHole TVD 10000 ftMaximum formation pressure 6,074 psi

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/



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Kick tolerance factor (KTF)

Casing shoe TVD 4000 ftWell depth TVD 10000 ftMaximum allowable mud weight 14.2 ppgCurrent mud weight 10 ppgKick tolerance factor (KTF) 1.68 ppg


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/



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

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

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Starting volume in bbl of original mud weight required to achieve a predetermined final volume of desired mud weight with Hematite

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


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Current Mud Weight, ppg 10.0 ppgNew Mud Weight, ppg 13.0 ppgTotal mud in the system 500.0 bblSacks of Barite per 100 bbl of mud 298 sacksTotal sacks of barite required 1492 sacks



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/

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Starting volume in bbl of original mud weight required to achieve a predetermined final volume of desired mud weight with Carbonate

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


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Current Mud Weight, ppg 10.1 ppgNew Mud Weight, ppg 11.1 ppgTotal mud in the system 1000.0 bblSacks of Barite per 100 bbl of mud 61.5 sacksTotal sacks of barite required 615.1 sacks



Increase Mud Density by adding Barite

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



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

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



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

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

Input cellscalculated cells

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





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/



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

Hole size, Casing ID, Tubing ID, etc 6.1250.0364




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


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/



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Calculate Equivalent Circulating Density with Engineering Formula

Mud weight 13.2Reading at 300 47Reading at 600 80PV 33Pump rate, gpm 165Hole diameter, in 6.35Drill pipe OD, in 4Drill pipe length, ft 12276Drill collar OD, in 5Drill collar length, ft 100TVD, ft 10000

n 0.767K 0.394Annular velocity around DP, ft/min 166.2 Lamina FlowCritical velocity around DP, ft/min 327.9Annular velocity around DC, ft/min 263.8 Lamina FlowCritical velocity around DC, ft/min 462.9Pressure loss around DP 378.5Pressure loss around DC 8.2Total annular pressure loss 386.7

ECD at 10000' TVD in ppg 13.94


Reference

Website


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





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/



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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


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/



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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


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 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/


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/


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 !!!


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





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