Drilling Formulas Calculation Sheet Verson 1.4

Applied Drilling Formulas

Basic Drilling Formulas

Directional Drilling Calculation

Drilling Fluid Formulas

Engineering Formulas

Hydraulic Formulas

Well Control Formulas

Lag time Light weight spot fill to balance formation pressure Loss of hydrostatic pressure due to filling water into annulus in case of lost return Pressure required to break circulation Pump out (both duplex and triplex pump) Pump Pressure and Pump Stroke Relationship Stuck Pipe Calculation Ton Miles Calculation Equivalent Circulating Density (ECD) Using Yield Point for MW less than or equal to 13 ppg Equivalent Circulating Density (ECD) Using Yield Point for MW more than 13 ppg 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 Depth of washout D-Exponent and D-Exponent Corrected Displacement of plain pipe such as casing, tubing, etc. Drilling Cost Per Foot Equivalent Circulating Density (ECD) Formation Integrity Test (FIT) Formation Temperature How many feet of drill pipe pulled to lose certain amount of hydrostatic pressure (psi) Hydrostatic Pressure (HP) Hydrostatic Pressure (HP) Decrease When POOH Inner Capacity of open hole, inside cylindrical objects Leak Off Test (LOT) Pressure and Force Pressure Gradient Slug Calculation Specific Gravity (SG) Total Bit Revolution in Mud Motor 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 Critical Flow Rate Cutting Carrying Index Cutting Slip Velocity Method#1 Cutting Slip Velocity Method#2 Effective Viscosity Hydraulic Horse Power (HPP) Optimum Flow Rate for basic system Power Law Constant Pressure Loss Annulus Pressure Loss Annulus With Tool Joint Correction Pressure Loss Drillstring Pressure Loss Drillstring With Tool Joint Correction Pressure Loss in Surface Equipment Reynold Number 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

Equivalent Circulating Density (ECD) Using Yield Point for MW more than 13 ppg Mud weight Reading at 300 Reading at 600 Hole ID Pipe OD Flow rate AV PV YP Equivalent Circulating Density (ECD)

13.5 25 40 6.2 4 200 218.4 15.0 10 14.2

ppg

inch inch ppg ft/min

Input Cells Calculated Cell Back to the first page

Reference http://www.drillingformulas.com/equivalent-circula

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Equivalent Circulating Density (ECD) Using Yield Point for MW less than 13 ppg Mud weight Reading at 300 Reading at 600 Hole ID Pipe OD YP Equivalent Circulating Density (ECD)

9.2 25 40 6.2 4 10 9.7

ppg

inch inch CP ppg


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Total Bit Revolution in Mud Motor Rotor rpm Flow rate Rotary rpm Total Bit Revolution in Mud Motor

0.2 300 200 260

rev/gpm gpm rpm rpm

Input Cells Calculated Cell Back to the first page Do you want to have a good oilfield resume? Click Here !!!

Pressure Drop Across a Bit Flow rate Mud Weight Total Flow Area Pressure Drop Across a Bit

800 9 0.3728 3446

gpm ppg in2 psi

Input Cells Calculated Cell Back to the first page Reference http://www.drillingformulas.com/pressure-drop-across-a-bit/ Do you want to have a good oilfield resume? Click Here !!!

Optimum Flow Rate - Optimzed at The End of The Run Hole Size Depth at TD Maxium Surface Pressure Mud properties at TD MW PV YP 3 rpm 300 rpm 600 rpm Drill pipe OD Drill pipe ID Tool Joint OD Tool Joint ID Drill collar OD Drill collar ID Length of Drill Collar Cse (select) Cpb B Cpa Cp Ccb Cca Cc Vf Optimum flow rate Maximum hydraulic horsepower Maximum Impact Force

8.500 inch 6000 ft 4500 psi 9.5 14 11 3 30 33 5 4.2 6.5 3.5 6.75 3.5 800 5 0.00624349 2.4 0.00308269 0.00932617 0.016337 0.01655983 0.032896 1.055788

ppg

inch inch inch inch inch inch inch See the table =>

702 gpm 868 gpm


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Critical Flow Rate Power Law Constant, n Power Law Constant, K Mud Weight Hole Diameter (Dh) OD of pipe/collar (Do) Critical Annular Velocity Critical Flow Rate

0.51 6.63 10 12.25 5 3.82 1172

ppg in in ft/sec gpm

Input Cells Calculated Cell Back to the first page Reference http://www.drillingformulas.com/critical-flow-rate-drilling-hydraulics/ Do you want to have a good oilfield resume? Click Here !!!

Cutting Carrying Index Mud Weight 9.2 Annular Velocity 140 Plastic viscosity 17 Yield Point 15 n 0.61472 K 353.71 CCI 1.14 Hole cleaning Good Hole Cleaning

ppg ft/min cp lbs/100 sq ft

If CCI = 1 or greater, the hole cleaning is excellent. If CCI = 0.5 or less poor hole cleaning (expect hole problems).

ect hole problems).

Input Cells Calculated Cell Back to the first page Reference http://www.drillingformulas.com/cutting-carrying-index-simple-tool-to-determine-hole-cleaning/ Do you want to have a good oilfield resume? Click Here !!!

Reynold Number Annular Velocity Hole Diameter Drill pipe OD Mud Weight Effective viscosity Power Law Constant Reynold Number

6 8.5 5 9.5 42.53 0.514 3,781

ft/sec inch inch ppg centipoise

Input Cells Calculated Cell Back to the first page Reference http://www.drillingformulas.com/reynold-number-for-drilling-hydraulics/ Do you want to have a good oilfield resume? Click Here !!!

Power Law Constant Reading at 300 rpm Reading at 3 rpm na Ka

32 3 0.514 6.628

Input Cells Calculated Cell Back to Critical Flow Rate Calculation Back to the first page Reference http://www.drillingformulas.com/power-law-constants-n-and-k-calculation/ Do you want to have a good oilfield resume? Click Here !!!

Effective Viscosity Ka na Dh Do Flow rate Annular Velocity Effective viscosity

6.629 0.514 8.5 5 800 7 42.53

poise inch inch gpm ft/sec centipoise

Input Cells Calculated Cell Back to the first page Reference http://www.drillingformulas.com/effective-viscosity-calculation/ Do you want to have a good oilfield resume? Click Here !!!

Pressure loss through surface equipment General coefficient for surface equipment (Cse) Mud Weight Plastic Viscosity Flow rate Pressure loss through surface equipment

8 9.5 12 600 155.0

See => ppg centipoise gpm psi


Pressure loss in annulus with corrected coefficient Length of drill pipe OD of drill pipe OD of drill pipe tool joint Length of drill collar OD of drill collar Hole size Mud Weight Plastic Viscosity Flow rate B parameter (see the table) Coefficient for annulus around drillpipe and tool joint Coefficient for annulus around drill collar Pressure loss in the annulus around drill pipe Pressure loss in the annulus around drill collar Total Pressure loss in the annulus

2500 5 6 500 5 9 9.5 12 600 2.4

ft inch inch ft inch inch ppg centipoise gpm

0.001733 0.001645 63 psi 12 psi 74 psi


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Pressure loss in annulus Length of drill pipe/drill collar OD of drill pipe/drill collar Hole size Mud Weight Plastic Viscosity Flow rate B parameter (see the table) General coefficient Pressure loss in the annulus

2500 5 8.835 9.5 12 600 2.4 0.001912 69

ft inch inch ppg centipoise gpm

psi


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Pressure loss through the drill string with tool joint coefficient Length of drill pipe ID of drill pipe Tool joint ID of drill pipe Length of drill collar ID of drill collar Mud Weight Plastic Viscosity Flow rate General coefficient for drill pipe General coefficient for drill collar Pressure loss through the drill pipe Pressure loss through the drill collar Total pressure in drill string

5000 3.34 2.563 500 2.8 9.5 12 600 0.0204 0.0483 1473 349 1821

ft inch inch ft inch ppg centipoise gpm

psi psi psi


Pressure loss through the drill string Length of drill pipe ID of drill pipe Length of drill collar ID of drill collar Mud Weight Plastic Viscosity Flow rate General coefficient for drill pipe General coefficient for drill collar Pressure loss through the drill pipe Pressure loss through the drill collar Total pressure in drill string

5000 3.34 500 2.8 9.5 12 600 0.0174 0.0409 1254 295 1549

ft inch ft inch ppg centipoise gpm

psi psi psi


Nozzle size (x/32) 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30

1 Nozzle 0.0376 0.0491 0.0621 0.0767 0.0928 0.1104 0.1296 0.1503 0.1726 0.1963 0.2217 0.2485 0.2769 0.3068 0.3382 0.3712 0.4057 0.4418 0.4794 0.5185 0.5591 0.6013 0.6450 0.6903

2 Nozzles 0.0752 0.0982 0.1243 0.1534 0.1856 0.2209 0.2592 0.3007 0.3451 0.3927 0.4433 0.4970 0.5538 0.6136 0.6765 0.7424 0.8115 0.8836 0.9587 1.0370 1.1183 1.2026 1.2901 1.3806

3 Nozzles 0.1127 0.1473 0.1864 0.2301 0.2784 0.3313 0.3889 0.4510 0.5177 0.5890 0.6650 0.7455 0.8307 0.9204 1.0147 1.1137 1.2172 1.3254 1.4381 1.5555 1.6774 1.8040 1.9351 2.0709

4 Nozzles 0.1503 0.1963 0.2485 0.3068 0.3712 0.4418 0.5185 0.6013 0.6903 0.7854 0.8866 0.9940 1.1075 1.2272 1.3530 1.4849 1.6230 1.7671 1.9175 2.0739 2.2365 2.4053 2.5802 2.7612

5 Nozzles 0.1879 0.2454 0.3106 0.3835 0.4640 0.5522 0.6481 0.7517 0.8629 0.9817 1.1083 1.2425 1.3844 1.5340 1.6912 1.8561 2.0287 2.2089 2.3968 2.5924 2.7957 3.0066 3.2252 3.4515

6 Nozzles 0.2255 0.2945 0.3728 0.4602 0.5568 0.6627 0.7777 0.9020 1.0354 1.1781 1.3300 1.4910 1.6613 1.8408 2.0295 2.2273 2.4344 2.6507 2.8762 3.1109 3.3548 3.6079 3.8702 4.1417

7 Nozzles 0.2631 0.3436 0.4349 0.5369 0.6496 0.7731 0.9073 1.0523 1.2080 1.3744 1.5516 1.7395 1.9382 2.1476 2.3677 2.5986 2.8402 3.0925 3.3556 3.6294 3.9140 4.2092 4.5153 4.8320

8 Nozzles 0.3007 0.3927 0.4970 0.6136 0.7424 0.8836 1.0370 1.2026 1.3806 1.5708 1.7733 1.9880 2.2151 2.4544 2.7059 2.9698 3.2459 3.5343 3.8350 4.1479 4.4731 4.8106 5.1603 5.5223

9 Nozzles 0.3382 0.4418 0.5591 0.6903 0.8353 0.9940 1.1666 1.3530 1.5532 1.7671 1.9949 2.2365 2.4920 2.7612 3.0442 3.3410 3.6516 3.9761 4.3143 4.6664 5.0322 5.4119 5.8054 6.2126

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Surge and swab pressure method#2 θ300 θ600 Hole diameter Drillpipe diameter Drill collar diameter Average pipe running or pulling speed Drill Pipe Length Drill collar length Current Mud Weight Well TVD

85 130 9.000 5 6.25 250 12000 800 12.5 9000

PV n K Fluid Velocity (Closed Ended Pipe) around drill pipe Maximum pipe velocity around drill pipe Shear rate of mud around drill pipe (Ym) Shear stress of mud around drill pipe (T) Fluid Velocity (Closed Ended Pipe) around drill collar Maximum pipe velocity around drill collar Equivalent flow rate around drill collar Pressure lose around drill pipe Pressure loss around drill collar Total Pressure Loss Surge: Bottom Hole Pressure Surge: Bottom Hole Pressure in ppg Swab: Bottom Hole Pressure Swab: Bottom Hole Pressure in ppg

45 0.613 1.863 224.1 336.2 201.7 48.1 345.4 518.0 886.8 480.5 71.8 552.2 6402.2 13.7 5297.8 11.3

inch inch inch ft/min ft ft ppg ft

ft/min ft/min

ft/min ft/min gpm psi psi psi psi ppg psi ppg

Input Cells Calculated Cell Back to the first page Reference http://www.drillingformulas.com/determine-surge-and-swab-pressure-method-2/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Surge and swab pressure method#1 θ300 θ600 Hole diameter Drill Collar ID of drill collar Drillpipe diameter ID of drill pipe Average pipe running or pulling speed Drill Pipe Length Drill Collar Length Current Mud Weight Well TVD Select Criteria ---> n K Fluid volocity around drill pipe (Open ended pipe) Maximum pipe velocity around drill pipe Pressure Loss around drill pipe Fluid volocity around drill collar (Open ended pipe) Maximum pipe velocity around drill collar Pressure Loss around drill collar Total pressure loss Surge: Bottom Hole Pressure Surge: Bottom Hole Pressure in ppg Swab: Bottom Hole Pressure Swab: Bottom Hole Pressure in ppg

47 80 6.35 5 2.25 4 3.34 20 12270 100 13.2 9972 Open Ended Pipe

inch inch inch inch inch ft/min ft ft ppg ft

0.767 0.394 11.7 ft/min 17.6 ft/min 67.6 psi 28.6 42.8 2.9 70.5 6915.3 13.3 6774.3 13.1

ft/min ft/min psi psi psi ppg psi ppg

Input Cells Calculated Cell Back to the first page Reference http://www.drillingformulas.com/surge-and-swab-calculation-method-1/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Cutting Slip Velocity Method#2 θ300 θ600 Flow rate Hole diameter Drillpipe Diameter Diameter of cutting Density of cutting Mud Weight

32 49 600 11.50 5 0.75 21.5 9.2

gpm inch inch inch ppg ppg

n K Viscosity Annular Velocity Cutting Slip Velocity Net cutting rise velocity

0.614 0.694 82.40 137.1 76.93 60.1

cp ft/min ft/min ft/min

Moving Up Falling Down Good

Input Cells Calculated Cell Back to the first page Reference http://www.drillingformulas.com/cutting-slip-velocity-calculation-method-2/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Cutting Slip Velocity Method#1 Flow rate Hole Diameter Drillpipe OD PV MW Diameter of cutting Density of cutting Annular Velocity Cutting Slip Velocity Net cutting rise velocity

600 11.5 5 17 9.2 0.75 21.5

gpm inch inch cps ppg inch ppg

137.1 ft/min 85.34 ft/min 51.7 ft/min

Moving Up Falling Down Good

Input Cells Calculated Cell Back to the first page Reference http://www.drillingformulas.com/cutting-slip-velocity-calculation-method-1/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Maximum pit gain from gas kick in water based mud Expected formation pressure Pit volume gain Kill Weight Mud Annular Capacity Maximum pit gain

3620 20 14.5 0.1215 98.5

psi bbl ppg bbl/ft bbl


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Maximum Surface Pressure from Gas Influx in Water Based Mud Expected formation pressure Pit volume gain Kill Weight Mud Annular Capacity Maximum Surface Pressure

6378 25 13 0.0459 1344

psi bbl ppg bbl/ft psi


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Hydrostatic Pressure Loss Due to Gas Cut Mud weight Annular Capacity Pit volume gain Hydrostatic Pressure Loss Due to Gas Cut

12 0.0352 15 266

ppg bbl/ft bbl ft


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Calculate Influx Height Pit volume gain Annular Capacity Influx height

12 bbl 0.0459 bbl/ft 261 ft


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Kill Mud Weight Shut in Drillpipe Pressure Current Mud Weight Hole TVD Kill Mud Weight

500 9.5 9000 10.6

psi ppg ft ppg


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Acutal gas migration rate Increase in pressure Mud Weight Acutal gas migration rate

200 psi/hr 12 ppg 321 ft/hr

Input Cells Calculated Cell Back to the first page Reference http://www.drillingformulas.com/determine-the-actual-gas-migration-rate/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Estimate gas migration rate with an empirical equation. Current Mud Weight Vg Vg

12 ppg 0.14 ft/sec 510 ft/hr

Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/estimate-gas-migration-rate-in-a-shut-in-well/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Estimate Type of Influx (kick) Shut in casing pressure Shut in drill pipe pressure Height of influx Current Mud Weight Influx weight Type of influx

1050 750 450 14 1.2 Gas Influx

psi psi ft ppg ppg

Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/estimate-type-of-influx-kick/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Formation Pressure from Kick Analysis Shut in drill pipe pressure Hole TVD Current Mud Weight Formation Pressure

550 6000 10.2 3732

psi ft ppg psi

Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/formation-pressure-from-kick-analysis/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Adjusted maximum allowable shut-in casing pressure for new mud weight Leak off test pressure Casing shoe TVD Original Mud Weight Current Mud Weight New MASICP

1000 4500 9.5 12 415

psi ft ppg ppg psi

casing pressure for new mud weight Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/adjusted-maximum-allowable-shut-in-casing-pressure/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Maximum possible influx height when equal to maximum allowable shut in casing pressure Maximum Allowable Shut-In Casing Pressure (MASICP) Mud gradient Influx gradient Maximum possible influx height

874 0.52 0.12 2185

psi psi/ft psi/ft ft

ng pressure Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/maximum-influx-height-to-equal-the-maximum-allowable-shut-in-casing-pressure/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

ing-pressure/

Maximum Initial Shut-In Casing Pressure (MISICP) Leak off test pressure Current mud weight Casing shoe depth Maximum allowable shut in casing pressure

15 12.2 4000 582.4

ppg ppg ft psi

Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/maximum-initial-shut-in-casing-pressure-misicp/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Maximum formation pressure that can wistand when shut in the well. Kick tolerance factor Mud weight Hole TVD Maximum formation pressure

1.68 10 10000 6,074

ppg ppg ft psi

nd when shut in the well. Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/maximum-formation-pressure-that-can-be-controlled-when-we-shut-the-well-in/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

olled-when-we-shut-the-well-in/

Maximum surface pressure from kick tolerance information Kick tolerance factor Bottom hole, TVD Maximum pressure

1.68 ppg 10000 ft 873.6 psi

ce information Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/maximum-surface-pressure-from-kick-tolerance-factor/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Kick tolerance factor (KTF) Casing shoe TVD Well depth TVD Maximum allowable mud weight Current mud weight Kick tolerance factor (KTF)

4000 10000 14.2 10 1.68

ft ft ppg ppg ppg

Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/kick-tolerance-factor-calculation/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Trip margin calculation Mud Yield Point Hole Diameter Drillpipe Diameter Trip Margin

10 8.5 4.5 0.2

lb/100 sq ft in in ppg

Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/trip-margin-calculation/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Lag Time Calculation Pump speed Pump Output Annular Volume Lag time in minutes Lag time in strokes

300 0.102 250 35 2451

GPM bbl/stroke bbl minutes strokes

Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/lag-time-for-drilling-business-and-how-to-calculate-theoretical-lag-time/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Ton Mile Calculation Round-trip ton-mile Mud Weight Measured depth (D) Drillpipe weight drill collar weight drill collar length HWDP weight HWDP length BHA weight in air Length of BHA Block weight (Wb) Average length of one stand (Lp) Buoyancy factor Buoyed weight of drill pipe (Wp) 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)

10 5500 13.3 85 120 49 450 8300 94 95000 94 0.847 11.27

ppg ft lb/ft lb/ft ft lb/ft ft lb ft lb ft lb/ft

26,876.24 lb 258.75 Ton mile

Drilling or Connection Ton-miles 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 drilling (Td)

230 ton-miles 195 ton-miles 105.00 ton-miles

Ton-miles for Coring Operation 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 drilling (TC)

190 ton-miles 20.00 ton-miles

Ton-Miles for Setting Casing Mud weight Casing weight Depht of casing set Travelling block weight Length of one joint of casing Buoyancy factor Ton-Miles for Setting Casing

10 25 5200 95000 42 0.847 50.73

Ton-Miles for Short Trip Ton-miles for one round trip at the deeper depth(T6) Ton-miles for one round trip at the shallower depth (T5) Ton-miles for drilling (TC)

200 ton-miles

ppg lb/ft ft lb ft ton-miles

200 ton-miles 190 ton-miles 10.00 ton-miles

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Reference http://www.drillingformulas.com/round-trip-ton-miles-calculation/

Reference http://www.drillingformulas.com/drilling-or-connection-ton-miles/

Reference http://www.drillingformulas.com/ton-miles-for-coring-operation/

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

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

“d” Exponent Rate of penetration (R) Rotary drilling speed (N) Weight on bit (W) Bit Diameter (D) D-exponent, dimensionless

90 110 20 8.5 1.20

f/hr rpm klb inch

90 110 20 8.5 9 12 0.90

f/hr rpm klb inch ppg ppg

“d” Exponent Corrected Rate of penetration (R) Rotary drilling speed (N) Weight on bit (W) Bit Diameter (D) Initial mud weight in ppg (MW1) Actual mud weight in ppg (MW2) D-exponent, dimensionless

Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/d-exponent-calculation/

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Dilution to Control LGS 1st case: Dilution by adding base fluid or water Total barrels of mud in circulating system Percent low gravity solids in system Percent total low gravity solids desired Barrels of dilution water or base fluid

1000 6 4 500.0

2nd case: Dilution by adding drilling fluid Total barrels of mud in circulating system Percent low gravity solids in system Percent total low gravity solids desired Percent low gravity solids bentonite and/or chemicals added in mud Barrels of dilution water or base fluid

2000 7 3.5 2 4666.7

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Decrease oil water ratio % by volume oil % by volume water % by volume solids Total mud volume, bbl % original oil in liquid phase % original water in liquid phase % new oil in liquip phase % new water in liquid phase Water added per 100 bbl of original mud Total volume of water added into the system

56 14 30 300 80% 20% 70 30 10.00 bbl 30.00 bbl

Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/decrease-oil-water-ratio/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Increase oil water ratio % by volume oil % by volume water % by volume solids % original oil in liquid phase % original water in liquid phase % new oil in liquip phase % new water in liquid phase Oil added per 100 bbl of original mud

51 17 32 75% 25% 80 20 17.00 bbl

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Determine oil water ratio from a retort analysis % by volume oil % by volume water % by volume solids % oil in liquid phase % water in liquid phase Oil/Water ratio

56 14 30 80% 20% 80/20

Input cells Calculated cells Back to the first page Reference http://www.drillingformulas.com/calculate-oil-water-ratio-from-retort-data/ Website http://www.drillingformulas.com/ Do you want to have a good oilfield resume? Click Here !!!

Determine the density of oil/water mixture Percentage of oil Percentage of water Density of oil Density of water Final density

80 20 7 ppg 8.33 ppg 7.27 ppg

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Mix different fluid density: Case#2 unlimit space Mud Weight#1 Mud Weight#2 Volume of Mud#1 Volume of Mud#2 Total volume Final Mud Weight

10 14 200 300 500 12.4

ppg ppg bbl bbl bbl ppg

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Mix different fluid density: Case#1 limit space Mud Weight#1 Mud Weight#2 Final Mud Weight Final Volume Volume of Mud#1 Volume of Mud#2

10 14 12 300 150 150

ppg ppg ppg bbl bbl bbl

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Reduce mud weight (dilution) Strating volume (V1) in bbl Start drilling fluid weight in ppg (W1) Final drilling fluid weight in ppg (W2) Density of light weight fluid in ppg (Dw) Light weight fluid required in bbl

200 13.8 10 7.2 271.4

bbl ppg ppg ppg bbl

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Increase Mud Density by adding

Hematite

Current Mud Weight, ppg New Mud Weight, ppg Total mud in the system Sacks of Barite per 100 bbl of mud Total sacks of barite required

10.0 13.0 500.0 186.7 933.3

ppg ppg bbl sacks sacks

Volume of mud in bbl increase due to mud weight increase by adding Current Mud Weight, ppg New Mud Weight, ppg Total mud in the system Volume in bbl increase per 100 bbl of mud Total volume increase in bbl

10.0 13.0 500.0 11.11 55.56

Hematite

ppg ppg bbl bbl bbl

Starting volume in bbl of original mud weight required to achieve a predetermined final volume of desired mud weight Current Mud Weight in ppg New Mud Weight in ppg Final volume in bbl Starting volume in bbl

10.0 13.0 100.0 90.00

ppg ppg bbl bbl

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mined final volume of desired mud weight with

Hematite

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

Increase Mud Density by adding

Carbonate

Current Mud Weight, ppg New Mud Weight, ppg Total mud in the system Sacks of Barite per 100 bbl of mud Total sacks of barite required

10.0 13.0 500.0 298 1492



10.0 13.0 500.0 31.58 157.89

Carbonate

ppg ppg bbl bbl bbl


10.0 13.0 100.0 76.00

ppg ppg bbl bbl

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Carbonate

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

Increase Mud Density by adding Barite Current Mud Weight, ppg New Mud Weight, ppg Total mud in the system Sacks of Barite per 100 bbl of mud Total sacks of barite required

10.1 11.1 1000.0 61.5 615.1



9.2 10.1 650.0 3.61 23.49

Barite

ppg ppg bbl bbl bbl


10.0 13.0 100.0 88.00

ppg ppg bbl bbl

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Barite

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

Pressure required to break circulation Pressure required overcoming the mud’s gel strength inside the drill string. 10 min get strenght of mud, lb/100 sq ft Inside diameter of drill pipe in inch Length of drill string in ft Pressure required to break circulation inside drill string

12 3.32 11500 138.6

lb/100 sq ft in ft psi

Pressure required overcoming the mud’s gel strength in the annulus. 10 min get strenght of mud, lb/100 sq ft Outside diameter of drill pipe in inch Hole diameter in inch Length of drill string in ft Pressure required to break circulation inside drill string

12 4 6.5 11500 184.0

lb/100 sq ft in in ft psi

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Light weight spot fill to balance formation pressure Current mud weight, ppg Overblance with current mud weight, psi Weigth of light weight pill, ppg Height of light weight pill, ft, in annulus

13 300 8.3 1227

ppg psi ppg ft

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

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Loss of hydrostatic pressure due to filling water into annulus in case of lost return Current Mud Weight in ppg Water Weight in ppg TVD in ft Annular Capacity in bbl/ft Water filled into annulus in bbl Feet of water in annuls Hydrostaic Pressure decrease Equivalent Mud Weigth at TD

13 8.6 6000 0.1422 140 984.5 225.3 12.3

ppg ppg ft bbl/ft bbl ft psi ppg

to annulus in case of lost return Input cells Calculated cells Back to the first page Do you want to have a good oilfield resume? Click Here !!! Reference http://www.drillingformulas.com/loss-of-hydrostatic-pressure-due-to-lost-return/ Website http://www.drillingformulas.com/

Displacment of plain pipe such as casing, tubing, etc. OD ID Displacment in bbl/ft

9.625 inch 8.835 inch 0.01417 bbl/ft

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Stuck Pipe Calculation Stretch in inch Free point constant Pull force in Klb Depth of stuck pipe

5 inch 28634.51 100 Klb 1431.73 ft

Free Point Constant (FPC) calculation Outside Diameter 9.625 inch Inside Diameter 8.835 inch FPC 28634.51 Sutck Pipe Calculation (in case of not know Free Point Constant (FPC)) Stretch in inch Pull force in Klb Outside Diameter Inside Diameter Depth of stuck pipe

5 100 9.625 8.835 1431.73

inch Klb inch inch ft

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ree Point Constant (FPC)) Reference http://www.drillingformulas.com/determine-how-many-feet-of-free-pipe/ http://www.drillingformulas.com/determine-free-point-constant-fpc/ http://www.drillingformulas.com/determine-how-many-feet-of-free-pipe-without-free-pipe-constant-table/

Accumulator Capacity Suface Application Volume per bottle Pre-charge pressure Minimum System Pressure Operating Pressure Usable Volume per bottle

10 1000 1200 3000 5.00

gal psi psi psi gal

Subsea Application Volume per bottle Pre-charge pressure Minimum System Pressure Operating Pressure Pressure gradient of hydraulic fluid Water depth Usable Volume per bottle

10 1000 1200 3000 0.445 1500 4.38

gal psi psi psi psi/ft ft gal

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Calculate inner capacity of open hole, inside cylindrical objects such as tubulars, drill pipe, drill collars, tubing, casing Calculate capacity in bbl/ft Hole size, Casing ID, Tubing ID, etc Capacity in bbl/ft

6.125 0.0364

Calculate capacity in ft/bbl Hole size, Casing ID, Tubing ID, etc Capacity in ft/bbl

6.125 27.4392

Calculate capacity in gal/ft Hole size, Casing ID, Tubing ID, etc Capacity in gal/ft

6.125 1.5306

Calculate capacity in ft/gal Hole size, Casing ID, Tubing ID, etc Capacity in ft/gal

6.125 0.6533

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Annular capacity between casing or hole and drill pipe, tubing, or casing. Calculate annular capacity in bbl/ft Hole size, casing ID in inch Drill pipe size, DC size or casing/tubing OD Annular capacity, bbl/ft

8.5 5 0.04590

Calculate annular capacity in ft/bbl Hole size, casing ID in inch Drill pipe size, DC size or casing/tubing OD Annular capacity, ft/bbl

6.125 3.5 40.743

Calculate annular capacity in gal/ft Hole size, casing ID in inch Drill pipe size, DC size or casing/tubing OD Annular capacity, gal/ft

6.125 3.5 1.031

Calculate annular capacity in ft/gal Hole size, casing ID in inch Drill pipe size, DC size or casing/tubing OD Annular capacity, ft/gal

6.125 3.5 0.970

ipe, tubing, or casing. Input cells calculated cells Back to the first page Do you want to have a good oilfield resume? Click Here !!!

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Cost Per Foot Calculation Bit cost (B), $ Rig cost (CR), $/hr Rotating time (t), hrs Round trip time (T), hrs Footage per bit (F), ft Cost per foot , $/ft

27000 3500 50 12 5000 48.80

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Pump Pressure and Pump Stroke Relationship Basic Calculation Current Circulating Pressure, psi Old Pump Rate, SPM New Pump Rate, SPM New Circulating Pressure, psi

2500 40 25 976.6

Advanced calculation (Determine factor) Pressure 1, psi Flow rate1, gpm Pressure 2, psi Flow rate2, gpm Factor Current Circulating Pressure, psi Old Pump Rate, SPM New Pump Rate, SPM New Circulating Pressure, psi

2700 320 500 130 1.872 2500 40 25 1037.0


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

3500 800 1633.61

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Formation Temperature Surface Temperature, F Temperature Gradient, F/ft Formation Depth in TVD, ft Formation Temperature, F

90 0.015 12000 270

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Critical RPM to prevent pipe failure due to high vibration Just rough estimate 15% accurate Length of one joint of drill pipe, ft OD of drill pipe, inch ID of drill pipe, inch Critical RPM

32 4 3.5 172

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Calculate Equivalent Circulating Density with Engineering Formula Mud weight Reading at 300 Reading at 600 PV Pump rate, gpm Hole diameter, in Drill pipe OD, in Drill pipe length, ft Drill collar OD, in Drill collar length, ft TVD, ft

13.2 47 80 33 165 6.35 4 12276 5 100 10000

n K Annular velocity around DP, ft/min Critical velocity around DP, ft/min Annular velocity around DC, ft/min Critical velocity around DC, ft/min Pressure loss around DP Pressure loss around DC Total annular pressure loss ECD at 10000' TVD in ppg

0.767 0.394 166.2 Lamina Flow 327.9 263.8 Lamina Flow 462.9 378.5 8.2 386.7

13.94


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

Annular Pressure Loss Mud Weight in ppg Length in ft Flow rate in GPM Dh, in Dp, in velocity, ft/min P loss annular in psi

13.0 8000.0 320.0 6.50 4.00 298.7 531.65

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alcuate-annular-pressure-loss/

Direcional Survey Calculation Angle Averaging Method

Depth (ft) Inclination (degree) Azimuth (degree) North East Vertical

Survey1 Survey2 7482 7782 4 8 10 35 28.97 ft 12.00 ft 298.36 ft


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Direcional Survey Calculation Radius of Curvature Method



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Direcional Survey Calculation Balanced Tangential Method



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Direcional Survey Calculation Minimum Curvature Method

Depth (ft) Inclination (degree) Azimuth (degree) β RF North East Vertical

Survey1 Survey2 3500 3600 15.00 25.00 20.00 45.00 0.22605 1.00428 27.22 19.45 94.01

radians ft ft ft


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

Direcional Survey Calculation Tangential Method


Survey1 Survey2 3500 3600 15.00 25.00 20.00 45.00 29.88 ft 29.88 ft 90.63 ft

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Calculate dogleg severity between 2 survey points based on Radius of Curvature Method Depth (ft) Inclination (degree) Azimuth (degree) Dogleg severity

Survey1 Survey2 4231 4262 13.5 14.7 10 19 8.05 degree/100 ft

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Calculate dogleg severity between 2 survey points based on tangential method Depth (ft) Inclination (degree) Azimuth (degree) Dogleg severity

Survey1 Survey2 4231 4262 13.5 14.7 10 19 3.23 degree/100 ft

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Determine force with given pressure and area Pressure 500 psi 2 Area 3 in Force 1500 lb or Determine force with given pressure and diameter Pressure 500 psi Diameter 3 in Force 3534.3 lb

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Leak Off Test Pressure Converted to Equivalent Mud Weight (LOT) LOT pressure (psi) Mud Weight (ppg) Shoe Depth (TVD) LOT equivalent mud weight

1600 9.2 4000 16.9

psi ppg ft ppg

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Pressure Required Formation Integrity Test (FIT) FIT required (ppg) Mud Weight (ppg) Shoe Depth (TVD) Pressure required (psi)

14.5 ppg 9.2 ppg 4000 ft 1102.4

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Equivalent Circulating Density (ECD), ppg Annular pressure loss(psi) Mud weight (ppg) TVD (ft) ECD

400 10 8000 11.0

psi ppg ft PPG

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Specific Gravity (SG) Specific gravity using mud weight, ppg Mud weight (ppg) SG

13 ppg 1.56

Specific gravity using pressure gradient, psi/ft Pressure gradient (psi/ft) SG

0.50 psi/ft 1.15

Specific gravity using mud weight, lb/ft3 Mud weight (lb/ft3) SG

90.00 lb/ft3 1.44

Convert specific gravity to mud weight, ppg SG MW (ppg)

1.50 12.50 ppg

Convert specific gravity to pressure gradient, psi/ft SG Pressure Gradient (psi/ft)

1.50 0.650 psi/ft

Convert specific gravity to mud weight, lb/ft3 SG Mud weight (lb/ft3)

1.50 93.600 lb/ft3

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Converting Pressure into Mud Weight Convert pressure, psi, into mud weight, ppg using feet as the unit of measure Pressure (psi) TVD (ft) MW (ppg)

5000 psi 8000 ft 12.0 PPG

Convert pressure, psi, into mud weight, ppg using meters as the unit of measure Pressure (psi) TVD (m) MW (ppg)

5000 psi 2500 m 11.7 PPG

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Barrels of slug required for a desired length of dry pipe Desired length of dry pipe (ft) Drill pipe capacity (bbl/ft) Current MW (PPG) Slug Weight (PPG)

400 0.015 11.5 12.5

ft bbl/ft ppg ppg

Hydrostatic pressure required to give desired drop inside drill pipe Difference in pressure gradient bw slug and current MW Length of slug in drill pipe (ft) Slug Volume

239.2 0.052 4600 69.00

psi psi/ft ft bbl

Weight of slug required for a desired length of dry pipe with a set volume of slug Desired length of dry pipe (ft) Slug Volume (bbl) Drill pipe capacity (bbl/ft) Current MW (PPG) Slug length (ft) Hydrostatic Pressure required (psi) Weight of slug (PPG)

400 30 0.015 11.5

ft bbl bbl/ft ppg

2000.0 ft 239.2 psi 13.8 ppg

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Hydrostatic Pressure (HP) Hydrostatic pressure using ppg and feet as the units of measure Mud weight TVD (ft) Hydrostatic Pressure (psi)

12 ppg 10000 ft 6240.0 psi

Hydrostatic pressure, psi, using pressure gradient, psi/ft Pressure gradient (psi/ft) TVD (ft) Hydrostatic Pressure (psi)

0.5 psi/ft 10000 ft 5000.0 psi

Hydrostatic pressure, psi, using mud weight, lb/ft3 Mud weight (lb/ft3) TVD (ft) Hydrostatic Pressure (psi)

80 lb/ft3 10000 ft 5555.2 psi

Hydrostatic pressure, psi, using meters as unit of depth Mud weight TVD (m) Hydrostatic Pressure (psi)

12 ppg 5000 m 10236.7 psi

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Annular Velocity (AV) in ft/min Formula 1: AV = pump output, bbl/min ÷ annular capacity, bbl/ft Pump out put (bbl/min) 10 bbl/min Annular capacity (bbl/ft) 0.13 bbl/ft Annular Velocity (AV) 76.92 ft/min Formula 2: Flow rate in gpm and diameter between 2 diameters Flow rate (gpm) 800 gpm Bigger diameter (in) 10 in such as hole size, casing ID, etc Smaller diameter (in) 5 in such as drill pipe OD, tubing OD, etc Annular Velocity (AV) 261.33 ft/min Formula 3: flow rate in bbl/min and diameter Flow rate (bbl/min) 13 bbl/min Bigger diameter (in) 10 in such as hole size, casing ID, etc Smaller diameter (in) 5 in such as drill pipe OD, tubing OD, etc Annular Velocity (AV) 178.43 ft/min

Annular velocity (AV), ft/sec Formula 1: Flow rate in bbl/min and diameter between 2 diameters Flow rate (bbl/min) 13 bbl/min Bigger diameter (in) 10 in Smaller diameter (in) 5 in Annular Velocity (AV) 2.97 ft/sec Pump output in gpm required for a desired annular velocity, ft/mim Annular Velocity (ft/min) 120 ft/min Bigger diameter (in) 10 in Smaller diameter (in) 5 in Required pump rate (gpm) 367.35 gpm Strokes per minute (SPM) required for a given annular velocity Annular Velocity (ft/min) 150 ft/min Bigger diameter (in) 10 in Smaller diameter (in) 5 in Pump out put (bbl/stk) 0.1 bbl/stk SPM required 109.29 spm

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Pump out Triplex Pump, bbl/stk efficiency (%) Liner diameter (in) Stroke length (in) PO (bbl/stk)

97 6 in 12 in 0.10183 bbl/stk

Duplex Pump , bbl/stk efficiency (%) Liner diameter (in) Rod diameter (in) Stroke length (in) PO (bbl/stk)

85 6 2 12 0.11236

in in in bbl/stk


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

Buoyancy Factor (BF) Buoyancy factor using mud weight, PPG MW (PPG) BF

13 0.802

Buoyancy factor using mud weight, lb/ft3 MW (lb/ft3) BF

100 0.796

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Amount of cuttings drilled per foot of hole drilled a) BARRELS of cuttings drilled per foot of hole drilled: Porosity(%) Hole diameter (in) BBL/ft

25 6.125 0.027333

Porosity(%) Hole diameter (in) cu-ft/ft

25 6.125 0.153462

bbl/footage drilled b) CUBIC FEET of cuttings drilled per foot of hole drilled: cu.ft/footage drilled

c) Total solids generated: Hole diameter (in) Hole capacity (bbl/ft) Footage drilled (ft) Porosity(%) Cutting Density (gm/cc) Solid generated(pounds)

6.125 0.036444 100 25 2.2 2104.651 pound


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Pressure Gradient Calculation Pressure gradient, psi/ft, using mud weight, ppg MW (ppg) Pressure gradient (psi/ft)

9 PPG 0.468 psi/ft

Pressure gradient, psi/ft, using mud weight, lb/ft3 MW (lb/ft3) Pressure gradient (psi/ft)

80 lb/ft3 0.556 psi/ft

Pressure gradient, psi/ft, using mud weight, specific gravity (SG) MW sg Pressure gradient (psi/ft)

2 0.866 psi/ft

Convert pressure gradient, psi/ft, to mud weight, ppg Pressure gradient (psi/ft) MW (ppg)

0.5 psi/ft 9.62 PPG

Convert pressure gradient, psi/ft, to mud weight, lb/ft3 Pressure gradient (psi/ft) MW (ppg)

0.5 psi/ft 72.00 lb/ft3

Convert pressure gradient, psi/ft, to mud weight specific gravity (SG) Pressure gradient (psi/ft) Specific Gravity

0.5 psi/ft 1.155

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Convert temperature, °Fahrenheit (F) to °Celsius (C) F C

347 175.0

Convert temperature, °Celsius (C) to °Fahrenheit C F

26.667 80.0

Convert temperature, ° Celsius (C) to °Kelvin (K) C K

23 296.2

Convert temperature, °Fahrenheit (F) to °Rankine (R) F R

150 609.7

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Accumulator Pre-charge Pressure P start P final Volume removed Volume total Average pre charge pressure

3000 2000 25 200 750


Bulk Density of Cuttings by using Mud Balance Procedure 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. 5. Move counterweight to obtain new balance. This value is “Rw” = resulting weight with cuttings plus water, ppg. RW, ppg SG

14 3.13

h cuttings plus water, ppg.

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How many feet of drill pipe pulled to lose certain amount of hydrostatic pressure (psi) when pull dry. Hydrostatic pressure to lose Casing capacity Pipe displacement Mud weight Feet of drill pipe pulled

200 0.0873 0.01876 12 1171

psi bbl/ft bbl/ft PPG ft

How many feet of drill pipe pulled to lose certain amount of hydrostatic pressure (psi) when pull wet. % of volume in drill pipe out of hole Hydrostatic pressure to lose Pipe displacement Pipe capacity Casing capacity Mud Weight Feet of drill pipe pulled

100 200 0.0055 0.01876 0.0873 12 833

% psi bbl/ft bbl/ft bbl/ft PPG ft

se certain amount of hydrostatic pressure (psi) when pull dry. Input cells calculated cells Back to the first page Do you want to have a good oilfield resume? Click Here !!!

se certain amount of hydrostatic pressure (psi) when pull wet. Reference http://www.drillingformulas.com/drill-pipe-pulled-to-lose-hydrostatic-pressure/ Website http://www.drillingformulas.com/

Hydrostatic Pressure (HP) Decrease When POOH When pulling DRY pipe Stands pulled Length per stand Pipe displacement Casing capacity Mud Weight BBL displace HP decrease (psi)

10 91 0.0055 0.0873 12 5.01 38.18

stands ft bbl/ft bbl/ft PPG bbl psi

100 10 91 0.0055 0.01876 0.0873 12.0 22.08 218.52

stands ft bbl/ft bbl/ft bbl/ft PPG bbl Psi

When pulling WET pipe % of volume in drill pipe out of hole Stands pulled Length per stand Pipe displacement Pipe capacity Casing capacity Mud Weight BBL displace HP decrease (psi)

Input cells calculated cells Back to the first page Do you want to have a good oilfield resume? Click Here !!! Reference http://www.drillingformulas.com/hydrostatic-pressure-decrease-when-pooh/ Website http://www.drillingformulas.com/

Depth of washout

Method 1: Strokes pumped till pressure increase Internal capacity of drill pipe Pump output Depth of washout

Method 2: Strokes pumped till material seen Internal capacity of drill pipe Annulus capacity Pump output Volume from bell nipple to shale shakers Depth of washout

The concept of this method is to pump plugging material to plug the wash out. We wil calculate back where the washout is. 400 0.00742 0.0855 4609

strokes bbl/ft bbl/stk ft

The concept of this method is to pump material that can be easily observed from drill calculate the depth of washout bases on the combination volume of internal drill pipe 2500 0.00742 0.0455 0.0855 10 3850

strokes bbl/ft bbl/ft bbl/stk bbl ft

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 ck where the washout is. Input cells calculated cells Back to the first page Do you want to have a good oilfield resume? Click Here !!!

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 depth of washout bases on the combination volume of internal drill pipe volume and annulus volume.

Reference http://www.drillingformulas.com/depth-of-washout/ Website http://www.drillingformulas.com/

p till pressure increase then we can

nto annulus and over the surface. We can

Drilling Formulas Calculation Sheet Verson 1.4

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