Workover Calculations

(1)

Atm. PSI kPa Cu.meter BBLs Galons

PSI Atm. kPa Galons BBLs Cu.meter

kPa Atm. PSI BBLs Galons Cu.meter

M3/M BBL/ft #DIV/0! ft/BBL gal/ft #DIV/0! ft/gal lt/m

BBL/ft M3/M #DIV/0! ft/BBL gal/ft #DIV/0! ft/gal lt/m

ft/BBL #DIV/0! BBL/ft #DIV/0! M3/M #DIV/0! gal/ft ft/gal #DIV/0! lt/m

gal/ft BBL/ft #DIV/0! ft/BBL M3/M #DIV/0! ft/gal lt/m

ft/gal BBL/ft #DIV/0! ft/BBL #DIV/0! gal/ft #DIV/0! M3/M #DIV/0! lt/m

lt/m BBL/ft #DIV/0! ft/BBL gal/ft #DIV/0! ft/gal M3/M

meters cm yards mm inches feet

cm yards meters mm inches feet

inches cm meters mm yards feet

feet cm meters mm inches yards

yards cm meters mm inches feet

If you want to compare obtained data in the table above with other data, or if you do not plan to use calculations above for further reference, go to => Converter

CONVERSION DATA TABLE Pressures

Capacities

(2)

Date: Well #:

Oilfield: Tbg Size:

Run for: Tallied in:

Item ## Length, ft Length, m Total Length, ft Total Length, m Remarks

1 #VALUE! 2 #VALUE! #VALUE! 3 #VALUE! #VALUE! 4 #VALUE! #VALUE! 5 #VALUE! #VALUE! 6 #VALUE! #VALUE! 7 #VALUE! #VALUE! 8 #VALUE! #VALUE! 9 #VALUE! #VALUE! 10 #VALUE! #VALUE! 11 #VALUE! #VALUE! 12 #VALUE! #VALUE! 13 #VALUE! #VALUE! 14 #VALUE! #VALUE! 15 #VALUE! #VALUE! 16 #VALUE! #VALUE! 17 #VALUE! #VALUE! 18 #VALUE! #VALUE! 19 #VALUE! #VALUE! 20 #VALUE! #VALUE! 21 #VALUE! #VALUE! 22 #VALUE! #VALUE! 23 #VALUE! #VALUE! 24 #VALUE! #VALUE! 25 #VALUE! #VALUE! 26 #VALUE! #VALUE! 27 #VALUE! #VALUE! 28 #VALUE! #VALUE! 29 #VALUE! #VALUE! 30 #VALUE! #VALUE! 31 #VALUE! #VALUE! 32 #VALUE! #VALUE! 33 #VALUE! #VALUE! 34 #VALUE! #VALUE! 35 #VALUE! #VALUE! 36 #VALUE! #VALUE! 37 #VALUE! #VALUE! 38 #VALUE! #VALUE! 39 #VALUE! #VALUE! 40 #VALUE! #VALUE! 41 #VALUE! #VALUE! 42 #VALUE! #VALUE! 43 #VALUE! #VALUE! 44 #VALUE! #VALUE! 45 #VALUE! #VALUE! 46 #VALUE! #VALUE! 47 #VALUE! #VALUE! 48 #VALUE! #VALUE! 49 #VALUE! #VALUE! 50 #VALUE! #VALUE!

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51 #VALUE! #VALUE! 52 #VALUE! #VALUE! 52 #VALUE! #VALUE! 54 #VALUE! #VALUE! 55 #VALUE! #VALUE! 56 #VALUE! #VALUE! 57 #VALUE! #VALUE! 58 #VALUE! #VALUE! 59 #VALUE! #VALUE! 60 #VALUE! #VALUE! 61 #VALUE! #VALUE! 62 #VALUE! #VALUE! 63 #VALUE! #VALUE! 64 #VALUE! #VALUE! 65 #VALUE! #VALUE! 66 #VALUE! #VALUE! 67 #VALUE! #VALUE! 68 #VALUE! #VALUE! 69 #VALUE! #VALUE! 70 #VALUE! #VALUE! 71 #VALUE! #VALUE! 72 #VALUE! #VALUE! 73 #VALUE! #VALUE! 74 #VALUE! #VALUE! 75 #VALUE! #VALUE! 76 #VALUE! #VALUE! 77 #VALUE! #VALUE! 78 #VALUE! #VALUE! 79 #VALUE! #VALUE! 80 #VALUE! #VALUE! 81 #VALUE! #VALUE! 82 #VALUE! #VALUE! 83 #VALUE! #VALUE! 84 #VALUE! #VALUE! 85 #VALUE! #VALUE! 86 #VALUE! #VALUE! 87 #VALUE! #VALUE! 88 #VALUE! #VALUE! 89 #VALUE! #VALUE! 90 #VALUE! #VALUE! 91 #VALUE! #VALUE! 92 #VALUE! #VALUE! 93 #VALUE! #VALUE! 94 #VALUE! #VALUE! 95 #VALUE! #VALUE! 96 #VALUE! #VALUE! 97 #VALUE! #VALUE! 98 #VALUE! #VALUE! 99 #VALUE! #VALUE! 100 #VALUE! #VALUE! 101 #VALUE! #VALUE! 102 #VALUE! #VALUE! 103 #VALUE! #VALUE! 104 #VALUE! #VALUE! 105 #VALUE! #VALUE! 106 #VALUE! #VALUE! 107 #VALUE! #VALUE! 108 #VALUE! #VALUE!

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109 #VALUE! #VALUE! 110 #VALUE! #VALUE! 111 #VALUE! #VALUE! 112 #VALUE! #VALUE! 113 #VALUE! #VALUE! 114 #VALUE! #VALUE! 115 #VALUE! #VALUE! 116 #VALUE! #VALUE! 117 #VALUE! #VALUE! 118 #VALUE! #VALUE! 119 #VALUE! #VALUE! 120 #VALUE! #VALUE! 121 #VALUE! #VALUE! 122 #VALUE! #VALUE! 123 #VALUE! #VALUE! 124 #VALUE! #VALUE! 125 #VALUE! #VALUE! 126 #VALUE! #VALUE! 127 #VALUE! #VALUE! 128 #VALUE! #VALUE! 129 #VALUE! #VALUE! 130 #VALUE! #VALUE! 131 #VALUE! #VALUE! 132 #VALUE! #VALUE! 133 #VALUE! #VALUE! 134 #VALUE! #VALUE! 135 #VALUE! #VALUE! 136 #VALUE! #VALUE! 137 #VALUE! #VALUE! 138 #VALUE! #VALUE! 139 #VALUE! #VALUE! 140 #VALUE! #VALUE! 141 #VALUE! #VALUE! 142 #VALUE! #VALUE! 143 #VALUE! #VALUE! 144 #VALUE! #VALUE! 145 #VALUE! #VALUE! 146 #VALUE! #VALUE! 147 #VALUE! #VALUE! 148 #VALUE! #VALUE! 149 #VALUE! #VALUE! 150 #VALUE! #VALUE! 151 #VALUE! #VALUE! 152 #VALUE! #VALUE! 153 #VALUE! #VALUE! 154 #VALUE! #VALUE! 155 #VALUE! #VALUE! 156 #VALUE! #VALUE! 157 #VALUE! #VALUE! 158 #VALUE! #VALUE! 159 #VALUE! #VALUE! 160 #VALUE! #VALUE! 161 #VALUE! #VALUE! 162 #VALUE! #VALUE! 163 #VALUE! #VALUE! 164 #VALUE! #VALUE! 165 #VALUE! #VALUE! 166 #VALUE! #VALUE!

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167 #VALUE! #VALUE! 168 #VALUE! #VALUE! 169 #VALUE! #VALUE! 170 #VALUE! #VALUE! 171 #VALUE! #VALUE! 172 #VALUE! #VALUE! 173 #VALUE! #VALUE! 174 #VALUE! #VALUE! 175 #VALUE! #VALUE! 176 #VALUE! #VALUE! 177 #VALUE! #VALUE! 178 #VALUE! #VALUE! 179 #VALUE! #VALUE! 180 #VALUE! #VALUE! 181 #VALUE! #VALUE! 182 #VALUE! #VALUE! 183 #VALUE! #VALUE! 184 #VALUE! #VALUE! 185 #VALUE! #VALUE! 186 #VALUE! #VALUE! 187 #VALUE! #VALUE! 188 #VALUE! #VALUE! 189 #VALUE! #VALUE! 190 #VALUE! #VALUE! 191 #VALUE! #VALUE! 192 #VALUE! #VALUE! 193 #VALUE! #VALUE!

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Mud Density was measured in units "metric" or "english"

Hole Angle, Buoyancy

lbs m. ton degrees ppg kg/m3 Factor lb/ft kg/m

FALSE FALSE 1.000

Neutral

Point Factor ft m

#DIV/0! #DIV/0!

If you need refer to API Tubulars Dimensions, select one of links below:

Drill Collars Drill Collar Data below

Drill Collar Length REQUIRED DRILL COLLAR LENGTH

(7)

The controlling criteria for drill string design are collapse, tension, slip crushing, and dogleg severity. Collapse and tension are used to select pipe weights, grades, and couplings.

Mud Density was measured in units

"metric" or "english"

The most severe collapse loading occurs when the evacuated (or partially empty) drill string reaches the bottom of the well. The load from the annular mud tends to cause pipe collapse.

Safety

ft m ppg kg/m3 psi kPa Factor psi kPa

#VALUE! FALSE FALSE #VALUE! #VALUE! #VALUE! #VALUE!

The tension load can be evaluated after the weights, grades, and section length have been established from the collapse designs.

ft m lb/ft kg/m ft m lb/ft kg/m

Buoyancy Safety

ft m lb/ft kg/m Factor Factor lbs daN

FALSE 1.000

If you need refer to API Tubulars Dimensions, select one of links below:

Tubing Drill Pipe Drill Collars

When you finish your calculations, see comments in the cell => Get Strength Data below

DRILL STRING DESIGN

COLLAPSE

String Length Mud Weight Net Collapse Pressure Pipe Collapse Strength

DC Length DC Weight Pipe Tension Load

TENSION

(8)

ft m in mm in mm ft m Nodal Pendulum

#VALUE! #DIV/0! #VALUE!

F C in m in m in m

PIPE STRING CALCULATIONS 1. Critical Rotational Speed

Length of 1 pipe OD of pipe ID of pipe Length of string Critical RPMs

2. Drill String Stretch due to weight, buoyancy and temperature

Mud SG Stretch due to weight Stretch due to temp. Total Stretch Average Temperature

(9)

TABLE OF DIMENSIONS AND CAPACITIES OF FREQUENTLY USED TUBULARS

If you would like to look at the

inch mm inch mm bbls/ft lt/m lbs/ft kg/m Specification of selected tubulars, please

FALSE FALSE FALSE select the cell "Casing" , "Tubing" , or

FALSE FALSE FALSE "Drill Pipe" and follow

recommenda-FALSE FALSE FALSE tions given in comments.

Casing

If you need to convert values from English Units to Metric or back, go to Sheet "Conversions" or open link to Converter

inch mm inch mm lbs/ft kg/m bbls/ft lt/m bbls/ft lt/m bbls/ft lt/m

FALSE FALSE FALSE

Tubing

inch mm inch mm lbs/ft kg/m bbls/ft lt/m bbls/ft lt/m bbls/ft lt/m

FALSE FALSE FALSE

Drill Pipe

If you need refer to API Tubulars Dimensions, select one of links below:

Tubing Drill Pipe Drill Collars Casing

Present Table is to help during calculations presented at another sheets. Just copy required parameter from tables above and paste

If you have any comments on this Spreadsheet, please contact me on E-mail Address: [email protected]

Metal Displacement Weight ID Weight Capacity TUBING ID Capacity Displacement CASING OD OD OD DRILL PIPE

Displacement Metal Displacement

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1 0 0 0

2 0 0 0 0

3 0 0 0 0

4 0 0 0 0

5 0 0 0 0

The calculation of Mast static Hook Load Rating is based on heaviest string to be run.

1 0 0 #DIV/0! For currently planned strings Mast

2 0 0 #DIV/0! should have a static hook load rating

3 0 0 #DIV/0! of: #DIV/0! lbs

4 0 0 #DIV/0!

5 0 0 #DIV/0!

Click on the Hyperlinks, if you need more information on Casing Tubing Drill Pipe Drill Collar

WORKOVER/DRILLING RIG REQUIRED MAST CAPACITY CALCULATIONS BASED ON PIPE WEIGHT

String Option Travelling System Weight, lbs No of Lines Fluid Buoyancy Factor Casing, DP or Tubing Weight, lbs/ft Pipe String Length, ft Pipe String Length, m DC or BHA Weight, lbs/ft DC or BHA Length, ft DC or BHA Length, m DC or BHA Weight in Mud, lbs Hook Load due to String Overpull, %/100 Safety Factor, %/100 Total Load including Overpull, lbs Effective Mast Load, lbs

(11)

Planned type of drilling fluid is with SG of m. tons lbs 1 0 0 2 0 0 3 0 0 4 0 0 5 0 0

1 0 0 0 #DIV/0! #DIV/0! #DIV/0!

2 0 0 0 #DIV/0! #DIV/0! #DIV/0!

3 0 0 0 #DIV/0! #DIV/0! #DIV/0!

4 0 0 0 #DIV/0! #DIV/0! #DIV/0!

5 0 0 0 #DIV/0! #DIV/0! #DIV/0!

Click on the Hyperlinks, if you need more information onCasing Tubing Drill Pipe Drill Collar

If you have any comments on this Spreadsheet, please contact me on E-mail Address: [email protected]

WORKOVER/DRILLING RIG DEPTH RATING CALCULATIONS BASED ON PIPE WEIGHT

String Option Mast Capacity or SHLR Engine HP Drawworks HP DP, Tbg or Csg Weight, lbs/ft DC or BHA Weight, lbs/ft DC or BHA Length, ft Travelling System Weight, lbs No of Lines String Option Safety Factor, %/100 Overpull, %/100 Mast Capacity with SF Max. Hook Load, with OP, lbs Max. String Weight in Fluid, lbs Max. Depth, ft (with SF and Overpull) Max. Depth, m (with SF and Overpull) Max. Pull Speed, ft/min

(12)

1.000 1.000 1.000 1.000 1.000

If you have any comments on this Spreadsheet, please contact me on

WORKOVER/DRILLING RIG DEPTH RATING CALCULATIONS BASED ON PIPE WEIGHT

Fluid Buoyancy Factor (appr.)

(13)

Delta Engineering Co. Ltd.

The calculatios of required capacity of the mud pump are based on selected API Rules of Thumb Guide for Hydraulics as:

Flow Rate, m3/min = 5 x Bit Diameter, m Bit Pressure Loss = 50-65% of Pump Pressure Annular Velocities = 35-40 m/min for mud

45-55 m/min for water

To reach recommended Annular Velocity of drilling mud the minimum Flow Rate must be maintain as shown in the table below:

Velocity,

inch mm inch mm in2 m2 m/min GPM m3/min

Required Pressure Rating of the Mud Pump is calculated from expected pressure losses in the well as shown in the table below:

Plastic DP DC Drill Pipe Drill Pipe Drill Drill Viscosity, Length, Length, OD, ID, Collar OD, Collar ID,

ctps meters meters mm mm mm mm

in2 m2 in2 m2

psi kPa psi kPa psi kPa psi kPa

#DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!

Remark: The Bit Pressure Loss is not included

in calculations above. Approximate value of bit

psi kPa psi kPa loss based on experience is taken of 50%

#DIV/0! #DIV/0! #DIV/0! #DIV/0! of pump pressure. Bit Pressure Loss is included

#DIV/0! #DIV/0! FALSE in final result below.

Result: To perform sufficient cleaning of the bottom of the hole and efficient penetration rate while drilling, the Mud Pump(s) should has minimum required ratings as:

Working Pressure (including Bit Pressure Loss) at least of #DIV/0! kPa or #DIV/0! psi

Volumetric Rate at least of m3/min

MUD PUMP REQUIRED CAPACITY CALCULATIONS

Annular Velocity Annular Area

Circulating Losses Calculations

Drill Pipe OD Annular Area Min. Pump Rate Hole Size Pump Rate, m3/min Mud Dencity, kg/m3

past Drill Collars past Drill Pipe

m/min m/min

Annular Velocity Annular Area past Drill Pipe past Drill Collars

Loss, Loss,

Loss,

#DIV/0! #DIV/0!

Inside DP Pressure Inside DC Pressure Outside DP Pressure

#DIV/0! #DIV/0! Total Pressure Losses, Outside DC Pressure Loss, Surface Pressure Loss, Author: Sergei Tchernenkov

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Delta Engineering Co. Ltd

Date: Rig #: Oilfield: Company: If you need to convert values from English

Well #: Pump: Liner, inch: Stroke, inch: to Metric units or back, go to Sheet

"Conversions" or link to Converter Csg Length

inch mm inch mm m bbls/ft lt/m bbls Liters

Pipe Length

inch mm inch mm m bbls liters bbls liters bbls liters bbls liters

Rate gal/str bbl/str lt/str

at pump eff. Tbg Volume Anls Vlm Total Vlm

#DIV/0! #DIV/0! #DIV/0! Pump

SPM gal/min BPM lt/min PSI kPa Tbg Volume Anls Vlm Total Vlm bbls liters

CIRCULATION PROGRAM Workover and Well-service

Casing ID

Total

Casing Volume

Pipe ID

Casing OD Casing Capacity

Pipe OD

Total

Circulation Volume Tubing Volume Metal Displ. Annular Volume

w/ rate,min Total

Pump Calculations

Strokes to pump

Rate Pressure Est. Time to pump Actual pumping Time Volume pumped

Pump Efficiency, %:

Author: Sergei Tchernenkov

(15)

Well #: Objectivity of the test: Date: Company: Toolpusher: Driller: Time: Pressure, psi: Pump Rate, SPM: 0 0 0 0 0 0 0 0 0 0 Injectivity Rate, BPD: 0 0 0 0 0 0 0 0 0 0

Pump: Liner, inch: Stroke, inch:

gal/str bbl/str lt/str 0.00 0.0000 0.00

Pump

SPM gal/min BPM lt/min PSI kPa bbls liters

0.00 0.00 0.00 0 0 0.00 0 0.00 0.00 0.00 0 0 0.00 0 0.00 0.00 0.00 0 0 0.00 0 0.00 0.00 0.00 0 0 0.00 0 0.00 0.00 0.00 0 0 0.00 0 0.00 0.00 0.00 0 0 0.00 0 0.00 0.00 0.00 0 0 0.00 0 0.00 0.00 0.00 0 0 0.00 0 0.00 0.00 0.00 0 0 0.00 0 0.00 0.00 0.00 0 0 0.00 0 0.00 0

0:00 0:00

Time to Fill: To Fill The Well: 0:00

Pumping Time Total Pumped: 0:00 0:00 0:00 0:00 0:00 0:00

Rate Pressure Actual pumping

Time w/ Rate

Volume pumped 0:00

0:00

FORMATION INJECTIVITY TEST

TEST DATA

PUMP DATA

Pump Calculations

Pump Efficiency, %: Rate at pump

(16)

0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 0 0.2 0.4 0.6 0.8 1 1.2 Pressure, psi: Injectivity Rate, BPD:

(17)

Delta Engineering Co. Ltd.

Perforated Casing: If you need to convert values from English Units to

Size, inch: Metric or back, go to Sheet "Conversions" or open

Capacity, m3/m: link to Converter

kg/m3 m m kPa/m kPa PSI kg/m3 kg/m3

#DIV/0! #DIV/0! #DIV/0!

kPa/m kPa PSI kPa PSI kPa PSI kPa PSI kPa PSI

#DIV/0! #DIV/0! #DIV/0! #DIV/0!

Actual Effective

kPa PSI kPa PSI m3 m3

#DIV/0! #DIV/0! #DIV/0! #DIV/0!

If you have any comments on this Spreadsheet, please, contact me on E-mail Address:

[email protected]

Workover Calculations©2000, Sergei Tchernenkov Annulus Hydrostatic Pressure Final Maximum Circulating Pressure Formation Pressure Fracture Gradient Equivalent Fluid Density Original Fluid Density Kill Fluid Pressure Gradient

WELL KILLING CALCULATIONS

Tubing Hydrostatic Pressure (if plugged)

Influx Size Formation Fracture Pressure Shut-in Tubing Pressure Kill Fluid Density Well Depth Tubing Length Initial Maximum Circulating Pressure Shut-in Casing Pressure Author: Sergei Tchernenkov

(18)

Date: Report #:

WELL: Lt/m

Capacity: l/m Ltrs/cm:

Tag Pull m ft m ft before after Ltr bbls Ltr bbls cu.m/day bbl/day

1 0 0 0.0 0.0 0 0.0 2 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 3 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 4 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 5 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 6 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 7 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 8 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 9 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 10 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 11 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 12 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 13 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 14 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 15 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 16 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 17 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 18 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 19 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 20 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 21 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 22 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 23 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 24 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 25 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 26 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 27 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 28 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0! 29 0 0 0.0 0.0 0 0.0 #DIV/0! #DIV/0!

0 Liters 0.0 0.0 0 0.0 #DIV/0! #DIV/0!

Tubing Volume to max Swabbing Depth Actual Inflow Rate for swabbing period

Time

SWABBING REPORT

Annulus Capacity:

Swab in: Tbg. Size, inch: Swab to:

Fluid Level Swabbing Depth Level in Tank Theoretical Volume

Total Theoretical Swabbed Volume Total Swabbed Volume

none none none none Volume Recovered Inflow Rate

Remarks none none none none none none none none none none none none none none none none none none none none none none none none none Packer Set or Plugged Tubing

(19)

Actual Inflow Rate for swabbing period

SWABBING REPORT

none none none none Remarks none none none none none none none none none none none none none none none none none none none none none none none none none

(20)

Well #: Company:

The looses are measured in separated tank with V/H (Volume per Height)

capacity equal to m3/cm 0.00 bbl/in 0 gal/in 1 0 0.0 0.0 2 0 0 0.0 0.0 #DIV/0! #DIV/0! 3 0 0 0.0 0.0 #DIV/0! #DIV/0! 4 0 0 0.0 0.0 #DIV/0! #DIV/0! 5 0 0 0.0 0.0 #DIV/0! #DIV/0! 6 0 0 0.0 0.0 #DIV/0! #DIV/0! 7 0 0 0.0 0.0 #DIV/0! #DIV/0! 8 0 0 0.0 0.0 #DIV/0! #DIV/0! 9 0 0 0.0 0.0 #DIV/0! #DIV/0! 10 0 0 0.0 0.0 #DIV/0! #DIV/0! 11 0 0 0.0 0.0 #DIV/0! #DIV/0! 12 0 0 0.0 0.0 #DIV/0! #DIV/0! 13 0 0 0.0 0.0 #DIV/0! #DIV/0! 14 0 0 0.0 0.0 #DIV/0! #DIV/0! 15 0 0 0.0 0.0 #DIV/0! #DIV/0! 16 0 0 0.0 0.0 #DIV/0! #DIV/0! 17 0 0 0.0 0.0 #DIV/0! #DIV/0! 18 0 0 0.0 0.0 #DIV/0! #DIV/0! 19 0 0 0.0 0.0 #DIV/0! #DIV/0! 20 0 0 0.0 0.0 #DIV/0! #DIV/0! 21 0 0 0.0 0.0 #DIV/0! #DIV/0! 22 0 0 0.0 0.0 #DIV/0! #DIV/0! 23 0 0 0.0 0.0 #DIV/0! #DIV/0! 24 0 0 0.0 0.0 #DIV/0! #DIV/0! 25 0 0 0.0 0.0 #DIV/0! #DIV/0! 26 0 0 0.0 0.0 #DIV/0! #DIV/0! 27 0 0 0.0 0.0 #DIV/0! #DIV/0! 28 0 0 0.0 0.0 #DIV/0! #DIV/0! 29 0 0 0.0 0.0 #DIV/0! #DIV/0! 30 0 0 0.0 0.0 #DIV/0! #DIV/0! 31 0 0 0.0 0.0 #DIV/0! #DIV/0! 32 0 0 0.0 0.0 #DIV/0! #DIV/0! 33 0 0 0.0 0.0 #DIV/0! #DIV/0! 34 0 0 0.0 0.0 #DIV/0! #DIV/0! 35 0 0 0.0 0.0 #DIV/0! #DIV/0! 36 0 0 0.0 0.0 #DIV/0! #DIV/0! 37 0 0 0.0 0.0 #DIV/0! #DIV/0! 38 0 0 0.0 0.0 #DIV/0! #DIV/0! 39 0 0 0.0 0.0 #DIV/0! #DIV/0! 40 0 0 0.0 0.0 #DIV/0! #DIV/0! #DIV/0! #DIV/0! Workover Calculations©2000, Sergei Tchernenkov

Gauge Elapsed,

min m

3 _bbl _gal

m3/min BPM

Average Looses for measuring period TANK LOOSES RECORD

Measure No

Time

Level, cm

(21)

m3/min 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 BPM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 L o ss es V alue Time

Losses during operations

(22)

Well: Company:

Formation Pressure 0 kPa

0 bar psi

Formation Fluid Density kg/m3 Kill Fluid Density kg/m3

0.00 ppg 0.00 ppg

Formation Fluid SG 0.00 Kill Fluid SG 0.00

Perforation Depth meters Estimated Fluid Level meters

0 feet 0 feet

Diferential Pressure @ perfs 0 kPa Required Differential Pressure 0 kPa

0 bar bar

0 psi 0 psi

Trip Tank Volume/Height m3/cm

0.00 bbl/in 0 gal/in

Average Looses #DIV/0! m3/min Average Injection Rate #DIV/0! m3/min

#DIV/0! bbl/min #DIV/0! bbl/min

(23)

0 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 #DIV/0! ##### #DIV/0! #DIV/0! ## #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!

0

0.2

0.4

0.6

0.8

1

1.2

1.4

1.6

0

0.5

1

1.5

2

2.5

3

3.5

4

4.5

5

(24)

Op. Type daN-km daN-km

From To (Dr=1;Tr=2) Size kg/m Size kg/m Length Drilling Short Trip

1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 Mud Density Buoyancy Factor D.P.Eff. Weight D.C.Eff. Weight d Total daN-km Rem.daN-km Notes

1" DRILL LINE EVALUATION RECORD (for 98' - 110' derricks)

#

Depth

Date

(25)

1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00 1.000 0.00 0 0 0 0.00 0.00 716.00

(26)

Milling Tool Remarks: If mill is bouncing or torquing up, slow Diameter, inch Minimum Maximum RPM down as this will fracture carbides.

#DIV/0! #DIV/0!

Type of Mill RPM Weight, Min. Vis. Remarks

lbs of Mud

Junk Mill 100 4,000-10,000 50 Spud Mill from time

to time

Pilot Mill 125 6,000-10,000 60 Vary weight to attain best cutting speed Taper Mill 50-80 2,000-4,000 50 Begin with light weight

and low speed Servco Economill 100 2,000-8,000 55 Start Economill about

one foot above fish Washover Shoe 50-100 2,000-6,000 50 Pick up from time to time Servco K-Mill 100-125 4,000-8,000 55-60 Do not mill faster than

cuttings are removed Drill Mill 55-80 2,000-4,000 50 Start with light weight

and low speed Junk Master 50-80 2,000-4,000 50 Do not mill faster than

cuttings are removed

Material Junk Pilot Econo- Section K-Mill Washover

Mill Mill mill (6 blades) Shoe

Casing 2-4 2 2-4

Drill Pipe 2-6 2-4 2-4 6

Drill Collars 1-2 1-2 2-3 4

Packers 4 2-3 2-3

Bits, Cones, etc 2-4 2-6

General Junk 3-5 2-4

Wash Pipe 2-4 4

MILLING PROGRAM

A. MIN (MAX) RECOMMENDED RPM OF PIPE STRING FOR MILLING RPM