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Well Test Dept. Saudi Arabia Ver 8.0

Note : This table is for a general guide only - results must be obtained for reporting using recognised calculation tables.

By:Stephen

Main Testing menu

Press

Pressure Conversions

Psig Bar Kpa atms inH2O ftH2O inHg mmHg Kgs/cm^2

14.73 1 2100 6 7 8 9 1 4

Psig 14.73 14.503263234 304.56852792 88.170462895 0.252616384 3.464 4.42043222 0.0193369738 56.889

Bar 1.0 1 21 6.0793534166 0.0174178997 0.2389 0.3047888016 0.0013332843 3.92252

Kpa 101.6 100 2100 607.93534166 1.7417899675 23.887 30.478880157 0.1333284346 392.252

atms 1.0023765 0.9869470631 20.725888325 6 0.0171905449 0.236 0.3008104126 0.0013158811 3.87132

inH2O 408.2 401.88542422 8439.5939086 2443.2035268 7 96.00 122.49017682 0.5358275451 1576.40

ftH2O 34.01 33.490452018 703.29949239 203.6002939 0.5833333333 8.00 10.207514735 0.0446522954 131.36686

inHg 30.0 29.528643945 620.10152284 179.51506245 0.5143269578 7.054 9 0.0393700787 115.827

mmHg 761.8 750.0275562 15750.57868 4559.6825863 13.063904728 179.16 228.6 1 2941.9957

Kgs/cm^2 1.03569576 1.0197534445 21.414822335 6.1994415871 0.0177619632 0.2436 0.3108094303 0.0013596213 4.00000

Conversions

Press

Conversions

Vol

Volume Conversions

Litres US Gallons Barrels ins^3 ft^3 cm^3

120 1 1 1558.04 1 1

Litres 120.00 3.7854 158.99 25.5316 28.32 0.0010

US Gallons 31.70 1.0000 42.00 6.7448 7.48 0.0003

Barrels 0.75 0.0238 1.00 0.1606 0.18 0.0000

in^3 7322.88 231.0002 9702.01 1558.0400 1728.00 0.0610

ft^3 4.24 0.1337 5.61 0.9016 1.00 0.0000

cm^3 120000.00 3785.4008 158986.83 25531.6015 28316.74 1.0000

m^3 0.12 0.0038 0.16 0.0255 0.03 0.0000

Volumes

Vol

Volume Conversions

m^3

50

50000.00

13208.64

314.49

3051199.12

1765.74

50000000.00

50.00

Volumes

Temp

Temperature Conversions

Fahrenheit Celsius Kelvin Rankin

1 1 1 1

Fahrenheit 1 33.8 -458.2 -459

Celsius -17.22 1.00 -272.33 -272.78

Kelvin 256.11 274.33 1 0.55

Rankin 461.00 493.80 1.81 1.00

Temperature

Lengths

Length Conversions

Inches Feet Yards Miles mm cm m km

24 1 1 1 1 1 1 1

Inches 24 12.0 36 63360 0.0393700787 0.3937007874 39.37 39370.07874

Feet 2.0000 1.0000 3.0000 5280.0 0.003 0.033 3.281 3280.8

Yards 0.667 0.333 1.000 1760.00 0.001 0.011 1.094 1093.61

Miles 0.0003788 0.0001894 0.0005682 1.0000000 0.0000006 0.0000062 0.0006214 0.6213712

mm 609.6 304.8 914.4 1609344 1.0 10.0 1000.0 1000000

cm 60.96 30.48 91.44 160934 0.10 1.00 100.00 100000

m 0.6096 0.3048 0.9144 1609.344 0.001 0.01 1 1000

km 0.00061 0.00030 0.00091 1.60934 0.00000 0.00001 0.00100 1.00000

Lengths

Rates

Rates Conversions

bbl/day bbl/min gall/min m^3/day m^3/min ltr/min

1 1 1 1 1 1

bbl/day 1 1440 34 6 9057 9

bbl/min 0.00 1.00 0.02 0.00 6.29 0.01

gall/min 0.0 42.0 1.0 0.2 264.2 0.3

m^3/day 0.2 228.9 5.5 1.0 1440.0 1.4

m^3/min 0.00 0.16 0.00 0.00 1.00 0.00

ltr/min 0.1 159.0 3.8 0.7 1000.0 1.0

Rates

Densities

Density Conversions

°API S.G. ppg lb/ft^3 g/cc

1 1 1 1 1

°API <10° 10.0 >60° >60° 10.0

S.G. 1.068 1.000 0.120 0.016 1.000

ppg 8.90 8.34 1.00 0.13 8.34

lb/ft^3 66.60 62.36 7.48 1.00 62.36

g/cc 1.068 1.000 0.120 0.016 1.000

psi/ft 0.462 0.433 0.052 0.007 0.433

bar/m 0.1046032075 0.09795 0.0117488305 0.0015707184 0.09795

Densities

Densities

Density Conversions

psi/ft bar/m

1 1

<10° <10°

2.309 10.209

19.25 85.11

144.02 636.65

2.309 10.209

1.000 4.421

0.2262124711 1

Densities

Gas

Gas Flow Rate Estimation through a fixed choke when Critical Flow exists

Choke Size (64ths) 28 Choke Size (64ths)

Choke Coefficient 85.33 Choke Coefficient

Upstream Pressure (Psig) 4132 Upstream Pressure (Psig)

Downstream Temperature (deg f) 51

Gas Gravity (Air =1) 0.662

GAS RATE (Mscfd) 19238 GAS RATE (Mscfd)

CRITICAL FLOW - When the Downstream Pressure is less than half of the Upstream Pressure

Use this side if you know the DownstreamTemperature and Gas Gravity

Gas flow

Gas

Gas Flow Rate Estimation through a fixed choke when Critical Flow exists

26

73.10

4414

17986

CRITICAL FLOW - When the Downstream Pressure is less than half of the Upstream Pressure

Gas flow

Oil

Estimate Oil Flow Rate through a fixed choke using both Gilbert's and Ros's multi-phase flow equations

Upstream Pressure (psig) 3000

Choke Size (64ths) 32

GOR (scf/bbl) 250

OILRATE (bpd) 10282

Gilbert Equation Qo = P * ( C^1.89) / 435

* ((G/1000) ^ 0.546)

P = Upstream Pressure (psig) C = Choke size (64ths) G = GOR (scf/bbl)

Oil rate

Oil

Estimate Oil Flow Rate through a fixed choke using both Gilbert's and Ros's multi-phase flow equations

OILRATE (bpd) 11221

Ros Equation Qo = ( P + 14.73 ) * ( C ^ 2 ) /

17.4 * ( G ^ 0.5 )

Oil rate

Choke Nipple Gas Rate Calculations

Choke Size Co-efficient WHP WHT Gas Gravity Atmos Temp Gas Rate Choke Size Co-efficient WHP WHT Gas Gravity Gas Rate(64ths) psig °F Air = 1 Absolute mscf/d (64ths) psig °F Air = 1 mscf/d

14.7 4602/64 0.324 50/64 286.1923/64 0.918 52/64 310.6044/64 1.638 54/64 336.0595/64 2.610 56/64 362.5606/64 3.690 58/64 390.1107/64 5.166 60/64 418.7138/64 6.250 62/64 448.3719/64 7.992 64/64 479.088 3000 200.0 0.700 67195.22

10/64 9.954 68/64 543.70911/64 12.132 72/64 612.59812/64 14.440 80/64 763.26613/64 17.208 88/64 931.25114/64 20.088 96/64 1116.69715/64 23.184 112/64 1540.49416/64 26.510 1000 100.0 0.700 1358.64 128/64 2035.61217/64 30.006 2000 120.0 0.700 3000.24 82 803.633 1740 183.0 0.750 64213.2618/64 33.930 Enter unusual choke size in Box above.19/64 37.98020/64 43.640 3000 140.0 0.700 6419.5421/64 46.81822/64 51.588 Qmscfd = Coefficient x Pressure absolute23/64 56.592 sqrt(Gas gravity x Temp absolute)24/64 61.21025/64 67.32026/64 73.134 Requirements for accurate results are:-27/64 79.092 1 Critical Flow28/64 85.130 2 Dry gas29/64 91.818 3 Positive choke bean (6" long)30/64 98.532 4 Ideal Gas31/64 105.51632/64 112.720 3000 120.0 0.700 16864.8336/64 144.180 3820 215.0 0.680 25806.5640/64 179.740 3750 205.0 0.700 31362.8344/64 219.16848/64 260.990 967 111.0 0.920 11178.68

GOR2

Separator pressure (psig) 720Oil line temperature (°f) 136

Gas gravity (Air =1) 0.751Oil API gravity @ 60°f 48.3

GOR 2 247 GOR 2 235

This routine estimates the Solution GOR ( GOR 2 ) Rs (scf/stbbl) for saturated oilusing both STANDING's and VASQUEZ & BEGG's correlations

STANDING ^1.204 p Rs = g 18 * 10 ^ yg

VASQUEZ & BEGG

C3 * api Rs = C1 * g * p^C2 * exp T + 460

p =Separator Pressure (psia) T = Oil line temperature (°f) g = Gas gravity (Air = 1) api = Oil API gravity @ 60°f yg = 0.00091(T) - 0.0125( api)C1,2,3 = constants dependant on oil API value

Oil API <= 30C1 = 0.0362C2 = 1.0937C3 = 25.724

Oil API >30C1 = 0.0178C2 = 1.1870C3 = 23.931

Rates

GOR2

This routine estimates the Solution GOR ( GOR 2 ) Rs (scf/stbbl) for saturated oilusing both STANDING's and VASQUEZ & BEGG's correlations

VASQUEZ & BEGG

C3 * api Rs = C1 * g * p^C2 * exp T + 460

Oil API >30C1 = 0.0178C2 = 1.1870C3 = 23.931

Rates

Kfactor

769.51659227001 0.9994523032 769.09513 0.00058###### 0 0 1### 480.0478184109828 0.12 0.9928106 0.96849###

OBSERVED API 52.2

HYDROMETER TEMPERATURE 102

OIL LINE TEMPERATURE (deg f) 120

OIL API GRAVITY @ 60°f 47.8

K FACTOR 0.9679

This routine converts an observed API and Hydrometer reading to Oil API gravity @ 60°f

and works out a K factor value for a given Oil line temperature

A.P.I.

SpecificationsLinear Flow Range

FLOW NOMINAL MAXMETER GPM M3/DAY BBLS/DAY

SIZE FACTOR FREQUENCY(PULSES/SEC)

3/8 x 1(3) .3-3 1.6-16 10 to 100 22,000 (5,812) 1,100

1/2 x 1(3) .75-7.5 4 to 40 25 to 250 14,500 (3,830) 1,815

3/4 x 1(3) 2 to15 11 to 80 68 to 515 2,900 (766) 725

7/8 x 1(3) 3 to 30 16 to 160 100 to 1,000 2,300 (608) 1,150

1 x 1 5 to 50 27 to 270 170 to 1,700 925 (244) 771

1 x 2 5 to 50 27 to 270 170 to 1,700 925 (244) 771

1-1/2 x 2 15 to180 80 to 1,000 515 to 6,000 325 (86.0) 975

2 40 to 400 210 to 2,100 1,300 to 13,000 55 (14.5) 365

3 60 to 600 335 to 3,300 2,100 to 21,000 57 (15.2) 570

4 100 to1,200 540 to 6,500 3,400 to 41,000 30 (7.9) 600

6 200 to 2,500 1,100 to 14,000 6,800 to 86,000 7 (1.8) 290

8 350 to 3,500 1,900 to 19,000 12,000 to 120,000 3 (.8) 175

PULSES/GAL (PULSES/dm3)

Turbine

HALLIBURTON TURBINE METERS

METER

1.5" OIL 326 13692 136.9 6.312" OIL

3" OIL ( 1 ) 55.2 2318 23.2 37.273" OIL ( 2 )

WATER

Input pulses/bbl into Scan from table above . If meter is changed, enter new value.

Meter Calibration

from meter (pulses/gall)

Pulses per bbl

(Enter in SCAN)

Number to Enter in TOP display (1 decimal place)

(bbls)

Number to Enter in BOTTOM

display (bbl/day)

Note: The MCII analyzer should also have the correct divisor entered for accuracy.

Meters

Turbine

Meters

Quick Gas Rate Estimation

Enter Choke Size ( 64ths ) 46

Calculated Co-efficient 240.4800

Enter Wellhead Pressure ( psia ) 4000

Enter Wellhead Temperature ( F ) 183

Enter Gas Gravity ( Use 0.7 for default ) 0.75

Atmos 14.73

Temp Absolute 460

Estimated Dry Gas Rate 43.804 mscf/day

3phase

3 Phase Electrical current calculations

440 1000 0.875 1500 10497

Convert Kw to Hp Convert Hp to KwKw Hp Hp Kw

1000 1340 1380 1029

3 phase supply voltage (Volts)

Power rating of

motor (Kilowatts)

Power factor ( use 0.875)

Full load current (Amps)

Start up current (Amps)

3Phase

3phase

3Phase

DVM

Signal

0 whp 10000 14 1.000 5.000 32,500.0

1 wht 400 1.000 5.000

2 csg 5000 22 1.000 5.000 26,250.0

3 dsp 5000 1.000 5.000

4 dst 400 1.000 5.000

5 static 2000 1.000 5.000

6 diff 400 1.000 5.000

7 oiltemp 400 1.000 5.000

8 gastemp 400 1.000 5.0009 1.000 5.000

DVM channel

Transducer Range

Raw Voltage

Zero Value

Max Value

Calculated Reading

Raw Voltage.

DVM

Raw Voltage.

Halliburton Saudi Arabia

Meter Factor Calibration Data Sheet

Welltest Unit # 1

Well Name & Number Hawiyah 959

DATE 4-Apr-01 METER SIZE 1.5" TurbineTIME 8:00 METER SERIAL No TEST NUMBER 1 TANK NUMBER 1API @ 60 F 52.4 TANK FACTOR 0.4348

64 METER TEMPERATURE F 96INITIAL TANK (reading cm ) 0 INITIAL METER (reading bbls ) 350FINAL TANK (reading cm ) 35 FINAL METER (reading bbls ) 370TANK INCREASE ( bbls ) 15.22 METER INCREASE (bbls) 20.00K FACTOR 0.9975 K FACTOR 0.9900TANK VOLUME INCREASE 15.18 METER VOLUME INCREASE 19.80

CORRECTION FACTOR (Cf) 0.767

1.5" Turbine * Pre-test Mf 0.990

Wf ( Cf / Pre-test Mf ) 0.774

SUPERVISOR / OPERATOR Mf ( Cf / Wf ) 0.990

SIGNATURE

* Note: Pre-test Mf is obtained using water prior to test.

TANK CONVERSION FACTORS

Tank Number 1 : 1 cm = 0.4452 bblsTank Number 2 : 1 cm = 1.00 bblsTank Number 3 : 1 cm = 1.00 bbls

Meter Calibration should be performed at least once per 12 hour flow period and following a choke /rate change.

TANK TEMPERATURE F

Meters

Meter Model Size Range ( gall/min ) Range ( bbl/day )

Type Number (inches) Minimum Maximum Minimum Maximum

Floco F2500 - 1 1 6 60 206 2057

Floco F2500 - 2 2 6 60 206 2057

Floco F2500 - 3 3 9 90 308 3086

Floco F382 2 30 250 1029 8571

Floco F383 3 30 250 1029 8571

Rotron xxxx - 20 2 25 250 857 8571

Rotron xxxx - 30 3 60 650 2057 22286

Rotron xxxx - 40 4 200 1200 6857 41113

Halliburton 1.5 15 180 500 6100

Halliburton 2 40 400 1300 13000

Halliburton 3 60 600 2100 21000

Halliburton 4 100 1200 3400 41000

Currents

Nominal Temperature rise = 45°Ccross-sectional N° of conductors

area 2 3 4 ( mm ^2 ) (Amps) (Amps) (Amps)

2 20 17 153 27 22.5 215 35 31 28

10 53 47 4416 66 60 5525 88 81 7040 110 103 8850 130 123 10575 167 154 13295 192 184 155

RETURN TO MAIN MENU

Calcs

Calculation interval (mins) 60 Gas meter run size (ins) 5.761

Observed API gravity 50.0 Orifice plate size (ins) 1.500

Observed hydrometer temp (deg f) 78.0 Separator pressure (psig) 280

Current meter reading (bbls) 590.0 Differential pressure (inH2O) 125

Previous meter reading (bbls) 7.0 Gas gravity (Air=1) 0.700

Oil line temperature (deg f) 90 Gas line temperature (deg f) 68

(BS&W) (%) 25

Meter Factor 0.998

Shrinkage Factor 0.998

Oil Rate (bpd) 10283.91 Gas Rate (mscfd) 2575

GOR (scf/bbl) 250.4 OGR (bbl/mmscf) 3994.2

GAS FLOWRATE FACTORS

METHOD USED FOR CALCULATING OIL FLOWRATE

Vo = Volume of oil at atmospheric pressure and temperature ( i.e. 14.73 psia @ 60°f ) Vm = Volume of oil registered by meter(s) since last reading at separator pressure and temp. Cf = Measured correction factor. It is obtained by calibrating the meter with a tank during the test and includes both the meter factor ( Mf ) and the weathering factor ( Wf ) Cf = Mf * Wf Mf = Meter factor, it is to correct for any meter non linearities. Wf = Weathering factor = Volume of oil at 14.73 psia @ 60°f / Volume of oil at separator conditions. NB!! Wf = (1 -Sh) where Sh = Oil shrinkage from separator to stock tank conditions. k = Temperature correction factor from ASTM tables ( k = 1 for an oil temperature of 60°f ) BSW = Basic sediment and water measured using field centrifuge method Percent of BSW volume to total volume of oil and BSW. Vt = Volume of oil measured in tank at tank temperature since last reading.

measurement by meterVo = Vm * Cf * k * ( 1- BSW/100 )

measurement by tankVo = Vt * k * ( 1- BSW/100 )

METHOD USED FOR CALCULATING GAS FLOWRATE

hw = Differential pressure across orifice plate measured in inches of water @ 60°f Pf = Static pressure ( taken from downstream tap of Daniel's box ) measured in psia Fpv = Supercompressibility factor ( corrected for N2, H2S and CO2 ) Fb = Basic Orifice factor Fg = Specific Gravity factor Ftf = Flowing temperature factor Ftb = Temperature base factor Fpb = Pressure base factor Fr = Reynolds number factor ( equal to 1 ) Fm = Manometer factor ( equal to 1 ) Y2 = Expansion factor for downstream pressure tap Unit Conversion factor = Factor changing flowrate units

Corrected gas flowrate ( Qg ) = C * sqrt( hw * Pf ) where C ( Orifice flow constant ) = Fpv * Fb * Fg * Ftf * Ftb * fr * Y2 * Fm * Unit

conversion factor

Corrected oil flowrate ( Qo ) Vo / Time to produce the volume Vo

Fu factor Fu = Ftb * Fpb * Unit conversion factor

Standard conditions of 14.73 psia @ 60°fand gas flowrate in standard cubic feet / day

Fu factor = 24

Calc Rates

Group Box 19

Calcs

Sqrt (hw*Pf) 191.94Fpv 1.0325 Supercompressibility factor

Fb 455.03 Basic Orifice factorFg 1.19523 Specific gravity factorFtf 0.99240 Flowing temperature factorY2 1.00298 Expansion factor for downstream pressure tap

Ftb 60 Temperature base factorFpb 14.73 Pressure base factor

Fu 24 Value for gasrate in scfd (14.73psia @ 60°f)C1 28.69C2 467.63

C 13414.13

Group Box 19

Calcs

0.260371 427.440735 0.602334 -0.103581

294.730000 191.940746 28.685487 0.992395

778.844066 0.999768 778.663336 0.000563

0.048198 0.090000 1.002536 0.984236

METHOD USED FOR CALCULATING OIL FLOWRATE

Vo = Volume of oil at atmospheric pressure and temperature ( i.e. 14.73 psia @ 60°f ) Vm = Volume of oil registered by meter(s) since last reading at separator pressure and temp. Cf = Measured correction factor. It is obtained by calibrating the meter with a tank during the test and includes both the meter factor ( Mf ) and the weathering factor ( Wf ) Cf = Mf * Wf Mf = Meter factor, it is to correct for any meter non linearities. Wf = Weathering factor = Volume of oil at 14.73 psia @ 60°f / Volume of oil at separator conditions. NB!! Wf = (1 -Sh) where Sh = Oil shrinkage from separator to stock tank conditions. k = Temperature correction factor from ASTM tables ( k = 1 for an oil temperature of 60°f ) BSW = Basic sediment and water measured using field centrifuge method Percent of BSW volume to total volume of oil and BSW. Vt = Volume of oil measured in tank at tank temperature since last reading.

measurement by tankVo = Vt * k * ( 1- BSW/100 )

METHOD USED FOR CALCULATING GAS FLOWRATE

hw = Differential pressure across orifice plate measured in inches of water @ 60°f Pf = Static pressure ( taken from downstream tap of Daniel's box ) measured in psia Fpv = Supercompressibility factor ( corrected for N2, H2S and CO2 ) Fb = Basic Orifice factor Fg = Specific Gravity factor Ftf = Flowing temperature factor Ftb = Temperature base factor Fpb = Pressure base factor Fr = Reynolds number factor ( equal to 1 ) Fm = Manometer factor ( equal to 1 ) Y2 = Expansion factor for downstream pressure tap Unit Conversion factor = Factor changing flowrate units

Corrected gas flowrate ( Qg ) = C * sqrt( hw * Pf ) where C ( Orifice flow constant ) = Fpv * Fb * Fg * Ftf * Ftb * fr * Y2 * Fm * Unit

conversion factor

Fu factor Fu = Ftb * Fpb * Unit conversion factor

Standard conditions of 14.73 psia @ 60°fand gas flowrate in standard cubic feet / day

Fu factor = 24

C1 = Fu * Fg ( theoretically constant during test )C2 = Fpv * Fb * Ftf * Y2

C = C1 * C2

Group Box 19

Calcs

Group Box 19

Calcs

0.000000 0.239629 0.001748 -0.439629

1.032480 0.016117 1.002984 467.627851

0.010126 0.008101 0.000082 -0.010208

0.983912 24.000000 0.750000 583.000000

Calcs

0.000000 0.600585 0.598029 455.030010

13414.132466 2574718.593394 2574.718593

0.989844 786.652874 48.198318

0.996004 428.496243 10283.909828

Tankvol

RECTANGULAR TANK HORIZONTAL

Height of tank (ins) 4 CYLINDRICAL TANK

Length of tank (ins) 4 Diameter of vessel (ins) 42.0

Width of tank (ins) 5 Length of vessel (ft) 10.00

Estimated Total Volume (bbls) 0.01 Estimated Total Volume (bbls) 17.14

Estimated Total Volume (galls) 0.3 Estimated Total Volume (galls) 719.71

Height of fuid level in tank (ins) 12 Height of fuid level in tank (ins) 46

Estimated Tank Volume (bbls) 0.02 Estimated Tank Volume (bbls) 17.10

Estimated Total Volume (galls) 1.04 Estimated Total Volume (galls) 718.20

Weight of fluid in tank (ppg) 67

Tare weight of tank (tons) 4

Max fluid weight (tons) 0.01

Weight of tank + fluid (tons) 4.01

Max deck loading (lb/ft) 64679

Volumes

Estimate the total volume of a rectangular or horizontal cylindrical tank, contents at any given fluid level and maximum weight and deck loading of a rectangular tank

Tankvol

Height (ins) - H 42 H/h

Length (ft) - L 10 1.0952380952

Total Volume (bbls) - V 17.1 fraction of H

Fluid level (ins) - h 46 1.1

fraction of V

Estimate thtank (bbls) 17.1 1

Volumes

Estimate the total volume of a rectangular or horizontal cylindrical tank, contents at any given fluid level and maximum weight and deck loading of a rectangular tank

Tankvol

Fraction Value

0.01 0.0017

0.02 0.0047

0.03 0.0087

0.04 0.0134

0.05 0.0187

0.06 0.0245

0.07 0.0308

0.08 0.0375

0.09 0.0446

0.10 0.0520

0.11 0.0599

0.12 0.0680

0.13 0.0764

0.14 0.08510.15 0.09410.16 0.10330.17 0.11270.18 0.12330.19 0.13230.20 0.14240.21 0.15260.22 0.16310.23 0.17370.24 0.18450.25 0.19550.26 0.20660.27 0.21790.28 0.22920.29 0.24070.30 0.2552

Tankvol

0.31 0.26400.32 0.27590.33 0.28780.34 0.29980.35 0.31190.36 0.32410.37 0.33640.38 0.34870.39 0.36110.40 0.37360.41 0.3860.42 0.39860.43 0.41110.44 0.42370.45 0.43640.46 0.4490.47 0.46170.48 0.47450.49 0.48720.50 0.50.51 0.51280.52 0.52550.53 0.53830.54 0.5510.55 0.56360.56 0.57630.57 0.58890.58 0.60140.59 0.6140.60 0.62640.61 0.63890.62 0.65130.63 0.66360.64 0.67590.65 0.68810.66 0.70020.67 0.71220.68 0.72410.69 0.7360.70 0.74770.71 0.75930.72 0.77080.73 0.78210.74 0.79340.75 0.80450.76 0.81550.77 0.82630.78 0.83690.79 0.84740.80 0.85760.81 0.86770.82 0.87760.83 0.88730.84 0.8967

Tankvol

0.85 0.90590.86 0.91490.87 0.92360.88 0.9320.89 0.94010.90 0.9480.91 0.95540.92 0.96250.93 0.96920.94 0.97550.95 0.98130.96 0.98660.97 0.99130.98 0.99520.99 0.99831.00 1

Pipesched

Nominal Wall thickness Inside Diameterpipe Outside Schedule Schedule Schedule Schedule size Diameter 40 80 40 80(ins) (ins) (ins) (ins) (ins) (ins)

1 1.315 0.133 0.179 1.049 0.957

1.5 1.900 0.145 0.200 1.610 1.500

2 2.375 0.154 0.218 2.067 1.939

2.5 2.875 0.203 0.276 2.469 2.323

3 3.500 0.216 0.300 3.068 2.900

3.5 4.000 0.226 0.318 3.548 3.364

4 4.500 0.237 0.337 4.026 3.826

5 5.563 0.258 0.375 5.047 4.813

6 6.625 0.280 0.432 6.065 5.761

8 8.625 0.322 0.500 7.981 7.625

10 10.750 0.365 0.594 10.020 9.562

12 12.750 0.406 0.688 11.938 11.374

Schedule 40Standard Wall

Schedule 80Extra Strong

Wall

Prefixes

Multiplying factor Prefix Symbol

10^18 exa E

10^15 peta P

10^12 tera T

10^9 giga G

10^6 mega M

10^3 kilo k

10^2 hecto h

10^1 deca da

10^-1 deci d

10^-2 centi c

10^-3 milli m

10^-6 micro µ

10^-9 nano n

10^-12 pico p

10^-15 femto f

Prefix

Retention

Estimated retention time in separator.

Separator capacity (bbls) 17.4

Separator fluid level (%) 50

Flowrate (bpd) 6600

Retention Time ( mm:ss ) 1:53

Retention

Retention

1.90

1

53

53

Retention

Dosage

Product Type Product Name Required Dosage

OIL ANTIFOAM TROS DF328 0.5 - 1 ppm

DEMULSIFIER PHASETREAT 6026E 10 ppm

SCALE INHIBITOR TROS 93-64 30 ppm

FLOWRATE ( bpd ) 12000

CHEMICAL INJECTION RATE

ANTIFOAM 1.3 cc / min

DEMULSIFIER 13 cc / min

SCALE INHIBITOR 40 cc / min

WELL TEST CHEMICALSTROS - TR OIL SERVICES ( 01224 - 884239 )

WELL TEST CHEMICALSTROS - TR OIL SERVICES ( 01224 - 884239 )

Dosage

Dosage

Dosage

Chokes

Choke Size Conversion

Choke Decimal Metricsize equivalent equivalent

( 64ths ) (ins) mm

24

Choke size (64ths) 24

Decimal (ins) 0.375

Metric (mm) 9.52

Chokes

Symbols

Description Symbol Unit

Formation Volume Factor (Gas) Dimensionless

Formation Volume Factor (Oil) psi-1

Compressibility (Gas) Cg psi-1

Compressibility (Oil) Co psi-1

Compressibility (Water) Cw psi-1

Compressibility (Formation) Cf psi-1

Compressibility (Total) Ct psi-1

Formation Thickness (Net Pay) h feet

Productivity Index (PI) J bpd/psi

Formation permeability k mD (milliDarcy)

Gradient (slope) of line on build-up plot m psi / log cycle

Initial reservoir pressure Pi psia

Description Symbol UnitBottomhole flowing pressure Pwf psiaBottomhole shut-in pressure Pws psiaPressure 1 hour after shut-in P1hr psiaExtrapolated pressure (pressure at X=1) P* psiaProduction rate at surface (Gas) Qg MscfdProduction rate at surface (Oil) Qo stobpdWellbore radius (open hole not casing size) rw ins or feetSkin factor S dimensionlessPressure drop due to Skin at wellbore psiaFlowing Time t hoursShut-in Time hoursGas deviation factor z dimensionless

Description Symbol UnitPorosity f % or fractionViscosity (Gas) cp (centipoise)Viscosity (Oil) mo cp (centipoise)

bg

bo

dPskin

dt

mg

STANDARD OILFIELD SYMBOLS AND UNITSSTANDARD OILFIELD SYMBOLS AND UNITSSy

Symbols

STANDARD OILFIELD SYMBOLS AND UNITSSTANDARD OILFIELD SYMBOLS AND UNITSSy

Argentometic Method for Chloride Determination

A Quantity of silver nitrate used (ml ) 29.3

B Titration for blank (ml ) if not distilled water 0

N Strength of silver nitrate (AG No. ) 0.1

D ml of sample 1

Result in ppm chlorides 103,869

For Sodium Chloride in (mg NaCl) 171,383

mg CL per litre ( same as ppm ) =

Note: A Measure the quantity of silver nitrate used

B If not using distilled water check cl of blank (or use zero for distilled water).

N Check the bottle for the strength of silver nitrate solution.

D For normal determination use 1ml of sample.

( A-B ) x N x 35450ml of sample (D)

Argentometic Method for Chloride DeterminationFormation Salinity Pressure Equivalent

Water Chloride ppm NaCl Gradient Mud WeightType mg/litre ( psi/ft ) ( ppg )

Fresh Water 0 0 0.433 8.34

6,098 10,062 0.435 8.38Brackish Water 12,287 20,274 0.438 8.43

24,921 41,120 0.444 8.55Seawater 33,000 54,450 0.448 8.63

37,912 62,555 0.451 8.68Saltwater 51,296 84,638 0.457 8.80

64,987 107,229 0.464 8.93

Formation Salinity Pressure Equivalent

Water Chloride ppm NaCl Gradient Mud Weight

Type mg/litre ( psi/ft ) ( ppg )65,287 107,724 0.465 8.95

79,065 130,457 0.470 9.05

93,507 154,287 0.477 9.18

Typical 108,375 178,819 0.484 9.32

Offshore 123,604 203,947 0.490 9.43

Gradients 139,320 229,878 0.497 9.57

155,440 256,476 0.504 9.70

171,905 283,643 0.511 9.84

188,895 311,677 0.518 9.97

Saturated Saltwater 191,600 316,140 0.519 9.99

TYPICAL SALINITY VALUES

TYPICAL SALINITY VALUES

PRESSURE DROP FORMULAS

For a flow through an orifice or choke the energy equation is:

For practical purposes V1 is very small as compared to V2

V2 Outlet Velocity =

V1 Inlet Velocity = 32000 x mm

D^2 X P1

the flow pipe.

Example ( Inlet Velocity ) Example ( Outlet Velocity )

Constant 32000 Upstream 1595 Enter values in Blue boxes onlyQ mm 63 2016000 D/stream 900 V2= 37.28

Dia ^2 16 28.00 X2 1390 V1= 28.00

Upstream 4500 72000 Sqrt 37.28 9 Resultant velocity

This calculation will show if our flow velocities are within 80ft/sec. This is an empirical value calculation indicating that beyond 80ft/sec

the gas starts expanding very rapidly and velocities increase due to the expansion.

( Based on Bernoulli's principle )

P1 is pressure energy ( Absolute pressure )

V1 is the velocity

Z1 is the elevation of the system from the ground.

D = diameter in inches of

P1+V1^2+Z1g = P2+V2^2Z2g---------------------------------------- 2

P1+V1^2+Z1g = P2+V2^2Z2g---------------------------------------- 2

2 X ( P1 - P2 ) 2 X ( P1 - P2 )

32000 x Q (mmscf)--------------------------------------- D^2 x P1

32000 x Q (mmscf)--------------------------------------- D^2 x P1

Enter values in Blue boxes only

This calculation will show if our flow velocities are within 80ft/sec. This is an empirical value calculation indicating that beyond 80ft/sec

Swages

Hose Pipe or Part N°

I.D. Dash Size Thread Coupling Die Pusher

3/16 -4 7/16 - 20 3903 - 03544 4540 - 303 4599 - FP011

1/4 -4 7/16 - 20 3903 - 04544 4540 - 304 4599 - FP012

3/16 -4 7/16 - 20 390H - 03544 4540 - H03 4599 - FP011

1/4 -4 7/16 - 20 390H - 04544 4540 - H04 4599 - FP012

SYNFLEX HOSE SWAGED COUPLINGSSynflex

Swages

SYNFLEX HOSE SWAGED COUPLINGSSynflex

document.xls 04/08/2023

Pressure Drop in (Edit the values in red)Straightening Vanes Steam: Enter Column E & H

Gas Liquid Steam GAS LIQUID

NOMINAL CV Flow Flow Flow SG SG P T PRESSURE PRESSURE

PIPE SIZE VALUE [SCFH] [GPM] [PPH] [GAS] [LIQUID] [PSI] [DEG F] DROP[psi] DROP[psi]

2 128 300000 3000 21548 0.500 0.56 180 200 14.52 307.623 304 300000 3000 21548 0.500 0.56 180 200 2.57 54.544 558 300000 3000 21548 0.500 0.56 180 200 0.76 16.196 1325 300000 3000 21548 0.500 0.56 180 200 0.14 2.878 2450 300000 3000 21548 0.500 0.56 180 200 0.04 0.84

10 3940 300000 3000 21548 0.500 0.56 180 200 0.02 0.3212 5850 300000 3000 21548 0.500 0.56 180 200 0.01 0.1514 8100 300000 3000 21548 0.500 0.56 180 200 0.00 0.0816 10750 300000 3000 21548 0.500 0.56 180 200 0.00 0.0418 13750 300000 3000 21548 0.500 0.56 180 200 0.00 0.0320 17200 300000 3000 21548 0.500 0.56 180 200 0.00 0.0222 22000 300000 3000 21548 0.500 0.56 180 200 0.00 0.0124 25400 300000 3000 21548 0.500 0.56 180 200 0.00 0.0126 27750 300000 3000 21548 0.500 0.56 180 200 0.00 0.0128 35400 300000 3000 21548 0.500 0.56 180 200 0.00 0.0030 41000 300000 3000 21548 0.500 0.56 180 200 0.00 0.0036 61000 300000 3000 21548 0.500 0.56 180 200 0.00 0.0042 85000 300000 3000 21548 0.500 0.56 180 200 0.00 0.00

Gas Flow: Enter Column C, F, H, & I

Liq Flow: Enter Column D & G


/PBA1..H23~LMR125~L10~QQDPAASAFQ

/FSR/FRLIQVANE.WQ1~/FSR/FRSATVANE.WQ1~

/FXY


Steam

PRESSURE

DROP[psi]

47.558.432.500.440.130.050.020.010.010.000.000.000.000.000.000.000.000.00

Flow Rate Conversions

FROM / TO LTRS / SEC GAL / MIN FT3 / SEC FT3 / MIN BBL /HOUR

LTRS / SEC 1 15.85 0.03532 2.119 22.66

GAL / MIN 0.06309 1 0.00223 0.1337 1.429

FT3 / SEC 28.32 448.8 1 60 641.1

FT3 / MIN 0.4719 7.481 0.01667 1 10.69

BBL /HOUR 0.04415 0.6997 0.00156 0.09359 1

BBL /DAY 0.00184 0.02917 650000 0.0039 0.04167

NOTE: CHANGE VALUES IN BLUE BOXES ONLY

Flow rate

Flow Rate Conversions

BBL /DAY

543.8

34.3

15400

256.5

24

1

Flow rate

Flow Calc.

GAS / OIL FLOW RATE THROUGH CHOKE

1800 psia Wellhead Pressure

184 °F Wellhead Temperature

90 64 ths Manifold Choke

100 scf/bbl Gas/Oil Ratio (Qo only)

89370 Mscf Gasrate (estimate)

71829 bbl Oilrate (estimate)

386.419.65706

1.40625

Flow

Gravity

OIL GRAVITY CONVERSION

0.816 Observed S.G42.0 Observed API80.0 Observed Temperature

0.824 S.G @ 60°F40.3 API @ 60°F

Shr Factor

ESTIMATE OF SHRINKAGE FACTOR

710 Sep. pressure (psig)136 Sep.Temperature (°f)

0.751 Observed Gas S.G52.0 Observed Oil API

110.0 Observed Temperature

0.8068 ( 1-Shr ) @ 60°F

0.77251.9

348.745368395621.223494859997

609.175398998981.2394554939628

Shrink

Twin Chokes

EFFECTIVE AREA OF TWIN CHOKES

80 64 ths Diameter of choke 140 64 ths Diameter of choke 2

89.4 64 ths Combined choke

1.250.625

Twin

Gas rates by Choke Coefficient

C = Constant 605.4A = Choke Size (Area in square ins)P1 = Upstream Pressure ( psig )

(C) * (A) * (P1) * (Cd) Cd = Constant 0.83mscf/d = ((T) * (Yg) * (Z)) ^0.5 T = Temperature Rankin

Yg = S.G of the GasZ = Constant 0.9

Enter choke size 45Enter downstream temperature in deg F 110

Enter Upstream pressure 3200Enter S.G of the gas 0.75

mscf/d 31988.47mmscf/d 31.988

Formula

45 C= 605.4 T= 5700.703125 A= 0.388438 Yg= 0.750.351563 P1= 3214.7 Z= 0.90.123596 Cd= 0.83 0.50.388438 627455.3 19.61505

Choke

Gas rates by Choke Coefficient

Choke Size (Area in square ins)Upstream Pressure ( psig )

31988.5


PRESSURE DROP FOR STRAINERS

LINE BODY ANSI MAWP LINE BODY D1/D2 Kexp Kcon Ktot J GPM S.G. VEL. BASKET BODY TOTAL KSIZE SIZE RATING I. D. I.D. FT/SEC PSI PSI PSI STRNR

2 4 150 285 2.067 4.026 0.513 0.542 0.368 0.910 0.0175 2550 0.85 243.87 884.65 309.18 1193.83 3.52300 740 2.067 4.026 0.513 0.542 0.368 0.910 0.0175 2550 0.85 243.87 884.65 309.18 1193.83 3.52600 1480 2.067 3.826 0.540 0.501 0.354 0.856 0.0175 2550 0.85 243.87 884.65 290.51 1175.16 3.46900 2220 1.936 3.624 0.534 0.511 0.357 0.868 0.0175 2550 0.85 277.99 1149.51 382.99 1532.50 3.47

2.5 6 150 285 2.469 6.065 0.407 0.696 0.417 1.113 0.0175 225 0.85 15.08 3.38 1.45 4.83 3.72 300 740 2.469 6.065 0.407 0.696 0.417 1.113 0.0175 225 0.85 15.08 3.38 1.45 4.83 3.72 600 1480 2.469 5.761 0.429 0.666 0.408 1.075 0.0175 225 0.85 15.08 3.38 1.40 4.78 3.68 900 2220 2.323 5.501 0.422 0.675 0.411 1.086 0.0175 225 0.85 17.04 4.32 1.80 6.12 3.693 6 150 285 3.068 6.065 0.506 0.554 0.372 0.926 0.0175 400 0.85 17.36 4.48 1.59 6.08 3.53

300 740 3.068 6.065 0.506 0.554 0.372 0.926 0.0175 400 0.85 17.36 4.48 1.59 6.08 3.53600 1480 3.013 5.761 0.523 0.528 0.363 0.891 0.0175 400 0.85 18.00 4.82 1.65 6.47 3.50900 2220 2.900 5.501 0.527 0.521 0.361 0.882 0.0175 400 0.85 19.43 5.62 1.90 7.52 3.49

4 8 150 285 4.026 7.981 0.504 0.556 0.373 0.929 0.0175 650 0.85 16.39 3.99 1.42 5.42 3.53300 740 4.026 7.981 0.504 0.556 0.373 0.929 0.0175 650 0.85 16.39 3.99 1.42 5.42 3.53600 1480 3.826 7.625 0.502 0.560 0.374 0.934 0.0175 650 0.85 18.14 4.90 1.76 6.65 3.54900 2220 3.624 7.187 0.504 0.556 0.373 0.929 0.0175 650 0.85 20.22 6.08 2.17 8.25 3.53

6 10 150 285 6.065 10.020 0.605 0.401 0.317 0.718 0.009 1250 0.85 13.89 1.47 0.79 2.27 2.06300 740 6.065 10.020 0.605 0.401 0.317 0.718 0.009 1250 0.85 13.89 1.47 0.79 2.27 2.06600 1480 5.761 9.562 0.602 0.406 0.319 0.724 0.009 1250 0.85 15.39 1.81 0.98 2.79 2.06900 2220 5.501 8.750 0.629 0.366 0.302 0.668 0.009 1250 0.85 16.88 2.18 1.09 3.27 2.01

8 12 150 285 7.981 12.000 0.665 0.311 0.279 0.590 0.022 2450 0.7 15.72 3.80 0.69 4.49 3.86300 740 7.981 12.000 0.665 0.311 0.279 0.590 0.022 2450 0.7 15.72 3.80 0.69 4.49 3.86600 1480 7.625 11.062 0.689 0.275 0.262 0.538 0.022 2450 0.7 17.22 4.57 0.75 5.32 3.81900 2220 7.187 10.500 0.684 0.282 0.266 0.548 0.022 2450 0.7 19.38 5.78 0.97 6.75 3.82

10 16 150 285 10.020 15.250 0.657 0.323 0.284 0.607 0.0105 5200 0.85 21.16 4.00 1.55 5.55 2.17300 740 10.020 15.000 0.668 0.307 0.277 0.584 0.0105 5200 0.85 21.16 4.00 1.49 5.49 2.15600 1480 9.562 13.935 0.686 0.280 0.265 0.545 0.0105 5200 0.85 23.24 4.82 1.68 6.50 2.11900 2220 8.750 13.124 0.667 0.309 0.278 0.586 0.0105 5200 0.85 27.75 6.87 2.58 9.45 2.15

12 18 150 285 12.000 17.250 0.696 0.266 0.258 0.524 0.0105 8000 0.85 22.70 4.60 1.54 6.14 2.09300 740 12.000 17.000 0.706 0.252 0.251 0.503 0.0105 8000 0.85 22.70 4.60 1.48 6.08 2.07600 1480 11.626 15.688 0.741 0.203 0.225 0.429 0.0105 8000 0.85 24.18 5.22 1.43 6.65 1.99900 2220 10.500 14.876 0.706 0.252 0.251 0.503 0.0105 8000 0.85 29.65 7.85 2.52 10.37 2.07

16 24 150 285 15.25 23.25 0.656 0.325 0.285 0.610 0.0076 12000 0.85 21.08 2.87 1.55 4.42 1.74300 740600 1480900 2220

20 30 150 285 19.25 29.25 0.658 0.321 0.283 0.605 0.0076 18000 0.85 19.85 2.54 1.36 3.91 1.74300 740600 1480900 2220

STRAINER MESH FACTOR

MESH SIZE J40x40x0.010 0.022020x20x0.016 0.0135

0.125"HL ON 0.188" CTRS 0.01754 x 4 X 0.063 0.00903 x 3 x 0.092 0.01052 x 2 x 0.105 0.0076

DRY GAS FLOW THRU POSITIVE CHOKEWhen critical conditions exist and specific gravity : G =0.7

555453525150 5049484746 48/64454443424140 403938 44/6437363534333231 40/6430 302928272625 36/642423222120 201918 32/64171615 28/6414131211 24/6410 10

98765 At 3750 psig4 on a 28/64 3 Gas rate = 15.521 Pressure Upstream of Choke x 1000, psig0### ### ### ### ### 5

GENERAL CACULATIONS

GAS VELOCITY V = (2122 x Bg x Q)/(D)^2

where :

Z = 1/Fpv T = Upstream temp. deg F + 460 Bg = 0.02833 x ((Z x T)/P)

P= Upstream pressure psia Q = Gas Q (mscf/d) D = Line ID"

Z = 0.973 T = 540 deg F P = 4000 psia

Q = 40.000 mscf/d D = 2.85 ins

V = 76.09 ft/sec.

GAS VOLUME (1) Q = 0.000471 x ((D)^2 x V)/Bg

where :

Z = 1/Fpv Bg = 0.02833 x ((Z x (T + 460) / P)

P= Upstream pressure psia T = Upstream temp. deg F

V = Gas velocity (ft/sec.) D = Line ID"

Fpv = 0.973 T = 160 deg F P = 2170 psia

D = 0.75 ins V = 76.09

Q = 2.423 mmscf/d

GAS VOLUME (2) Q = P x (D)^2 x 24

where :

P= Upstream pressure psia D= choke size in 64ths

P = 3000 psia D = 32 ins

Q = 1.800 mmscf/d

TWIN CHOKE FACTOR D = ¦((d1)^2 + (d2)^2)

where :

D = Actual orifice size d = Choke size (64th")

d1 = 46 64ths d2 = 46 64ths

D = 65 64th" 1.02 ins

OIL VOLUME Q = (P x (D)^1.89)/435 x (GOR/1000)^0.546

where :

P= Upstream pressure psig D = Choke size (64th")

P = 3000 psig GOR = 250 scf/bbl

D = 32 64ths BSW = 25.0 %

Q = 10282 bopd Water Q = 2571 bpd (Gas Q = ) 2.571 mmscfd

OIL S.G. TO API OIL API TO S.G.

S.G. = 0.946 deg API = 45.0 deg

API = 18.1 deg S.G. = 0.802 deg

CORRECTED S.G. @ 60°F

Observed SG = 0.6 Observed T° = 84 deg F

SG @ 60°F = 0.611 API @ 60°F = 100.0106

SHRINKAGE FACTOR (FROM TABLES)

S = 1/(((((0.02-(0.00000357 x (1.797/S.G. - 1.838) x P)) x (141.5/S.G. - 131.5) + 0.25)

/S.G.)^0.5 x ((1.797/S.G. - 1.838) x P) = 1.25 x T)^1.2 x 0.00012 = 0.9759)

where :

S.G. = Oil S.G. @ 60°F P = Separator pres. psig T = Oil temp. °F

S.G. @ 60°F = 0.946 Oil temp. = 124 deg F Sep. pres. = 130 psig

Shrinkage = 0.971

mmscfd

tankrates

Estimated Flow Returns - Based on Tank readings

0 10:00 1.5 11:00

For use on Well Test unit 1. ( For use with other calibration tanks the constant 0.4348 will need correcting in the cell F6 formula )

0 Enter the intial tank reading ( Use 0 for new rate )

3.4

10:00

11:00 Enter end time ( Diverted from tank ) hh:mm

Initial Tank Reading (bbls)

Start Time (hh:mm)

Final Tank Reading (bbls)

End Time (hh:mm)

Enter the final height in cm. ( Note: 1cm = 0.4348 bbls )

Enter the start time ( diverted to tank ) hh:mm

Tank returns

tankrates

Estimated Flow Returns - Based on Tank readings

35 1.48

( For use with other calibration tanks the constant 0.4348 will need correcting in the cell F6 formula )

Estimated Tank Rate

(bpd) day

Estimated Tank Rate (Bph) hour

Tank returns

bottomsup

180 0.1 30 240 04 : 00

flowrate ( bpd )

flowrate ( bpm )

tubing volume ( bbls )

time taken for bottoms up

(mins )

time taken for bottoms up

(hh : mm )

This routine estimates the time it will take for bottoms up based on tubing volume and current flowrate

bottomsup

total mins hours hh

240 4 0 00

04 1 012 023 034 045 056 067 078 089 09

10 1011 1112 1213 1314 1415 1516 1617 1718 1819 1920 2021 2122 2223 23

bottomsup

mins mm

0 0 00

00 1 012 023 034 045 056 067 078 089 09

10 1011 1112 1213 1314 1415 1516 1617 1718 1819 1920 2021 2122 2223 2324 2425 2526 2627 2728 2829 2930 3031 3132 3233 3334 3435 3536 3637 3738 3839 3940 4041 4142 4243 4344 44

bottomsup

45 4546 4647 4748 4849 4950 5051 5152 5253 5354 5455 5556 5657 5758 5859 59

ansiflanges

Service Flange NOMINAL PIPE SIZEPressure Bolting facing

Rating 1 2 3 4 6 8 10 12 14 16 18 20 24

Number 4 4 4 4 8 8 12 12 12 16 16 20 20

150# Diameter 1 1 BOLTS & RINGS

Length of 4 6 7 Flange

275 psi stud bolts RTJ 6

Ring Size R 15 22 29 36 43 48 52 56 59 64 68 72 76 2 1/16 5K 6.5 0.875

2 1/16 6.5K 6.5 0.875

2 1/16 10K 5.5 0.75

Service Flange NOMINAL PIPE SIZE 3 1/8 5K 7.75 1.125

Pressure Bolting facing 3 1/16 10K 7 1

Rating 1 2 3 4 6 8 10 12 14 16 18 20 24 4 1/16 10K 8.25 1.125

Number 4 8 8 8 12 12 16 16 20 20 24 24 24 5 1/8 5K 10.5 1.5

300# Diameter 1 5 1/8 10K 9 1.125

Length of 5 7 7 1/16 5K 11.25 1.375

720 psi stud bolts RTJ 5 7 9 7 1/16 6.5K 11.25 1.375

Ring Size R 16 23 31 37 45 49 53 57 61 65 69 73 77 7 1/16 10K 11.5 1.5

RX - 23 31 37 45 49 53 57 61 65 69 73 77

Service Flange NOMINAL PIPE SIZEPressure Bolting facing

Rating 1 2 3 4 6 8 10 12 14 16 18 20 24

Number 4 8 8 8 12 12 16 20 20 20 20 24 24

600# Diameter 1

Length of 5 10 13

1440 psi stud bolts RTJ 6 7 8 9 11

Ring Size R 16 23 31 37 45 49 53 57 61 65 69 73 77

RX - 23 31 37 45 49 53 57 61 65 69 73 77

1/25/8

5/85/8

3/43/4

7/87/8 1 1/8 1 1/8 1 1/4

1/16 RF 2 3/4 3 1/4 3 3/4 3 3/4 4 1/4 4 3/4 4 3/4 5 1/4 5 1/2 6 1/4 Bolt Length

Bolt Dia3 1/4 3 3/4 4 1/4 4 1/4 4 1/2 4 1/2 5 1/4 5 1/4 5 3/4 6 1/2 6 3/4 7 1/2

5/85/8

3/43/4

3/47/8 1 1/8 1 1/8 1 1/4 1 1/4 1 1/4 1 1/2

1/16 RF 3 1/4 3 1/2 4 1/4 4 1/2 5 1/2 6 1/4 6 3/4 7 1/2 7 3/4 8 1/4 9 1/4

3 3/4 4 1/4 5 1/4 5 3/4 6 1/4 7 1/2 7 3/4 8 1/4 8 1/2 10 1/4

5/85/8

3/47/8 1 1/8 1 1/4 11/4 1 3/8 1 1/2 1 5/8 1 5/8 1 7/8

1/16 RF 3 3/4 4 1/4 5 3/4 6 3/4 7 3/4 8 1/2 8 3/4 9 1/4 10 3/4 11 1/2

3 3/4 4 1/2 5 1/4 8 3/4 9 1/2 10 1/4 11 3/4 13 1/2

ANSI FLANGES - NUMBER and SIZE of STUDS and RING GASKETS

ansiflanges

BOLTS & RINGS

8 37

8 37

8 32

8 46

8 41

8 46

8 60

12 46

12 55

12 55

12 60

Number of

Spanner mm

Gas Estimate for Aramco Khuff Gas Well's.

3200 Wellhead Pressure

183 Wellhead Temp

48 Choke size ( 64ths )

0.75 S.G. ( Enter .7 for default )

0.9 Wet factor ( Compensates for fluids ) .7 default

34.63 Estimated Flow Rate ( mmscf/day )

2002 Schedule

Wednesday Changeout

January February MarchSun Mon Tue Wed Thu Fri Sat Sun Mon Tue Wed Thu Fri Sat Sun Mon Tue Wed Thu Fri Sat

1 2 3 4 5 1 2 1 2

6 7 8 9 10 11 12 3 4 5 6 7 8 9 3 4 5 6 7 8 9

13 14 15 16 17 18 19 10 11 12 13 14 15 16 10 11 12 13 14 15 16

20 21 22 23 24 25 26 17 18 19 20 21 22 23 17 18 19 20 21 22 23

27 28 29 30 31 24 25 26 27 28 24 25 26 27 28 29 30

31

April May JuneSun Mon Tue Wed Thu Fri Sat Sun Mon Tue Wed Thu Fri Sat Sun Mon Tue Wed Thu Fri Sat

1 2 3 4 5 6 1 2 3 4 1

7 8 9 10 11 12 13 5 6 7 8 9 10 11 2 3 4 5 6 7 8

14 15 16 17 18 19 20 12 13 14 15 16 17 18 9 10 11 12 13 14 15

21 22 23 24 25 26 27 19 20 21 22 23 24 25 16 17 18 19 20 21 22

28 29 30 26 27 28 29 30 31 23 24 25 26 27 28 29

30

July August SeptemberSun Mon Tue Wed Thu Fri Sat Sun Mon Tue Wed Thu Fri Sat Sun Mon Tue Wed Thu Fri Sat

1 2 3 4 5 6 1 2 3 1 2 3 4 5 6 7

7 8 9 10 11 12 13 4 5 6 7 8 9 10 8 9 10 11 12 13 14

14 15 16 17 18 19 20 11 12 13 14 15 16 17 15 16 17 18 19 20 21

21 22 23 24 25 26 27 18 19 20 21 22 23 24 22 23 24 25 26 27 28

28 29 30 31 25 26 27 28 29 30 31 29 30

October November DecemberSun Mon Tue Wed Thu Fri Sat Sun Mon Tue Wed Thu Fri Sat Sun Mon Tue Wed Thu Fri Sat

1 2 3 4 5 1 2 1 2 3 4 5 6 7

6 7 8 9 10 11 12 3 4 5 6 7 8 9 8 9 10 11 12 13 14

13 14 15 16 17 18 19 10 11 12 13 14 15 16 15 16 17 18 19 20 21

20 21 22 23 24 25 26 17 18 19 20 21 22 23 22 23 24 25 26 27 28

27 28 29 30 31 24 25 26 27 28 29 30 29 30 31

Gas Gradient

Gas Gradient CalculationNote: Please enter the values in red boxes and find the results in green boxes.

1- Using Reservoir Pressure, Reservoir Temperature and Gas Deviation factor

Gas Gradient = (0.01875x SGxP) / ZT 0.0896875 psi/ft

Where

SG= Gas gravity 0.7P= Reservoir Pressure 3731 psia

T= Reservoir Temperature 600 Deg R= Deg F+460

Z= Gas Deviation/Comp.Factor 0.910

Gas Static Bottom Hole Pressure Calculation at any depth

1- Using Well head Pressure, Average Temperature,Gas SG, depth and Average Gas Deviation factor

Pws= 3731 psia

Where

Pws= Static bottom Hole Pressure psia

Pwh= Well head Pressure 2500 psia

SG= Gas gravity 0.78D= Depth 13650 ft

* Tavg= Average Temperature 600 Deg R= Deg F+460

* Zavg= Gas Deviation/Comp. Factor 0.831

* Average of surface value and at specific depth value.

2- Approximated formula using well head Pressure and depth onlyThe pressure in static gas column increases approximately one fourth of a psi for every hundred psi well head pressure and for every hundred feet of depth.

Pws= Pwh + 0.25 x (Pwh/100)x(D/100) 3353 psia

Where

Pws= Static bottom Hole Pressure psia

Pwh= Well head Pressure 2500 psia

D= Depth 13650 ft

>>You can compare the results of 1 & 2>>

Pwh e (0.01875xSGxD) / ZavgTavg

Gas Gradient

Please enter the values in red boxes and find the results in green boxes.

1- Using Reservoir Pressure, Reservoir Temperature and Gas Deviation factor

Deg F+460

Gas Static Bottom Hole Pressure Calculation at any depth

1- Using Well head Pressure, Average Temperature,Gas SG, depth and Average Gas Deviation factor

Deg F+460

2- Approximated formula using well head Pressure and depth onlyThe pressure in static gas column increases approximately one fourth of a psi for every hundred psi well head pressure

document.xls

Input Output

42.8 Enter API Gravity 41.7 817.1 kg/m3

76 0.9918 Volume Correction Factor (K-fact)

Time 3:00 0.8171

Password:42.8 API Gravity at Observed Temperature Note: Oil Density (kg/m3) by 76.0 Observed Temperature PDO Unit -

811.02 RHOt Density at Temperature t ASTM D1250/19800.999793933 Hydrometer Correction

16.0 Delta T

810.85 RHOt Density corrected f/Hydrometer

341.0957 K0

0.0000 K1

0.375503450 Term 1

0.0004133821 Term 2

0.000000000 Term 3

0.000413400 Alpha

908.369000000 RHO60 Est. Kg/M3

0.006614400 Term 1

0.005291500 Term 2

0.000035000 Term 3

-0.006649400 Term 4

0.993373 VCF Volume Correction Factor

816.259 RHO 60

41.681 API60

Volume Correction Factor at Hydrometer Conditions

816.167000 RHO60

0.417923905 a(1)

0.000512057 a(2)

0.000000000 b(1)

0.000512100 a

0.008193600 a(1)

0.006554880 a(2)

0.000053710 a(3)

-0.008247310 a(4)

0.991786600 VCF Volume Correction Factor

API Gravity Correction to 60oF - Hydrometer

API Gravity at 60oF =

Enter Observed Temperature(oF)

SG Oil at 60oF

Correct API to 60oF

Saudi Refractometer Conversion Table.

15 Enter % reading from refractometer

150,000 Results in Sodium Chloride (mgNaCl)

81,522 Results in ppm Chlorides

Enter the % reading from the refractomter. Make sure the refrac has been zeroed before

use.

Bubble point for Oil

Well Name:Well Number: Enter

Oil Gravity 45GOR 300Gas Gravity 0.7Seperator Temp 110Seperator Press 500Reservoir Temp 440

GAS GS 0.8310

1553.3

0.018API 1.187Scf/Bbl ->m3/m3 = 53.47 23.93deg_F-> deg_C = 43 psia -> kPa = 3,447 deg_F -> deg_C = 227

( Bubble Point Press ) =

Bubble Point

Enter Oil Gravity, GOR, Seperator tempSeparator pressure, Reservoir Temp in box.Use 0.7 if gas gravity not known.

Shrinkage

Shrinkage factor @ 60 F by Katz Chart

Separator Press 10*API 15*API 20*API 25*API 30*API 35*API 40*API 45*API 50*API 55*APIPsig Kpag

20 138 0.999 0.998 0.997 0.997 0.996 0.996 0.996 0.995 0.994 0.993

40 276 0.998 0.997 0.995 0.994 0.993 0.992 0.991 0.989 0.988 0.985

60 414 0.997 0.996 0.993 0.991 0.99 0.988 0.986 0.983 0.982 0.978

80 552 0.995 0.994 0.991 0.989 0.987 0.984 0.981 0.977 0.973 0.97

100 690 0.994 0.992 0.989 0.986 0.984 0.98 0.976 0.972 0.968 0.963

120 827 0.994 0.99 0.988 0.983 0.981 0.976 0.971 0.967 0.962 0.957

140 965 0.993 0.988 0.986 0.981 0.978 0.973 0.967 0.962 0.957 0.951

160 1103 0.992 0.987 0.984 0.979 0.975 0.97 0.963 0.956 0.952 0.946

180 1241 0.991 0.986 0.982 0.977 0.972 0.967 0.959 0.952 0.947 0.941

200 1379 0.99 0.985 0.98 0.974 0.969 0.964 0.955 0.948 0.942 0.936

220 1517 0.989 0.983 0.979 0.971 0.967 0.96 0.951 0.944 0.938 0.931

240 1655 0.988 0.981 0.976 0.968 0.964 0.956 0.947 0.94 0.934 0.927

260 1792 0.987 0.98 0.974 0.966 0.961 0.952 0.944 0.936 0.93 0.923

280 1931 0.986 0.979 0.972 0.964 0.957 0.949 0.941 0.933 0.926 0.919

300 2069 0.986 0.978 0.97 0.962 0.955 0.946 0.938 0.93 0.912 0.915

320 2206 0.985 0.976 0.968 0.96 0.952 0.943 0.935 0.926 0.918 0.911

340 2344 0.984 0.975 0.966 0.958 0.95 0.94 0.932 0.922 0.914 0.907

360 2482 0.983 0.973 0.964 0.956 0.948 0.937 0.929 0.919 0.91 0.903

380 2620 0.982 0.972 0.963 0.954 0.946 0.935 0.926 0.916 0.907 0.899

400 2758 0.982 0.971 0.962 0.952 0.944 0.933 0.923 0.913 0.904 0.895

420 2896 0.981 0.97 0.96 0.95 0.942 0.931 0.92 0.91 0.901 0.892

440 3034 0.98 0.969 0.958 0.948 0.94 0.929 0.918 0.907 0.898 0.889

460 3172 0.979 0.968 0.958 0.947 0.938 0.927 0.916 0.905 0.895 0.886

480 3310 0.978 0.967 0.957 0.946 0.936 0.925 0.914 0.903 0.892 0.883

500 3447 0.978 0.967 0.956 0.945 0.934 0.923 0.912 0.901 0.89 0.88

520 3585 0.977 0.966 0.954 0.943 0.932 0.921 0.91 0.898 0.887 0.876

540 3723 0.976 0.965 0.953 0.941 0.93 0.919 0.908 0.895 0.884 0.873

560 3861 0.975 0.964 0.952 0.94 0.928 0.917 0.906 0.893 0.881 0.87

580 3999 0.974 0.963 0.951 0.939 0.927 0.916 0.904 0.891 0.878 0.867

600 4137 0.974 0.962 0.95 0.938 0.926 0.915 0.902 0.889 0.876 0.864

650 4448 0.972 0.961 0.949 0.934 0.923 0.913 0.899 0.884 0.872 0.86

700 4826 0.97 0.958 0.945 0.932 0.919 0.906 0.892 0.878 0.865 0.861

750 5171 0.968 0.956 0.943 0.93 0.917 0.904 0.889 0.872 0.859 0.844

800 5516 0.967 0.954 0.939 0.924 0.912 0.901 0.885 0.869 0.855 0.839

850 5860 0.964 0.951 0.937 0.922 0.91 0.895 0.882 0.864 0.848 0.831

900 6205 0.963 0.95 0.935 0.92 0.906 0.892 0.877 0.86 0.843 0.825

950 6550 0.961 0.948 0.933 0.916 0.903 0.89 0.873 0.854 0.837 0.819

1000 6895 0.96 0.945 0.929 0.912 0.898 0.883 0.866 0.848 0.83 0.81

1050 7240 0.958 0.942 0.926 0.91 0.896 0.881 0.862 0.842 0.824 0.804

1100 7584 0.957 0.94 0.923 0.906 0.892 0.877 0.858 0.837 0.817 0.796

1150 7929 0.956 0.939 0.922 0.905 0.887 0.87 0.851 0.831 0.81 0.788

1200 8274 0.954 0.936 0.918 0.901 0.883 0.864 0.846 0.826 0.804 0.781

1250 8619 0.953 0.935 0.917 0.9 0.882 0.863 0.842 0.819 0.796 0.772

1300 8963 0.952 0.933 0.914 0.895 0.876 0.857 0.835 0.811 0.788 0.764

Shrinkage

1350 9308 0.951 0.932 0.912 0.893 0.872 0.852 0.83 0.806 0.782 0.756

Shrinkage

Shrinkage factor @ 60 F by Katz Chart

60*API

0.992

0.984

0.976

0.96

0.958

0.952

0.946

0.94

0.935

0.93

0.925

0.92

0.915

0.91

0.906

0.902

0.898

0.894

0.89

0.866

0.882

0.879

0.876

0.873

0.87

0.866

0.862

0.859

0.858

0.852

0.847

0.837

0.83

0.823

0.814

0.807

0.801

0.791

0.784

0.775

0.765

0.758

0.747

0.739

Shrinkage

0.73

Vessel Cal

FORMULA IN TERMS OF INSIDE DIMENSIONS:

SHELL:

PR WHERE:t = -------------- + C.A.

(SE - 0.6P) P = DESIGN PRESSURE OR MAWP PSIS = ALLOWABLE STRESS OF MATERIAL 17,500 PSIE = JOINT EFFICIENCY 1R = INSIDE RADIUS INCHESD = INSIDE DIAMETER INCHESt = WALL THICKNESS INCHES

C.A. = CORROSION ALLOWANCE 0.125 in.

P R S E C.A. t (in.) t (mm)

1440 24 17,500 1 0.125 2.202422 55.94153

50 60 17,500 1 0.125 0.296723 7.536763

2:1 ELLIPTICAL HEAD

PD WHERE:t = -------------- + C.A.

(2SE - 0.2P) P = DESIGN PRESSURE OR MAWP PSIS = ALLOWABLE STRESS OF MATERIAL 17,500 PSIE = JOINT EFFICIENCY 1R = INSIDE RADIUS INCHESD = INSIDE DIAMETER INCHESt = WALL THICKNESS INCHES

C.A. = CORROSION ALLOWANCE 0.125 in.

P D S E C.A. t (in.) t (mm)

1440 42 17,500 1 0.125 1.867337 47.43036

50 120 17,500 1 0.125 0.296478 7.53053

PRESSURE VESSEL CALCULATION FOR MINIMUM ALLOWABLE WALL FOR ASME VESSELS

NOT TO BE USED FOR SEPARATOR SERIAL NUMBERS U16303, U16304, U16305

ORIGINALLY FABRICATED TO BS1515 SPECIFICATION

WARNING: VALUES IN COLUMNS C THROUGH E ARE CONSTANTSCOLUMNS F AND G ARE CALCULATED

ONLY COLUMNS A & B SHOULD BE CHANGED TO SUIT THE PARTICULAR VESSEL

CALCULATIONS ARE VALID FOR VESSELS FABRICATED FROM SA 285 GRADE C PLATE (NATCO 50 PSI TANKS) AND ALSO FOR ASTM 516 GRADE 70 PLATE (84" X 14' - 50 PSI TANKS AND SEPARATOR'S BUILT TO ASME

CURRENTLY WITHIN HALLIBURTON MIDDLE EAST TTTCP INVENTORY 24/02/97.

Vessel Cal

Pipe Cal

HALLIBURTON CERTIFICATION TABLE FOR PIPE WALL THICKNESS

Serial # Description Service Location Customer

Equip Code Loc Code Seq # D P S Y E C.A. tm tm3.50 600.00 20000.00 0.4000 1.0000 0.0625 0.115 2.9133.50 2000.00 20000.00 0.4000 1.0000 0.0625 0.234 5.9453.50 5000.00 20000.00 0.4000 1.0000 0.0625 0.479 12.1713.50 10000.00 20000.00 0.4000 1.0000 0.0625 0.858 21.7924.50 600.00 20000.00 0.4000 1.0000 0.0625 0.130 3.2923.50 2000.00 31667.00 0.4000 1.0000 0.0625 0.172 4.3603.50 5000.00 31667.00 0.4000 1.0000 0.0625 0.330 8.3913.50 10000.00 31667.00 0.4000 1.0000 0.0625 0.582 14.790

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

TO CALCULATE REQUIRED WALL THICKNESS, ENTER CORRECT OD AND PRESSURE RATING. USE 20,000 ALLOWABLE STRESS FOR A106 B. USE 31667 AS ALLOWABLE STRESS FOR 4130 FROM -20 TO 100 F.

MINIMUM WALL REQUIRED WILL BE CALCULATED IN COLUMNS 'N' & 'O'.

Nominal Size

LengthFeet

ODINCH

PressurePSI

AllowableStress

TempCoefficient

Weld QualityFactor

CorrosionAllowance

MinWallinch

Min. Wallmm

Point A1996

Point B1996

Point C1996

Test Press.1996

Insp. Date1996

ThicknessReport #

MPI REPORT

#

STRESSREPORT

#

X-RAYREPORT

#

INSPECTION PROCEDURES:1. VERIFY BAND STAMPED WITH SERIAL NUMBER, SERVICE AND PRESSURE RATING 2. VERIFY OUTSIDE DIAMETER3. MEASURE EXISTING WALL THICKNESS POINT A - THREAD END POINT B - CENTER POINT POINT C - WING END 4. REPORT READINGS BELOW MINIMUM TO ENGINNERING FOR FURTHER EVALUATION NOTE: MINIMUM VALUE CONTAINED IN TABLE IS CONSERVATIVE. PIPE MAY BE SUITABLE FOR CONTINUED SERVICE BASED ON DETAILED EVALUATION5. PRESSURE TEST TO MAWP6. STAMP ID BAND WITH NEW DATE, ONLY MONTH/YEAR REQUIRED ie 02/96 FOR FEB 19967. ENSURE COLOUR CODE AS PER QP 1433 IS IN PLACE - 2K BLUE 5K GOLD 10K YELLOW 8. CONTACT ENGINEERING ON ANY DISCREPANCIES OR QUESTIONS.

Recommended Flange Bolt Torque

Equations:

Where:

________ 1_____________in inches or millimeters.

= stress in stud.

Recommended Torques in ft/lbf for Flange Bolting

1 2 3 4 5 6 7 8 9 10 11

Bolt stress = 40 ksi Bolt stress = 52.5 ksi Bolt stress = 47.5 ksiStud ThreadsDiameter per in Tension Torque Torque Tension Torque Torque Tension Torque Torque

D N F f = 0.07 f = 0.13 F f = 0.07 f = 0.13 F f = 0.07 f = 0.13( in ) ( l/in ) ( lbf ) ( ft-lbf ) ( ft-lbf ) ( lbf ) ( ft-lbf ) ( ft-lbf ) ( lbf ) ( ft-lbf ) ( ft-lbf )

0.500 13 5,676 27 45 7450 35 590.625 11 19,040 52 88 11,865 68 1150.750 10 13,378 90 153 17,559 118 2000.875 9 18,469 143 243 24,241 188 319

1.000 8 24,230 213 361 31,802 279 4741.125 8 31,618 305 523 41,499 401 6861.250 8 39,988 421 726 52,484 553 9531.375 8 49,340 563 976 64,759 739 12811.500 8 59,674 733 1278 78,322 962 16771.625 8 70,989 934 1635 93,173 1226 21461.750 8 83,286 1169 2054 109,313 1534 26961.875 8 96,565 1440 2539 126,741 1890 33322.000 8 110,825 1750 3094 145,458 2297 40612.250 8 142,292 2496 4436 186,758 3276 58222.500 8 177,685 3429 6118 233,212 4500 8030

2.625 8 233,765 4716 84302.750 8 257,694 5424 97123.000 8 309,050 7047 126543.250 8 365,070 8965 161363.750 8 491,099 13782 249053.875 8 525,521 15208 27506

As = stress area, in square inches or square millimeters.D = thread major diameter, in inches or millimeters.E = pitch diameter of thread, in inches or millimeters.F = force per stud, lbf or newtons.H = hex size (nut) = 1.5 D + 0.125 inches ( 3.175 mm ).K = nut internal chamfer = 0.125 inches ( 3.175 mm ).

P = thread pitch = Number of threads per unit length

S = secant 30O = 1.1547T = torque.

Studs with Sy = 80 ksi Studs with Sy = 105 ksi Studs with Sy = 95 ksi

As = D – (0.9743 x P) 2

4

4.000 8 561,108 16730 30282

The torque values shown in these tables have beenshown to be acceptable values for use in API type 6B and 6BX flanges in some services. The user should refer to API 6AF. TR 6AFI, and TR 6AF2 for data on the effects of bolt preload stress and other factors on flange performance. It should be recognized that applied torque to a nut is only one of several ways to approximate the tension and stress in a fastener.

Recommendation for Specific FlangesThe following flanges should not be made up beyond40,000 psi ( 275 MP'a ) bolt stress due to potentially highflange stresses.

13 5/8 in. ( 346 mm) - 2000 psi ( 13.8 MP'a )16 3/4 in. ( 425 mm) - 2000 psi ( 13.8 MP'a )

21 1/4 in. ( 540 mm) - 2000 psi ( 13.8 MP'a )13 5/8 in. ( 346 mm) - 3000 psi ( 20.7 MP'a )

SAP Trip Number(s):

HALLIBURTON EXPENSE REPORT Page 1 of

Name (Last, First Middle Initial) Telephone Number ( Home ) Expenses Period from Thru Personnel Number ( SAP Emp # ) Check if appropriate:

Relocation Trip

Date CITY/ TYPE OF Description or further details Name/Title/Affiliation of all guests; Employee Employee Employee Enter- ChargeM/D/Y LOCATION EXPENSE Purpose, Discussion & length of Currency Meals Lodging Transport- tainment Other PERSONAL CAR Code

discussion for Entertainment ation Miles Rate Amount

Subtotals from continuation sheet 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Totals 0.00 0.00 0.00 0.00 0.00 0.00 0.00

TOTAL EXPENSE FOR PERIOD

$0.00 LESS: COMPANY ISSUED ADVANCE/S

LESS: T&E CARD CHARGES

$0.00 BALANCE DUE:

$0.00

Certification: I certify that this statement represents the actual and necessary business expenses

incurred by me while engaged in company business.Employee Signature Date: Approval Date:

10791 A-SAP

Personal Check Submitted Separately

Employee Company

YES NO

Krebbs Desander Velocity Estimation

WHP Gas Rate Flow Velocity Desander Velocity

3000 50.35 33.567 100.70psia MMscf/day ft/sec ft/sec

20684Kpa

velocity across desander.Enter the flowing WHP and Gas Rate for an estimated flow

110

8

Calculate length of Wire Cable for Tie Back

B c ?

aA

Height

Angle bC Length

Enter King post height ( ft ) 20

Enter length to tie point on boom ( ft ) 55

Enter required angle in Degrees 75( From King post )

Length of wire cable required ( c ) 53.44( Less length of turn buckles )

a^2 = 400b^2 = 3025

result 3425minus

2*axb = 2200

*cos C 0.258819

resultc40*c42 569.4019

c38-c45 2855.598

Square R 53.4378

Gas Downhole Pressures

14000

0.831

2500

0.7 Enter specific gravity of the gas ( use 0.7 for default )

580

3660.25

Pws = Pwh e ( 0.01875 x sg x depth ) / ZavgTavg

Enter depth to be calculated ( ft )

Gas Deviation / Compensation factor. Zavg

Enter Wellhead pressure ( psia )

Average temperature ( Deg F + 460 ) Tavg

Calculated bottom hole pressure. ( psia )

Gas Gal

pcf

Calculate Downhole hydrostatic for fluid

2.5

0.052 Multiplication factor ( fixed )

14000

1820.00

75

9940

144 Division factor

5177.08

Enter mud weight ( in lbs/gal )

Enter depth ( ft )


Enter mud weight ( in pcf )

Enter depth ( ft )


Gal

pcf

MUD PUMPS

Strokes per/min 30 54 54 54

Mud Pump # 1 2 3 4

Diameter ( inches ) 6.25 6.25 6.25 6.25

Length ( inches ) 12 12 12 12

Percent % 96% 96% 96% 96%

Constants 0.000243 0.052 42 1029.4

Pump Output 0.10935 0.10935 0.10935 0.10935

G.P.STK 4.5927 4.5927 4.5927 4.5927

Strokes per/bbl 9.1449 9.1449 9.1449 9.1449

GPM 137.78 248.01 248.01 248.01

BPM 3.2805 5.9049 5.9049 5.9049

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