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By:Stephen
Main Testing menu
Tools & Testing Dept - Saudi Arabia
Ver 3.0
Main Testing menu
Press
Page 3
Psig Bar Kpa atms inH2O ftH2O inHg
1 1 1 1 1 1 1Psig 1 14.50326 0.145033 14.69508 0.036088 0.433 0.491159Bar 0.1 1 0.01 1.013226 0.002488 0.0299 0.033865Kpa 6.9 100 1 101.3226 0.248827 2.986 3.386542
atms 0.06805 0.986947 0.009869 1 0.002456 0.029 0.033423inH2O 27.7 401.8854 4.018854 407.2006 1 12.00 13.61002ftH2O 2.31 33.49045 0.334905 33.93338 0.083333 1.00 1.134168inHg 2.0 29.52864 0.295286 29.91918 0.073475 0.882 1
mmHg 51.7 750.0276 7.500276 759.9471 1.866272 22.40 25.4Kgs/cm^2 0.070312 1.019753 0.010198 1.03324 0.002537 0.0304 0.034534
PRESSURE CONVERSIONSPRESSURE CONVERSIONSConversions
Press
Page 4
mmHg Kgs/cm^2
1 10.019337 14.2220.001333 0.980630.133328 98.0630.001316 0.967830.535828 394.100.044652 32.84172
0.03937 28.9571 735.4989
0.00136 1.00000
PRESSURE CONVERSIONSPRESSURE CONVERSIONSConversions
Vol
Page 5
Litres US Gallons Barrels ins^3 ft^3 cm^3 m^3
1 1 1 1 1 1 1Litres 1 3.7854008 158.9868 0.016387 28.31674 0.001 1000
US Gallons 0.26417 1.00000 42.00000 0.00433 7.48051 0.00026 264.17Barrels 0.00629 0.0238095 1 0.000103 0.178107 6.29E-06 6.2898
in^3 61.024 231.000 9702.0 1.000 1728.000 0.061 61024.0ft^3 0.03531 0.13368 5.61459 0.00058 1.00000 0.00004 35.31
cm^3 1000 3785.4008 158986.8 16.387 28316.74 1 1000000m^3 0.001 0.0037854 0.158987 1.639E-05 0.028317 0.000001 1
VOLUME CONVERSIONSVOLUME CONVERSIONSVolumes
Vol
Page 6
Volumes
Temp
Page 7
Fahrenheit Celsius Kelvin Rankin1 1 1 1
Fahrenheit 1 33.8 -458.2 -459Celsius -17.22 1.00 -272.33 -272.78Kelvin 256.11 274.33 1 0.55
Rankin 461.00 493.80 1.81 1.00
TEMPERATURE CONVERSIONSTEMPERATURE CONVERSIONSTemperature
Temp
Page 8
Lengths
Page 9
Inches Feet Yards Miles mm cm m1 1 1 1 1 1 1
Inches 1 12 36 63360 0.03937 0.393701 39.37Feet 0.0833 1.0000 3.0000 5280.0 0.003 0.033 3.281
Yards 0.028 0.333 1.000 1760.00 0.001 0.011 1.094Miles 0.000 0.000 0.001 1.000 0.000 0.000 0.001
mm 25.4 304.8 914.4 1609344 1.0 10.0 1000.0cm 2.54 30.48 91.44 160934 0.10 1.00 100.00
m 0.0254 0.3048 0.9144 1609.344 0.001 0.01 1km 0.00003 0.00030 0.00091 1.60934 0.00000 0.00001 0.00100
LENGTH CONVERSIONSLENGTH CONVERSIONSLengths
Lengths
Page 10
km1
39370.0793280.8
1093.610.621
1000000100000
10001.00000
Lengths
Rates
Page 11
bbl/day bbl/min gall/min m^3/day m^3/min ltr/min1 1 1 1 1 1
bbl/day 1 1440 34 6 9057 9bbl/min 0.00 1.00 0.02 0.00 6.29 0.01gall/min 0.0 42.0 1.0 0.2 264.2 0.3m^3/day 0.2 228.9 5.5 1.0 1440.0 1.4m^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
RATE CONVERSIONSRATE CONVERSIONSRates
Rates
Page 12
Rates
Densities
Page 13
°API S.G. ppg lb/ft^3 g/cc psi/ft bar/m1 1 1 1 1 1 1
°API <10° 10.0 >60° >60° 10.0 <10° <10°S.G. 1.068 1.000 0.120 0.016 1.000 2.309 10.209ppg 8.90 8.34 1.00 0.13 8.34 19.25 85.11
lb/ft^3 66.60 62.36 7.48 1.00 62.36 144.02 636.65g/cc 1.068 1.000 0.120 0.016 1.000 2.309 10.209
psi/ft 0.462 0.433 0.052 0.007 0.433 1.000 4.421bar/m 0.104603 0.09795 0.011749 0.001571 0.09795 0.226212 1
DENSITY CONVERSIONSDENSITY CONVERSIONSDensities
Densities
Page 14
Densities
Gas
Page 15
Choke Size (64ths) 64 Choke Size (64ths) 64Choke Coefficient 479.09 Choke Coefficient 479.09
Upstream Pressure (Psig) 2980 Upstream Pressure (Psig) 3000Downstream Temperature (deg f) 130
Gas Gravity (Air =1) 0.700
GAS RATE (Mscfd) 70599 GAS RATE (Mscfd) 80240
This routine estimates the Gas flowrate through a Fixed choke when CRITICAL FLOW exists
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
Page 16
This routine estimates the Gas flowrate through a Fixed choke when CRITICAL FLOW exists
CRITICAL FLOW - When the Downstream Pressure is less than half of the Upstream Pressure
Gas flow
Oil
Page 17
Upstream Pressure (psig) 4000Choke Size (64ths) 32
GOR (scf/bbl) 200
OILRATE (bpd) 15486 OILRATE (bpd)
This routine estimates the Oil flowrate through a Fixed choke using both GILBERT's and ROS's multi-phase flow equations
GILBERT EQUATION
P * ( C^1.89) Qo = 435 * (( G/1000) ^ 0.546)
ROS EQUATION
( P + 14.73 ) * ( C ^ 2) Qo = 17.4 * ( G ^ 0.5 )
P = Upstream Pressure (psig) C = Choke size (64ths) G = GOR (scf/bbl)
Oil rate
Oil
Page 18
16707
This routine estimates the Oil flowrate through a Fixed choke using both GILBERT's and ROS's multi-phase flow equations
ROS EQUATION
( P + 14.73 ) * ( C ^ 2) Qo = 17.4 * ( G ^ 0.5 )
Oil rate
Choke Nipple Gas Rate Calculations
Choke Size Co-efficient WHP WHT Gas Gravity Gas Rate Choke Size Co-efficient WHP WHT Gas Gravity Gas Rate(64ths) psig °F Air = 1 mscf/d (64ths) psig °F Air = 1 mscf/d
2/64 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 0.600 1467.50 128/64 2035.61217/64 30.006 2000 120.0 0.700 3000.24 42 198.894 4000 140.0 0.700 38962.7118/64 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
Page 20
Separator pressure (psig) 20Oil line temperature (°f) 136
Gas gravity (Air =1) 0.751Oil API gravity @ 60°f 48.3
GOR 2 6 GOR 2 6
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
Page 21
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
Page 22
800.90763739377 0.9996504202 800.6277 0.00053###### 0 0 1### 430.0425143831458 0.112 0.993588 0.97421###
OBSERVED API 45.0
HYDROMETER TEMPERATURE 87
OIL LINE TEMPERATURE (deg f) 112
OIL API GRAVITY @ 60°f 42.5
K FACTOR 0.9738
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 METER GPM M3/DAY BBLS/DAY
SIZE
3/8 x 1(3) .3-3 1.6-16 10 to 100
1/2 x 1(3) .75-7.5 4 to 40 25 to 250
3/4 x 1(3) 2 to15 11 to 80 68 to 515
7/8 x 1(3) 3 to 30 16 to 160 100 to 1,000
1 x 1 5 to 50 27 to 270 170 to 1,700
1 x 2 5 to 50 27 to 270 170 to 1,700
1-1/2 x 2 15 to180 80 to 1,000 515 to 6,000
2 40 to 400 210 to 2,100 1,300 to 13,000
3 60 to 600 335 to 3,300 2,100 to 21,000
4 100 to1,200 540 to 6,500 3,400 to 41,000
6 200 to 2,500 1,100 to 14,000 6,800 to 86,000
8 350 to 3,500 1,900 to 19,000 12,000 to 120,000
Specifications
NOMINAL MAX
FACTOR FREQUENCY(PULSES/SEC)
22,000 (5,812) 1,100
14,500 (3,830) 1,815
2,900 (766) 725
2,300 (608) 1,150
925 (244) 771
925 (244) 771
325 (86.0) 975
55 (14.5) 365
57 (15.2) 570
30 (7.9) 600
7 (1.8) 290
3 (.8) 175
PULSES/GAL (PULSES/dm3)
Turbine
Page 25
HALLIBURTON TURBINE METERS
METER
1.5" OIL 2233 93786 937.9 0.922" 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
Page 26
Meters
3phase
Page 27
3 Phase Electrical current calculations
440 1200 0.875 1800 12597
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
Page 28
3Phase
DVM
Page 29
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
Page 30
Raw Voltage.
Meters
Page 31
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
Page 32
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
Page 33
Calculation interval (mins) 15 Gas meter run size (ins)Observed API gravity 53 Orifice plate size (ins)
Observed hydrometer temp (deg f) 110 Separator pressure (psig)Current meter reading (bbls) 7.1 Differential pressure (inH2O)
Previous meter reading (bbls) 0 Gas gravity (Air=1)Oil line temperature (deg f) 136 Gas line temperature (deg f)
Base Sediment & Water (BS&W) (%) 1.4Meter Factor 0.853
Shrinkage Factor 1
Oil Rate (bpd) 549.99 Gas Rate (mscfd)
GOR (scf/bbl) OGR (bbl/mmscf)
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 oil flowrate ( Qo ) Vo / Time to produce the volume Vo
Calc Rates
Calcs
Page 34
GAS FLOWRATE FACTORS
Sqrt (hw*Pf) 0.00Fpv 1.0000 Supercompressibility factor
Fb #DIV/0! Basic Orifice factorFg #DIV/0! Specific gravity factorFtf 1.06322 Flowing temperature factorY2 #DIV/0! 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 #DIV/0!C2 #DIV/0!
C #DIV/0!
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
Page 35
#DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0! #DIV/0!14.73 0 #DIV/0! 1.063219 1 #DIV/0! #DIV/0! #DIV/0!
766.1799 0.999346 765.6785 0.000582 0.029091 0.023273 0.000677 -0.0297680.047706 0.136 0.987705 0.960118 0.959391 96 0.986 7.1
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
Calc Rates
Calcs
Page 36
Expansion factor for downstream pressure tap
Value for gasrate in scfd (14.73psia @ 60°f)
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
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
Page 37
#DIV/0! #DIV/0! #DIV/0! #DIV/0!#DIV/0! #DIV/0! #DIV/0!
0.970671 788.8136 47.70.853 5.729017 549.9856
Tankvol
Page 38
RECTANGULAR TANK HORIZONTALHeight of tank (ins) 14 CYLINDRICAL TANKLength of tank (ins) 26 Diameter of vessel (ins) 48
Width of tank (ins) 12 Length of vessel (ft) 10Estimated Total Volume (bbls) 0.5 Estimated Total Volume (bbls) 22.4Estimated Total Volume (galls) 19 Estimated Total Volume (galls) 940
Height of fuid level in tank (ins) Height of fuid level in tank (ins) 14Estimated Tank Volume (bbls) 0.0 Estimated Tank Volume (bbls) 5.4Estimated Total Volume (galls) 0 Estimated Total Volume (galls) 227Weight of fluid in tank (ppg)
Tare weight of tank (tons)Max fluid weight (tons)
Weight of tank + fluid (tons)Max deck loading (lb/ft)
This routine estimates the total volume of a rectangular and a horizontal cylindrical tank and the contents at any given fluid level in that vessel. It also estimates the maximum weight
and deck loading of a rectangular tank
Volumes
Tankvol
Page 39
Height (ins) - H 48 H/h
Length (ft) - L 10 0.2916666667Total Volume (bbls) - V 22.4 fraction of H
Fluid level (ins) - h 14 0.29fraction of V
Volume in tank (bbls) 5.4 0.2407
Volumes
Tankvol
Page 40
Fraction Value
0.01 0.00170.02 0.00470.03 0.00870.04 0.01340.05 0.01870.06 0.02450.07 0.03080.08 0.03750.09 0.04460.10 0.05200.11 0.05990.12 0.06800.13 0.07640.14 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 0.25520.31 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 0.449
Tankvol
Page 41
0.47 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 0.89670.85 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
Page 42
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
Pipesched
Page 43
Schedule 40Standard Wall
Schedule 80Extra Strong
Wall
Prefixes
Page 44
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
Page 45
Separator capacity (bbls) 130
Separator fluid level (%) 40
Flowrate (bpd) 180
Retention Time ( mm:ss ) 416:00
This routine estimates the retention time of a separator
Retention
Retention
Page 46
416.00
416
0
00
Retention
Dosage
Page 47
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 ) 3800
CHEMICAL INJECTION RATE
ANTIFOAM 0.4 cc / min
DEMULSIFIER 4 cc / min
SCALE INHIBITOR 13 cc / min
WELL TEST CHEMICALSTROS - TR OIL SERVICES ( 01224 - 884239 )
WELL TEST CHEMICALSTROS - TR OIL SERVICES ( 01224 - 884239 )
Dosage
Dosage
Page 48
Dosage
Chokes
Page 49
Choke Decimal Metricsize equivalent equivalent
( 64ths ) (ins) mm24
Choke size (64ths) 24
Decimal (ins) 0.375
Metric (mm) 9.52
CHOKE SIZE CONVERSIONSCHOKE SIZE CONVERSIONSChokes
Symbols
Page 50
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
Page 51
STANDARD OILFIELD SYMBOLS AND UNITSSTANDARD OILFIELD SYMBOLS AND UNITSSy
Meter Factor Calibration Data Sheet
DATE 24-Dec-98 METER SIZE 1.5 inch
TIME 0:00
TEST NUMBER 2 TANK NUMBER 1
API @ 60 F 48 TANK FACTOR 0.43478
TANK TEMPERATURE F 90 METER TEMPERATURE F 90
INITIAL TANK (reading cm ) 12 INITIAL METER (bbls ) 10
FINAL TANK (reading cm ) 24 FINAL METER (bbls ) 20
TANK INCREASE ( bbls ) 5.22 METER INCREASE (bbls) 10.00
K FACTOR 0.9822 K FACTOR 0.9917
TANK VOLUME INCREASE 5.12 METER VOLUME INCREASE 9.92
CORRECTION FACTOR (Cf) 0.517
TANK CONVERSION FACTORS
Tank Number 1 : 1 cm = 0.43478 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.
Note: Do not input in yellow shaded cells.
Meter Factor Calibration Data Sheet
Meter Calibration should be performed at least once per 12 hour flow period and following a choke /rate change.
Argentometic Method for Chloride Determination
A Quantity of silver nitrate used (ml ) 7
B Titration for blank (ml ) if not distilled water 0
N Strength of silver nitrate (AG No. ) 0.28
D ml of sample 0.5
Result in ppm chlorides 138,964
For Sodium Chloride in (mg NaCl) 229,291
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 WeightType 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 6000 Enter values in Blue boxes onlyQ mm 50 1600000 D/stream 500 V2= 104.88
Dia ^2 9 30.13 X2 11000 V1= 30.13
Upstream 5900 53100 Sqrt 104.88 75 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
Page 58
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
Page 59
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
document.xls 04/08/2023
/PBA1..H23~LMR125~L10~QQDPAASAFQ
/FSR/FRLIQVANE.WQ1~/FSR/FRSATVANE.WQ1~
/FXY
document.xls 04/08/2023
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 BBL /DAY
LTRS / SEC 1 15.85 0.03532 2.119 22.66 543.8
GAL / MIN 0.06309 1 0.00223 0.1337 1.429 34.3
FT3 / SEC 28.32 448.8 1 60 641.1 15400
FT3 / MIN 0.4719 7.481 0.01667 1 10.69 256.5
BBL /HOUR 0.04415 0.6997 0.00156 0.09359 1 24
BBL /DAY 0.00184 0.02917 650000 0.0039 0.04167 1
NOTE: CHANGE VALUES IN BLUE BOXES ONLY
Flow Calc.
Page 64
GAS / OIL FLOW RATE THROUGH CHOKE
3000 psia Wellhead Pressure
200 °F Wellhead Temperature
64 64 ths Manifold Choke
100 scf/bbl Gas/Oil Ratio (Qo only)
72225 Mscf Gasrate (estimate)
62851 bbl Oilrate (estimate)
39619.89975
1
Flow
Gravity
Page 65
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
Page 66
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
Page 67
EFFECTIVE AREA OF TWIN CHOKES
46 64 ths Diameter of choke 146 64 ths Diameter of choke 2
65.1 64 ths Combined choke
0.718750.71875
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 64Enter downstream temperature in deg F 130
Enter Upstream pressure 3000Enter S.G of the gas 0.7
mscf/d 61734.09mmscf/d 61.734
Formula
64 C= 605.4 T= 5901 A= 0.7857 Yg= 0.7
0.5 P1= 3014.7 Z= 0.90.25 Cd= 0.83 0.5
0.7857 1190204 19.27952
Choke
Gas rates by Choke Coefficient
Choke Size (Area in square ins)Upstream Pressure ( psig )
61734.1
document.xls 04/08/2023
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
Wishful Thinking !!!!!
tankrates
Page 78
2 10:00 9.6 11:00 182
2 Enter the intial tank reading ( Use 0 for new rate )
24 Enter the final height in cm. ( Note: 1cm = 0.4348 bbls )
10:00 Enter the start time ( diverted to tank ) hh:mm
10:30 Enter end time ( Diverted from tank ) hh:mm
Initial Tank
Reading (bbls)
Start Time
(hh:mm)
Final Tank
Reading (bbls)
End Time
(hh:mm)
Estimated Tank Rate
(bpd)
FLOWRATES BASED ON TANK READINGS
bottomsup
Page 79
1200 0.8 320 384 06 : 24
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
Page 80
total mins hours hh
384 6 0 00
06 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
Page 81
mins mm
24 0 00
24 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
Page 82
45 4546 4647 4748 4849 4950 5051 5152 5253 5354 5455 5556 5657 5758 5859 59
ansiflanges
Page 83
Service Flange NOMINAL PIPE SIZEPressure Bolting facing
Rating 1 2 3 4 6 8 10 12 14 16 18 20
Number 4 4 4 4 8 8 12 12 12 16 16 20
150# Diameter 1 1
Length of 4 6
275 psi stud bolts RTJ 6
Ring Size R 15 22 29 36 43 48 52 56 59 64 68 72
Service Flange NOMINAL PIPE SIZEPressure Bolting facing
Rating 1 2 3 4 6 8 10 12 14 16 18 20
Number 4 8 8 8 12 12 16 16 20 20 24 24
300# Diameter 1
Length of 5 7
720 psi stud bolts RTJ 5 7 9
Ring Size R 16 23 31 37 45 49 53 57 61 65 69 73
RX - 23 31 37 45 49 53 57 61 65 69 73
Service Flange NOMINAL PIPE SIZEPressure Bolting facing
Rating 1 2 3 4 6 8 10 12 14 16 18 20
Number 4 8 8 8 12 12 16 20 20 20 20 24
600# Diameter 1
Length of 5 10
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
RX - 23 31 37 45 49 53 57 61 65 69 73
1/25/8
5/85/8
3/43/4
7/87/8 1 1/8 1 1/8
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
3 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
5/85/8
3/43/4
3/47/8 1 1/8 1 1/8 1 1/4 1 1/4 1 1/4
1/16 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
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
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
1/16 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
ANSI FLANGES - NUMBER and SIZE of STUDS and RING GASKETS
ansiflanges
Page 84
RETURN TO GASKET MENU
ansiflanges
Page 85
NOMINAL PIPE SIZE
24
20
7
76
NOMINAL PIPE SIZE
24
24
77
77
NOMINAL PIPE SIZE
24
24
13
77
77
1 1/4
7 1/2
1 1/2
9 1/4
10 1/4
1 7/8
13 1/2
NAME EMPLOYEE NUMBER CLASSIFICATION PAGE 1
OF 1
ADDRESS COMPANY DEPARTMENT LOCATION
HWL Saudi Arabia. CITY,STATE,ZIP CODE EXPENSE PERIOD
From 9- June - 00 Through 17-Aug-00
PLACE NAME/TITLE/ REASON FOR BUSINESS TRAVEL AND/OR CREDIT TYPE EMP. ONLY EMP. ONLY-TRAVEL ENTERTAINMENT CHARGE
TYPE OF AFFILIATION FULL DISCUSSION INFORMATION CARD EXPENSE MEALS AND LODGING EXPENSE OTHER CARD
DATE CITY EXPENSE OF ALL GUESTS FOR ENTERTAINMENT CHARGE DEPT. (1) (2) (3) (4)
ENTERTAINED (INCLUDE DISCUSSION DURATION) X AMOUNT AMOUNT TRAVEL AMOUNT
DISTRIBUTION TOTAL THIS PAGE
CO. CODE LOCATION DEPT SUB ACCT. $ AMOUNT SECONDARY REFERENCE TOTAL ALL PAGES
SUB-ACCOUNTS
SIGNATURES TOTAL EMPLOYEE SIGNATURE DATE
LESS
ADVANCED
APPROVED BY DATE
APPROVED BY DATE AMT. DUE
COMPA
[ ] EMPLOYEE
Gas Estimate for Aramco Khuff Gas Well's.
2995 Wellhead Pressure
195 Wellhead Temp
64 Choke size ( 64ths )
0.7 S.G. ( Enter .7 for default )
0.68 Wet factor ( Compensates for fluids ) .7 default
45.79 Estimated Flow Rate ( mmscf/day )