DRL Design Tools A April 2015

Transcription

DRL Tools
DRL Toolbox & Templates
Example Functional Basis
TABLE OF CONTENTS
1
2
3
GENERAL .......................................................................................................................5
1.1
PURPOSE OF DOCUMENT ................................................................................5
1.2
AREA OVERVIEW ...............................................................................................5
1.2.1
PASCA Field ........................................................................................5
CONCEPT STUDY OBJECTIVES...................................................................................6
2.1
PASCA DEVELOPMENT OBJECTIVES ..............................................................6
SITE DATA .....................................................................................................................6
3.1
APPROXIMATE DISTANCES AND WATER DEPTHS ........................................6
3.2
GENERAL METEOROLOGY ...............................................................................6
3.2.1
General Meteorology ............................................................................6
3.2.2
EQUATORIAL TROUGH ......................................................................7
3.2.3
TROPICAL CYCLONES .......................................................................7
3.3
METOCEAN DATA ..............................................................................................7
3.3.1
Survey Area..........................................................................................7
3.3.2
Assumptions .........................................................................................7
3.3.3
Ambient CLIMATOLOGICAL Conditions ..............................................8
3.3.4
Rainfall .................................................................................................8
3.3.5
Solar radiation ......................................................................................9
3.3.6
wind, wave and current conditions ...................................................... 10
3.4
BATHYMETRY .................................................................................................. 11
3.5
GEOTECHNICAL............................................................................................... 12
4
RESERVOIR WELL FLUID DATA ................................................................................13
4.1
SEPARATOR TEST ...........................................................................................13
4.2
BINARY INTERACTION PARAMETERS ...........................................................14
4.3
FLUID COMPOSITION ......................................................................................15
4.4
PHASE ENVELOPE...........................................................................................16
4.5
RESERVOIR PROPERTIES ..............................................................................17
4.6
RESERVOIR DEPLETION AND SUPPORT MECHANISM ................................17
4.7
RECOVERABLE RESERVES ESTIMATE .........................................................17
4.8
WELL LOCATIONS ...........................................................................................17
4.9
WELL DATA & DELIVERABILITY ......................................................................17
4.10 FLOW ASSURANCE .........................................................................................18
5
PRODUCTION TARGETS ............................................................................................18
5.1
FIRST GAS AND PROJECT LIFE......................................................................18
5.2
GAS PRODUCTION ..........................................................................................18
5.2.1
Corrosivity ..........................................................................................18
5.2.2
condensate & lpg sales specifications ................................................19
6
OTHER REQUIREMENTS ............................................................................................19
6.1
DRILLING REQUIREMENTS .............................................................................19
6.2
PRODUCTION AVAILABILITY REQS AND CONTRACT OBLIGATIONS ..........19
6.3
FACILITY RELIABILITY .....................................................................................19
6.4
OPERATIONS PHILOSOPHY (HUC, SIMOPS) .................................................19
6.5
CONTINUOUS FLARING ..................................................................................19
6.6
FUTURE FACILITIES / DEVELOPMENTS – GAS EXPORT..............................19
6.7
INFRASTRUCTURE AVAILABLE ......................................................................19
6.8
OFFTAKES. .......................................................................................................19
REFERENCES .........................................................................................................................20
Fluid Characterization
Lab Test Data
Fluid
Characterisation
PFD - Overall
PFD – Sectional
PFD – Control
Process Flow Schematic
Equipment List
106
107
8060 : LIVING QUARTERS - HD & SHOP
LIVING QUARTERS & HD
108
TELECOMS
109
TRASH COMPACTOR
110
WAREHOUSE / SHOP
111
112
A-8010
TBA
TBA
10
430.0
500.0
4.0
11,000
1.0
25.000
175.0
40.000
24 / 32 MAN
Cost included separately
Solar
$250,000
$50,000
$500,000
$9,000,000
Solar
$9,000,000
Bi Level
9,000
9,000
XXX : GAS COMPRESSOR GT SKID
XXX : GAS COMPRESSOR GT SKID
14,300.0
2,900.0
65.00
25
14,300.0
2,900.0
65.00
25
XXX : GAS COOLER / SCRUBBER SKID
XXX : GAS COOLER / SCRUBBER SKID
14,300.0
6,000.0
70.00
80
14,300.0
6,000.0
70.00
80
T70 2 Stage Compressor Set
113
114
115
$4,000,000
$4,000,000
Phase 1 & 2
WP
1,401
800
96
DRL
936
430
20.0%
EQUIPMENT DRY WEIGHT
LQ DRY WEIGHT
FLARE BOOM WEIGHT
1,574
TOTAL
2,297
1,366
ABSORBED POWER
1,312.000
Contingency
TOTAL ABSORBED POWER
$55,350,363
$59,141
$ per Tonne
HYSYS – Heat & Material Balance
HYSYS – Utility Balance
Fuel Gas System
1
Generators
(3 - Centaur 40, 4,692 hp - ISO)
Load each
Running
Total Load
2
2011
2
hp
(2 x 50 %)
4022
hp
Heat Rate
9116
BTU/hp-h
Fuel Gas LHV
1300
BTU/scf
Fuel Consumption
0.68
MMscfd
6543
hp
Main Gas (Booster) Compressors
(2- Taurus 70, 10,912 hp - ISO)
Load each
Running
Total Load
3
2
13086
(2 x 50 %)
hp
Heat Rate
7205
BTU/hp-h
Fuel Gas LHV
1300
BTU/scf
Fuel Consumption
1.74
MMscfd
2805
hp
Gas Lift Compressors
(2- Centaur 40, 4692 hp - ISO)
Load each
Running
Total Load
4
Cooling Water Sum m ary
Equipment
Design Case
Supply
Return
No
Duty
Temp.
Temp.
kW
C
C
Flow
BPD
5
6
Process Coolers
1st Stage Booster Compressor Discharge Cooler (Train 1)
23-HG-1320
3852
130.3
45
22748
1st Stage Booster Compressor Discharge Cooler (Train 2)
23-HG-2320
3852
130.3
45
22748
2nd Stage Booster Compressor Discharge Cooler (Train 1)
23-HG-1340
3054
125.2
45
18033
2nd Stage Booster Compressor Discharge Cooler (Train 2)
23-HG-2340
3054
125.2
45
18033
1st Stage Gaslif t Compressor Discharge Cooler (Train 1)
23-HG-1430
1576
114.2
45
9304
1st Stage Gaslif t Compressor Discharge Cooler (Train 2)
23-HG-2430
1576
114.2
45
9304
2nd Stage Gaslift Compressor Discharge Cooler (Train 1)
23-HG-1450
1153
105.9
60
6809
2nd Stage Gaslift Compressor Discharge Cooler (Train 2)
23-HG-2450
1153
105.9
60
6809
Sub-total
19270
113788
Total
19270
113788
Sea Water Sum m ary
Sea Water Cross Exchanger A
40-HG-1610
9701
32.03
52.36
59269
Sea Water Cross Exchanger B
40-HG-1620
9701
32.03
52.36
59269
Total
19402
118538
2
(2 x 50 %)
5610
hp
Heat Rate
9125
BTU/hp-h
Fuel Gas LHV
1300
BTU/scf
Fuel Consumption
0.95
MMscfd
2042
1
2042
9125
1300
0.34
hp
(1 x 100 %)
hp
BTU/hp-h
BTU/scf
MMscfd
Sea Water Injection
(2- Centaur 40, 4692 hp - ISO)
Load each
Running
Total Load
Heat Rate
Fuel Gas LHV
Fuel Consumption
Gas Stripping 9 scf/bbl, MMscfd
Miscellaneous Consumption, MMscfd
Total Fuel gas Consumption
0.7
1
MMscfd
MMscfd
5.41
MMscfd
Notes
1. Design Case: 25,000 BOPD, 80,000 BWPD, 60 MMscfd Gas Lift & 1600 G
Dynamic Simulation
• Dynamic Simulation
12
Dynamic Simulation
• Dynamic Simulation
13
Flow Assurance Studies
• Projects
Fluid Characterization & Flow Assurance
14
Flow Assurance Studies
• Projects
Hydraulic & Corrosion Study
15
Equipment Sizing Basis
KNDP-DRL-CP-PR-PHI-0007
PROCESS REQUIREMENTS OF EQUIPMENT
AND SYSTEMS
Project:
Location:
Client:
Doc No.:
Author:
Rev. No.:
Talisman KNDPA
Offshore Pennisular Malaysia
Talisman
KNDP-DRL-CP-PR-PHI-0007
KAP / TRR
A
Date
24-Oct-12
TITLE: PROCESS REQUIREMENTS OF EQUIPMENT AND SYSTEMS
Systems / Equipment
Value
Comments
MP Separator (411-V-01)
Quantity
Configuration
Design Condition
Pressure
Temperature
Liquid Retention Time
Total Liquid Flow
Gas Flow
Condensate Flow
Max Water Flow
Normal Operation Level
Surge Factor
Maximum Liquid Carryover
Recovery of 50 micron droplets
Operation Condition
Pressure
Temperature
Rev
Date
A
24-Oct-12
1x100%
2-Phase Vertical
psig
ºF
min
blpd
MMscfd
bopd
bw pd
in
%
gal/MMscf
%
943/FV
149
2
7,000
447.00
800
6,200
36
20
0.1
99
psig
ºF
290
104.0
bar
ºC
65/FV
65
mm
914.4
bar
ºC
20.0
40.3
Notes:
1. High CO2 Case
Main Com pressor
Booster Com pressor (413-C-01/ 02/ 03)
Export Gas Com pressor (462-C-01/ 02/ 03)
Quantity
Configuration
Design Condition
Gas Flow rate (ea)
Surge Factor
Operation Condition
Suction Pressure
Discharge Pressure
Suction Temperature
Discharge Temperature
BHP (ea)
Notes
1) LM2500+ gas-turbine driver
MMscfd
%
3 x 50%
Gas Turbine Driven 2-Stage Centrifugal
Booster Compressor
Export Gas
227.00
215.00
0
0
psig
psig
ºF
ºF
hp
Total hp
261
798
88.0
258.0
15940
28740
715
1944
91.0
252.0
12800
A
2 4 - O c t - 12
bar
bar
ºC
ºC
MW
Total MW
18.0
55.0
31.4
125.9
11.9
21.4
API 14C Compliance
Process Line Sizing Report
7. PIPE PRESSURE DROP DUE TO FRICTION FOR TWO-PHASE FLOW IS ESTIMATED USING THE FOLLOWING EQUATION AS SUGGESTED BY API
14E:
P 
0.000336 f mW 2
din  m
where :
P Pressuredrop, psi/100ft;
W Total fluid (gas  liquid) flow rate, lbm/hr;
din  Pipe internal diameter,inch;
 m Gas/liquid mixture density at flowing temperature and pressure,lbm/ft3 ;
f m  Moody friction factor calculated using same method as in the single phase but weighted gas/liquid mixture viscosity is used.
8. THE LIQUID PHASE MIXING (EMULSION) RULE FOR VISCOSITY IS REFERENCING TO HYSYS OPERATION MANUAL, NOT IN API OR GPSA.
 eff   oil e 3.6(1 v
oil
)
( for voil  0.5)

  0.4 h 2o 
 eff   h 2 o 1  0.25voil ( oil
) ( for voil  0.33)
 oil   h 2o 

If the volume of the oil phase is between 0.33 and 0.5, the effective viscosityfor combined liquid phase is calculated
using a weighted average between two Equations.
where:
 eff  apparent viscosity of oil/water mixture, cp;
 oil  viscosityof oil phase, cp;
voil  volume fraction oil phase
 H2O  viscosity of Aqueous phase, cp.
9. THE PROCESS DATA CAN BE CREATED BY XXX/XXX. ASK XXX FOR DETAILS.
10. FOR QUESTION OR SUGGESTION, PLEASE CALL XXX @ XXX.
Pump Sizing
Pump Calculation Sheet
Input values required: blue numbers. Calculated values: black numbers
Item no.:
Service:
F
L
U
I
D
No. of:
Case:
P-3001
LPG pumps
Fluid
Fluid Temperature
LPG
37 deg.C
800 kg/m 3
0.12 cP
(1) Density (@ T & P)
Viscosity (@ T & P)
(4) Normal pressure
(5) Set Pressure
(6) Vapour pressure
(7) Static Head
(8) Max. Static Head Not
Note 1
10.0 m =
12.0 m =
(9) Line Loss
(10) Loss, Equipment
(11) Loss, Other/Fittings
P
U
M
P
N
O
T
E
S
Note1: Optional input for calculation of maximum discharge
pressure and estimated power consumption.
120 m 3/h
120 m 3/h
(2) Normal Flowrate
(3) Design Flowrate Note1
S
U
C
T
I
O
N
Type:
NPSHA calc.
10.00 barg
15.00 barg
4.01 bara
0.78 bar
0.94 bar
0.30 bar
1.50 bar
1.00 bar
D
I
S
C
H
A
R
G
E
(12) Termination Pressure
(13) Static Head
(14) Loss, Pipe & Fittings
(15) Loss, Other
17.00 barg
0.0 m =
(16) Pump Shut-in Diff.Pressure Note1
(17) Pump Suction Pressure = (4)+(7)-(9)-(10)-(11)
(18) Pump Discharge Pressure = (12)+(13)+(14)+(15)
(19) Pump Differential Pressure = (18)-(17)
7.98 barg
21.70 barg
13.72 bar
Maximum Discharge Press. = (5)+(8)+(16)
30.94 barg
NPSHA= [(17)-(6)+1 ATM]*100000/[(1)*9,81]
63.52 m
0.00 bara
1.60 bara
3.10 bara
15.00 bara
P2
Reference point 2
Hst2
P1
(20) Hydraulic Power = (19)*(3) / 36
(21) Estimated Efficiency
Estimated Power = (20) / (21)
45.7 kW
80 %
57.1 kW
Reference point 1
Hst1
Hf2
Hf1
Psuction
P1-Hst1-Hf
Pdischarge P2+Hst2+Hf2
SYSTEM SKETCH
P1
Hst1
Hf1
Psuction
normal operating pressure upstream pump
height difference between reference point 1 and pump suction
friction loss upstream pump
pump suction pressure
P2
Hst2
Hf2
Pdischarge
termination pressure
height difference between reference point 2 and pump discharge
friction loss downstream pump
pump discharge pressure
Prelim Compressor Sizing
Gas Compressor
3/7/2013
150
1
UNITS
NAME
Case 1
MMSCFD
lb/m in
kg/h
MSCF
m
150.00
5,461.73
148,618
MW
k
z
19.90
1.464
0.838
ps ia
°F
cu.ft./lb
ACFM
Nm 3/h
P1
T1
V1
Q1
435.0
113.0
0.60
3,251
5,526
ps ia
°F
cu.ft./lb
ACFM
P2
T2
V2
Q2
1,815.0
549.1
0.25
1,372
%
ft
PR
EP
pH
4.17
80.0%
71,618
BHP
kW
HP
14,817
11,053
15,261
11,385
11
Total gas
no. of com press ors
REMARKS
Capacity
Gas Flow
Mass Flow
Input from proces s data s heet.
Check calc. with proces s data s heet.
Calculate for each section
Gas Properties
m olecular Weight
Specific Heat Ratio
Com press ibility
Us e Cp/Cv from Gas Analys is
Us e avg. Z from Gas Analysis
Inlet Conditions
Suction Pres s ure
Suction Tem perature
Suction Specific Volum e
Actual Volum e Flow
Actual Volum e Flow
Discharge Conditions
Dis charge Pres s ure
Dis charge Tem perature
Dis charge Specific Volum e
Dis charge Volum e Flow
Stage Parameters
Press ure Ratio
Polytropic Efficiency
Polytropic Head
Power Requirements
Brake Hors epower
Brake Hors epower
Driver Hors epower
Driver Kilowatts
Driver Megawatts
Design Analysis
bhp
bkW
hp
KW
mW
mW
14
Allow interstage press ure drop.
Us e Cooler Outlet Tem p. in °F
ACFM selects cas ing fram e s ize.
ACFM selects cas ing fram e s ize.
Input in psia.
If T2 > 350 °F Us e Intercooler.
Input from flow coefficient chart.
Without recirc., gear & bearing loss
Without recirc., gear & bearing loss
BHP + 3% gearloss + 0% m argin
with 25% allowance
Separator Sizing
LP SEPARATOR
20-VA-1001
Horizontal Separator Data Sheet
INPUTS
with Demister Pad
OUTPUT
III. New Capacities:
I. Vessel Conditions :
HLLSD sw itch (from bott. of vessel)
Vessel Length S/S:
Estimated K value (using EXX
Specs. GSC-5-21 iss. 7/94 {pg.10/13})
User K value override:
K Value being used in calcs.
Critical Velocity:
Gas Over Design Factor:
Calculated Design Velocity:
Min. Liquid Residence time, min
Est. Liquid Level (% Diameter)
35 ft.
0.53
ft/sec
0.9
0.9000
12.081
1.1
10.873
4
60.00%
ft/sec
ft/sec
ft/sec
Use 0.9 for Cyclonics
NLL to HLLSD Surge Capacity:
-EXX Specs. us e K=0.67*(L/20).5
for scrubbers, and K=0.4*(L/20).5
for separators.
Nominal Vapor Capacity:
Nominal Total Liq. Capacity:
<---e.g. entry '1.1' means 10% safety factor
ft/sec
min.
117.2 in.
108.4 in.
Case ONE
122.00 in.
Liquid Height:
73.2 in.
50.8 ft²
Cross-sectional area occ. by liquid
Total Crossectional Area:
81.2 ft²
Cross-sectional area occupied by gas
30.32 ft²
3.2 ft.
Required Effective length
Liquid Containment (BBL) :
316.9
4.3 min.
Actual Retention Time:
1.000 in.
Shell Thickness
Vapor Velocity: (ft/sec)
8.59
Two Phase Separators:
Desired Internal Diameter of Vessel:
Case TWO
Case THREE
102.4 in.
107.2 in.
114 BBl
125 BBl
165.8 MMSCFD
181.7
111232 BPD
121905
IV. Sizing Parameters
II. Pre-sizing Calcs. :
Min. I. D. if liquid controlled
Min. I. D. if gas controlled
Case ONE
97.6 in.
104 BBl
150.6 MMSCFD
101049 BPD
Case TWO
128 in.
76.8 in.
56.0 ft²
89.3 ft²
33.38 ft²
3.1 ft.
348.8
4.8 min.
1.000 in.
7.81
Case THREE
134 in.
80.4 in.
61.3 ft²
97.9 ft²
36.58 ft²
2.9 ft.
382.3
5.2 min.
1.000 in.
7.12
Chosen Internal Diameter:
Chosen Liquid Height
Nominal Total Liq. Capacity:
Vessel Length
Slenderness Ratio:
Shell thickness
User Override Shell thickness
Nozzle Weight Multiplier
Estimated Weight (empty)
Estimated Weight (operating)
122.0 in.
73.2 in.
101049BPD
35 ft.
3.44
1.000 in.
1.25
65248 lb.
170947 lb.
std
Vessel Design Summary
V. Rates & Parameters:
Conditions
Operating Pressure:
Operating Temp.
Gas Viscosity:
72.519 psig
134.6 °F
0.012 cP
Design Properties
Design Pressure:
Design Temp.
Corrosion Allowance
Design Tensile Stress:
217.557 psig
200 ° F
.118 in.
17500 psi
Flow Rates
Vapor
Oil/Condensate
Water/Heavy
119.1 MMSCF/D
25126 BPD
80272 BPD
Nozzle Diameters
Inlet Diameter
Vapor Outlet
Oil/Condensate
Water/Heavy
34
30
6
10
in.
in.
in.
in.
Three Phase Separators:
Water Level (% of diameter)
40.00%
4 ft.
20.0%
Case THREE
80.4 in.
4.6 min.
53.6 in.
36.6 ft²
202 BBL
3.6 min.
24.8 ft²
140.3
8.0 min.
4.7 min.
Oil Section (w eir to outlet-seam)
Vessel Summary
Oil section, percent of diam. full:
Weir Height, (from bottom of tank)
Inlet Section Residence time
Water Height:
Cross-sectional area occ. by w ater
Water Containment:
Water Retention time
Cross-sectional area occ. by oil
Oil Containment (BBL):
Oil Retention time
Total Liq. Retention time
Case ONE
73.2 in.
3.8 min.
48.8 in.
30.3 ft²
167 BBL
3.0 min.
20.5 ft²
116.3
6.7 min.
3.9 min.
Case TWO
76.8 in.
4.2 min.
51.2 in.
33.4 ft²
184 BBL
3.3 min.
22.6 ft²
128.0
7.3 min.
4.3 min.
Internal Diameter
Shell thickness
Vessel Length
Comments:
122.0 in.
1.000 in.
35 ft.
65248 lb.
170947 lb.
<4.5m MAX
< 6 in MAX
< 100 T MAX
3.098806
25.4
10.67073
29.5911
77.52684
m
mm
m
mT
mT
Example Separator
LP Separator 3-Phase Conversion
Vane Type
Demister
Vane Type
Inlet Device
New Weir
Sand Flush System
Settled sand/solids will flushed
towards the
PW outlet and separated by
inline desanding system
Perforated Baffles
Reduce turbulence and set up
even liquid velocity profile
New PW
outlet nozzle
Oil Outlet
(existing)
Scrubber Sizing
23-VG-1310/2310
1ST STAGE SUCTION SCRUBBER A/B
Vertical Separator Data Sheet
I. Vessel Conditions:
Calculated K value
with Demister Pad
(using
INPUTS
IV. Liquid Capacity (For Specified Vessel)
OUTPUT
Nom. Liquid Capacity
Max. Liquid Capacity
Min. Liquid Capacity:
Slug Capacity:
0.35
GP SA Ch.7 pg.7-7, fig. 7-9)
User K value override:
K value being used in calc.:
0.9
Use 0.9 for Cyclonics
0.9
Critical Velocity:
10.8876 ft/sec
Gas Over Design Factor:
1.13 (e.g. entry '1.1'=10% safety facto r)
Calculated Design Velocity:
9.472 ft/sec
Liquid Retention Time recomm. 1.00 min.
Typical Rete ntion Tim es :
User override:
1 min.
Oil Gravities
Minutes
Liquid Retention Time used:
1.00 min.
above 35° API
1
II. Pre-Sizing Calcs.
A) Min. Dimensions (in.):
Min. demister pad clearance
Demister Pad thickness
Demister Pad to Inlet Nozzle
B)
C)
D)
E)
Min. Vessel Internal Diameter:
Vessel Height, est. using LRT:
20-30° API
1 to 2
10-20° API
2 to 4
Actual Retention time:
51.57
111
111
111
Inlet Nozzle to HLL
HLL to NLL
35
in.
in.
in.
in.
23
12
-------------------->
using an I.D.=
using an I.D.=
using an I.D.=
ro unded to nearest half-fo o t
VI. Vessel Summary
Inside Diameter
Shell thickness, inches
User Override Shell thickness
Calc. Vertical Dimensions (in.)
1) Minimum Extractor Clearance2) Demister Pad thickness
3) Inlet Nozzle to Demister Pad
4) Inlet Nozzle Diameter
5) Inlet Nozzle to HLL
6) NLL to HLL
7) Liquid Retention, in,
Total Height:
Slenderness Ratio:
54
in.
in.
in.
in.
in.
in.
12
.0 in.
11.3
6.0
36.0
22.0
23.0
12.0
110.3 in.
2.04
User Overrides (in.)
------------------------------------36
68.17 psig
134.42 °F
0.012 cP
261.07 Psig
200 °F
.118 in.
17500 Psig
Flow Rates
Vapor
Oil/Condensate
Water/Heavy
Nozzle Diameters
Inlet Diameter
Vapor Outlet
Oil/Condensate
Water/Heavy
59.7 MMSCF/D
0 BPD
0 BPD
22.0
22.0
2.0
2.0
in.
in.
in.
in.
Vessel Summary
III. Final Dimensions, inches.
Desired I.D.(in.)
Minimum extractor clearance:
Demister Pad thicknessInlet to Demister Pad:
Inlet Nozzle DaimeterInlet Nozzle to HLL
NLL to HLL
LLL to NLL
Liquid Height
Design Pressure:
Design Temp.
Corrosion Allowance
V. M ax. Gas Capacity (For specified Vessel)
8.641 ft/sec
New Vapor Velocity
YES
Critical>Nominal?
65.414 MMSCFD
Max Vapor
23
54
30
36
42
I. Rates & Parameters:
Conditions
Operating Pressure:
Operating Temp.
Gas Viscosity:
BPD
BPD
BPD
Barrels
min.
Design Properties
*Chart data taken fro m A P I 12-J spec. fo r Oil
& Gas Separato rs, pg. 14 sectio n C.1.7*
12
6
36
0
4079
0
2.8
#DIV/0!
55.12 m->in
Total Vessel Height:
User Override Vessel Height:
Nozzle Weight Multiplier:
Weight Estimation:
54.0 in.
1.371599 m
.625 in. <=== rounded up to nearest 1/8 inch.
Inside Diameter
1) Minimum Extractor Clearance2) Demister Pad thickness
11.3 in.
6.0 in.
36.0 in.
22.0 in.
23.0 in.
12.0 in.
12.0 in.
10.2 ft.
10.2 ft.
1.25
5630 lb.
Cyclone has greater thickness
5) Above NLL
6) NLL to HLL
Weight Estimation:
3.106765
10.82677
std
2.553357
2.2
54.0 in.
.625 in.
11.3 in.
6.0 in.
36.0 in.
22.0 in.
23.0 in.
12.0 in.
12.0 in.
10 ft.
1.25
5630 lbs.
ft->m
m-> ft (Genesis)
lb->Tonne
Tonne (Genesis)
-------------------------------------
(GPSA and API recommend ratio be betw een 3-5)
Comments:
Genesis D: 1.4m = 55.12 in. Minimum calculated D: 54 in. Genesis H = 3.3m, Calc
H = 3.1m. Genesis wt = 2.2 Tonnes. Calc wt = 2.5 Tonnes.
Flare Drum Sizing (Horizontal)
Equi pm e nt:
C LO SED DRAIN/LP FLARE KO DRUM
C lie nt:
TML
Proje ct:
KNDP B O ption 1A
Proje ct No.:
XXX
(Horizontal)
Equi pm e nt ID: 43-VD-1730
By: Danial
Date : 29/4/2013
HORIZONTAL SCRUBBER SIZING CALCULATION
(Based on API RP 521)
Case2:Peak Rate to Flare
INPUT DATA:
Operating Temperature (°F)
Operating Pressure (psig)
Droplet Diameter (microns) (API521: 400 - 600)
Liquid Specific Gravity
Gas Molecular Weight
Gas Compressibility Factor (z)
Design Gas Flowrate (mmscfd)
Gas Viscosity (cP)
Vessel Max Operating Level (% full)
Vessel Inner Diameter (ft)
Conditions
INTERMEDIATE VALUES:
135
30
600
0.7238
23.12
0.9803
5
0.012
70
5
Operating Temperature (°R)
Operating Pressure (psia)
Particle Diameter (ft)
Liquid Density (lbs/ft3)
Gas Density (lbs/ft3)
C(Re)^2
Gas Flowrate (acfs)
shouldbe
5
595
44.7
0.001968
45.2
0.1651
3.74E+04
21
1.524 m
Operating Pressure:
Operating Temp.
Gas Viscosity:
30 psig
135 °F
0.012 cP
Design Properties
Design Pressure:
Design Temp.
Corrosion Allowance
50
200
0.11811
17500
Psig
°F
in
Psig
Flow Rates
Vapor
Oil/Condensate
Water/Heavy
Nozzle Diameters
Inlet Diameter
Vapor Outlet
Oil/Condensate
Water/Heavy
5 MMSCF/D
18000 BPD
54000 BPD
18.0
10.0
6.0
10.0
in.
in.
in.
in.
<12
Vessel Summary
RESULTS:
Drag Coefficient (refer to API521, Fig20)
Dropout Velocity (ft/sec)
Liquid Dropout Time (sec)
Zc
0.70
( for C(Re)^2=
Internal Diameter
Shell thickness
Vessel Length
3.74E+04 )
5.71
0.26
0.30
1.98
0.252
4.94
4.32
1.13

F(Zc) [Vapor Section Area Fraction]
Cross secional area for gas flow (sq ft)
Velocity of vapor (ft/sec)
Minimum Required length of vessel by liquid droping(ft)
SLUG HANDLING:
Normal Operation Liquid Level (%)
Required Slug Handling (bbl)

F(Zc) [Normal Liquid Section Area Fraction]
Normal Operation Liquid Volume (ft3)
(bbl)
Max Operation level (%)
Max Operarion Liquid Volume (bbl)
Slug Handling (bbl)
" I.D x
in
30
50
15
std
1.16
0.252
74
13
70
39
26
<4.5m MAX
< 6 in MAX
< 100 T MAX
1.524003
6.35
4.573171
1.590692
6.484158
Comments:
Genesis D: 2.4 m = 7.9 ft. Minimum calculated D: 5 ft = 1.53 m. Genesis L = 7.2m
(23.6 ft), Calc L = 4.6m (15 ft). Genesis wt (dry) = 6.7 Tonnes. Calc wt = 1.6 Tonnes.
OVERALL VESSEL DIMENSIONS SELECTED:
60
60.0 in.
.250 in.
15 ft.
3507 lb.
14298 lb.
' S/S
ft
(Length)
3 < L/D < 6
L/D =
3
m
mm
m
mT
mT
Flare Drum Sizing (Vertical)
Tag No.
43-VD-1700
Se rvice
HP Flare KO Drum
(Vertical)
Case1
1. Operation Condition
Gas Flow rate
MMscfd
Operation Pressure
psig
50
Operation Temp
F
135
Gas Z
Operating Pressure:
Operating Temp.
Gas Viscosity:
0.797241379
cP
Liquid S.G
Liquid Slug Size
Conditions
0.9803
Gas S.G
Gas Viscosity
120
0.0120
A
Flow Rates
Vapor
Oil/Condensate
Water/Heavy
73 psig
135 °F
0.012 cP
0.7238
BBL
76
Design Properties
B
Design Pressure:
Design Temp.
Corrosion Allowance
C
ACFM
21287
Gas Density
lb/ft3
0.24
Liquid Density
lb/ft3
45.14
110 k BPD @ 1 min
bpd =
HHL
Nozzle Diameters
Inlet Diameter
Vapor Outlet
Oil/Condensate
Water/Heavy
145 Psig
200 °F
.118 in.
17500 Psig
min =
bbl =
D
110,000
1
76.38888889
Inside Diameter
HL
E
1) Minimum Extractor Clearance-
NL
3. Gravity Separation
2) Demister Pad thickness
F
Microns
C(Re)^2
600
5.38E+04
C, From Fig.7-3 of GPSA
5) Above NLL
0.59
V, Critical gas velocity
ft/s
5.20
A, Vessel Cross Area
ft2
68.28
D, Vessel ID
inches
112
34.0
30.0
6.0
10.0
in.
in.
in.
in.
H
2.8448 m
Vessel Summary
Dp, Particle Diameter
120 MMSCF/D
25126 BPD
80272 BPD
6) NLL to HLL
ID
Selected ID=
Weight Estimation:
112.00
112.0 in.
.625 in.
29.0 in.
6.0 in.
36.0 in.
34.0 in.
29.0 in.
12.0 in.
12.0 in.
14.0 ft.
1.25
17626 lbs.
9.333333 ft
4.2672 m
7.993496 Tonnes
4. Configuration
ID
inches
A
ft
112.00
in->ft
9.3333333
~10ft (3.1m) height standard for scrubber
2.8447999 m
2
B
ft
2
C
ft
2
D
ft
4.5
E
ft
0.42
F
ft
2.17
H
ft
13.1
Ratio
Se le cte d H=
3< L/D < 6
14 ft
1.5
4.2671999 m
Comments:
Genesis D: 3.0m = 118.12 in. Minimum calculated D: 112 in. Genesis L = 7.5m, Calc H =
4.3m. Genesis wt = 17.5 Tonnes. Calc wt = 8 Tonnes.
Electrical Load List
Full Production 30,000 BPD, 34.5 MSCFD
Load on Turbine Generators (1)
Ship Service Generation Capacity
(N + 1, Full Production Included, Electric Drive VRU)
(N + 1, Full Production Included, Electric Drive VRU)
One Turbine Generator running, one idle.
Full Production Load
4190
Rating of Taurus 60 (T-7901) Turbine
Generator, Dual Fuel, Using NG, Site Rating at
95º F, Inlet & Exhaust Duct Loss: 10" WC
XXX
XXX Field Development
Topsides FEED
Verificiation Against ABS & USCG Rules, Other Analysis
Full Production 45,000 BPD, 51.7 M SCFD
Load on Turbine Generators (1)
4376
Quantity of Turbines Running
kW
kW
Rating of Taurus 60 (T-7901) Turbine
Generator, Dual Fuel, Using NG, Site Rating at
95º F, Inlet & Exhaust Duct Loss: 10" WC
Load on One Turbine
4190
96%
Available Capacity With One Turbine Running
4376
4376
Quantity of Turbines Running
1
Percent Loading on One Turbine
5419
kW
kW
Non-Production Load
1889
kW
kW
T-60 (T-7901) Turbine Generator, Dual
Fuel, Using NG, Site Rating at 95º F,
Inlet & Exhaust Duct Losses 10" WC
4376
kW
Percent Loading on One Turbine
43%
2
Load on Each Turbine
2709
Percent Loading on Each Turbine
62%
Available Capacity With Tw o Turbines Running
8752
(2)
kW
Ship Service Transformer Capacity
Remaining Capacity
186
Load on 5 kV Switchgear Bus
Electrical Load Analysis
Rated Amps
Connected Load
kVA
2000
Amps
9521
1321
Connected Load
66%
Percent of Rated Amps
kW
kVA
4190
4749
Amps
659
33%
Amps
2063
2310
2779
Connected Load
69%
Amps
652
720
kVA
2000
Amps
9521
1321
Main Transformer Rating at 55º C
2500
Percent Loading on One Transformer
71%
kVA
kW
866
22%
Load on Emergency Diesel Generator
Connected Load
(4)
565
kW
Emergency Diesel Engine Rating
725
kW
Percent Loading on Emerg Diesel Engine
78%
66%
kW
kVA
5419
6147
Amps
853
43%
Load on Auxiliary Diesel Generator
Rated Amps
kVA
kVA
kW
8429
4000
kW
kW
3333
Load on 480V Switchgear - Bus A
Rated Amps
Connected Load
Rated Amps
kW
Load on 480V Switchgear - Bus A
JOB NO. XXX
Remaining Capacity
8429
Document No.XXX
kW
kVA
kW
Load on 5 kV Switchgear Bus
kW
(3)
One M ain Transform er in service, one idle.
Non-Production Load
1766
4000
kW
kVA
Amps
2063
2310
2779
Black Start Load
492
kW
725
kW
68%
kW
kVA
69%
Amps
Aux Diesel Engine Rating
855
949
1142
Percent Loading on Aux Diesel Engine
29%
Load on Main Transformer
Load 480V Switchgear - Bus B
Load 480V Switchgear - Bus B
Rated Amps
Connected Load
kVA
Amps
2082
2261
2720
Connected Load
kVA
68%
Amps
kW
928
1011
1216
30%
Rated Amps
4000
kW
4000
One M ain Transform er in service, one idle.
1731
kW
kVA
Amps
2082
2261
2720
Main Transformer Rating at 55º C
2500
kW
kVA
68%
Amps
Percent Loading on Main Transformer
69%
998
1077
1295
kVA
kVA
32%
Capacity of 5 kV Main Generation Bus (10)
REV NO.
A
DESCRIPTION
FOR CLIENT COMMENT
AUTHOR
XXX
CHECK
XXX
APPROVED
XXX
DATE
Tw o Turbine Generators Connected.
Load on 480V Emergency Switchgear
28/6/2005
Load on 480V Emergency Switchgear
Rated Amp
1600
kW
kVA
Amps
Connected Load
565
614
738
46%
kW
kVA
Amps
300
327
393
25%
Rated Amps
Connected Load
kW
kVA
565
614
738
kW
kVA
46%
Amps
300
327
1600
Amps
5 kV Bus Rating
2000
Amps
Maximum Generator Rating (2 Gen's)
1666
Amps
Percent of Bus Rating
83%
Capacity of 480V Switchgear Bus (10)
One M ain Transform er Connected.
393
480V Bus Rating
4000
Amps
25%
Maximum Transformer Rating (1 Trans)
3368
Amps
Percent of Bus rating
84%
Integrated LER & CR Modular Building Example
Layout - MOPU FE Studies
Flare Isopleths
Weight Estimation Model
Standard Work Breakdown Structure
Cost Estimating – Facilities Cost Output 1 of 2
31
Standard Work Breakdown Structure
Cost Estimating – Facilities Cost Output 2 of 2
32
Cost Estimating – Brownfield Tool Structure
• Offshore Brownfield Estimating Tools
• Cost Estimating
– Level 1
– Level 2
– Level 3
Norms
– Level 4
Norms
- Capacity Basis
- Tonnage Basis
- Composite Quantity
- Detailed Job Card
33
END

DRL Design Tools A April 2015

Transcription

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