z00b Ti Cal 1 0552-04-09 Lychkin Mooring Module3
Short Description
mooring analysis...
Description
333 ISTANBUL TECHNICAL UNIVERSITY
FACULTY OF NAVAL ARCHITECTURE AND OCEAN ENGINEERING DENTEK WORKING GROUP
ARAŞTIRMA YAZILIM OPTİMİZASYON VE HİZMETLERİ LİMİTED
1600 T PONTOON CRANE CAPTAIN LYCHKIN INSTALLATION 4 MODULE 3
MOORING ANALYSES
AUGUST 2014
COMMERCIALLY CONFIDENTIAL
ISTANBUL TECHNICAL UNIVERSITY FACULTY OF NAVAL ARCHITECTURE AND OCEAN ENGINEERING DENTEK WORKING GROUP
ILK CONSTRUCTION – 1600 T PONTOON CRANE CAPTAIN LYCHKIN INSTALLATION 4 MODULE 3 MOORING ANALYSES
1
CONTENTS 1. INTRODUCTION
2
2. GENERAL PARTICULARS
4
3. MOORING ARRANGEMENT AND EQUIPMENT
6
4. METOCEAN DATA
8
5. WIND, CURRENT AND WAVE FORCES
12
6. MOORING ANALYSIS (INTACT)
17
7. MOORING ANALYSIS (DAMAGED)
46
8. API RP 2SK REQUIREMENTS
48
9. CONCLUSIONS
50
APPENDIX : TYPICAL INPUT / OUTPUT FILES
51
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1. INTRODUCTION This report presents the results of a mooring analysis study for the 1600 T PONTOON CRANE CAPTAIN LYCHKIN INSTALLATION 4 MODULE 3 in which a mooring layout is developed and analyzed in accordance with the rules and recommendations of API RP 2SK (American Petroleum Institute - Design and Analysis of Station Keeping Systems for Floating Structures). First, general particulars and a general arrangement plan are presented in Section 2. Geometric and weight distribution characteristics are also presented. The vessel is assumed to be moored by 8 x 1000 m wire rope mooring lines and 8 anchors. The mooring layout and properties of the elements of the mooring system are presented in Section 3. Section 4 presents the environmental characteristics of the mooring area. Two distinct sets of environmental conditions are considered for the analyses: Maximum Allowable Conditions Significant Wave Height
: 1.2 m
Wind Speed
: 13 m/s
Current Velocity
: 0.9 m/s
Survival Conditions Significant Wave Height
: 5.0 m
Wind Speed
: 29 m/s
Current Velocity
: 1.2 m/s
Section 5 presents the methods used to predict the wind, current and wave forces acting on the system.
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Section 6 presents the results of intact mooring analysis for operating and survival environmental conditions. Based on these simulations maximum environmental loading on mooring lines are estimated. Mooring analyses presented in Section 6 assume that all the mooring lines are intact. In accordance with the API RP 2SK (American Petroleum Institute - Design and Analysis of Station Keeping Systems for Floating Structures) the system should have sufficient holding capacity when one of the mooring lines is damaged. In Section 7 the results of the damaged mooring analyses are presented. In Section 8 the results of the intact and damaged mooring analyses are compared with the rules and requirements of the API RP 2SK in order to prove that the mooring system has sufficient strength and holding capacity. A summary of the results of the study is presented in Section 9.
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2. GENERAL PARTICULARS General particulars of the 1600 T PONTOON CRANE CAPTAIN LYCHKIN are presented below. Figure 2.1 shows the general arrangement plan of the vessel. Length over all (LOA)
99.600 m
Length of waterline (LWL)
99.600 m
Moulded Breadth (BM)
35.000 m
Moulded Depth (DM)
6.450 m
Draught (Light Service)
2.800 m
Summer Draught (scantling)
4.500 m
Light Ship Weight
4485.43 t
Summer Displacement (scantling)
14803.5 t
Figure 2.1. General arrangement plan.
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General particulars for the case of INSTALLATION 4 MODULE 3 are as follows:
Module Dimensions (mm)
28100 x 21500 x 5500
Module Weight (t)
353
Lifting Equipment weight (t)
50
Total module weight (t)
403
Displacement (t)
13312.4
Draft at AP TAP (m)
4.278
Draft at FP TFP (m)
3.886
Mean Draft TMID (m)
4.082
Freeboard (m)
2.368 0.392 (bow)
Trim (m)
0
Heel (deg) LCG (m)
50.36
TCG (m)
0.0009
KG (m)
6.463
GM (m)
22.219
Lateral Windage Area (m2)
1512
Longitudinal Windage Area (m2)
734
Lateral Underwater Area (m2)
407
Longitudinal Underwater Area (m2)
143
The above information is taken from the following report: 1600 ton Pontoon Crane Captain Lychkin, Stability Information and Longitudinal Strength Booklet during the Installation of Modules, Report No : NVS075.5302.004.0, NavisDesign
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3. MOORING ARRANGEMENT AND EQUIPMENT Mooring arrangement for the case of INSTALLATION 4 MODULE 3 is provided by ILK CONSTRUCTION as shown in the following figure:
EX IS N TI G PE E N LI PE PI
Anchor 1
4,7
m
LAM F ck Ja et D Ja ck et A Ja
ck
et
C et
B
ck Ja
Module 3
Anchor 2
Anchor 3
Figure 3.1. Mooring arrangement for INSTALLATION 4 MODULE 3.
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Properties of the mooring anchors, anchor ropes and anchor winches are as follows:
1. HYDRAULIC WINCHES Winch No 1 2 3 4 5 6 7 8
Pull Load
Over Load Pull
Brake Hold
60 Ton 60 Ton 60 Ton 60 Ton 45 Ton 45 Ton 45 Ton 45 Ton
69 Ton 69 Ton 69 Ton 69 Ton 67.5 Ton 67.5 Ton 67.5 Ton 67.5 Ton
130 Ton 130 Ton 130 Ton 130 Ton 120 Ton 120 Ton 120 Ton 120 Ton
2. STEEL WIRE ROPE Line No 1 2 3 4 5 6 7 8
Length 1000 m 1000 m 1000 m 1000 m 1100 m 1100 m 1100 m 1100 m
Nominal Diameter 44 mm 44 mm 44 mm 44 mm 44 mm 44 mm 44 mm 44 mm
Minimum Breaking Load 1500 kN 1500 kN 1500 kN 1500 kN 1500 kN 1500 kN 1500 kN 1500 kN
Actual Breaking Load 1635 kN 1635 kN 1635 kN 1635 kN 1635 kN 1635 kN 1635 kN 1635 kN
Total Weight
3. ANCHOR LineNo 1 2 3 4 5 6 7 8
Type HYD-14 HHP HYD-14 HHP HYD-14 HHP HYD-14 HHP HYD-14 HHP HYD-14 HHP HYD-14 HHP HYD-14 HHP
4. METOCEAN DATA © Commercially
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Weight 10030 kg 10030 kg 10040 kg 10010 kg 10040 kg 10050 kg 10030 kg 10030 kg
Proof Load 1174 kN 1174 kN 1175 kN 1173 kN 1175 kN 1175 kN 1174 kN 1174 kN
8150 kg 8150 kg 8150 kg 8150 kg 8965 kg 8965 kg 8965 kg 8965 kg
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The operational area for the vessel is Lam and Zhdanov oil fields, offshore Turkmenistan, with location given by the co-ordinates 390 27’ 13” N, 520 48’ 39” E . The average water depth is about 20 m. Metocean data for the region is taken from the following report: METOCEAN DATA LAM AND ZHDANOV FIELDS Report No: L18982/NDE/hdl 20 April 2000 NOBLE DENTON EUROPE LTD. The extreme environmental conditions likely to be reached or exceeded once, on average, during the return period of One year, Five years, Ten years, Fifty years and Hundred years are presented in Tables 4.1 through 4.5.
Table 4.1. One year extreme environmental conditions
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Table 4.2. Five year extreme environmental conditions
Table 4.3. Ten year extreme environmental conditions
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ILK CONSTRUCTION – 1600 T PONTOON CRANE CAPTAIN LYCHKIN INSTALLATION 4 MODULE 3 MOORING ANALYSES
Table 4.4. Fifty year extreme environmental conditions
Table 4.5. Hundred year extreme environmental conditions
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Based on the above data two distinct sets of environmental conditions are considered for the analyses:
Maximum Allowable Conditions Significant Wave Height
: 1.2 m
Wind Speed
: 13 m/s
Current Velocity
: 0.9 m/s
Survival Conditions Significant Wave Height
: 5.0 m
Wind Speed
: 29 m/s
Current Velocity
: 1.2 m/s
5. WIND, CURRENT AND WAVE FORCES © Commercially
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The vessel must endure various phenomena, such as wind, waves and current. It is vital that the forces generated by wind, waves and current are modelled and calculated correctly.
5.1. Wind Forces API RP 2SK recommends the following formula for calculating the steady state force due to the wind acting on a moored floating unit: FW C W CSC h A VW2
where FW
: Wind force [N]
CW
: 0.615 [Nsec2/m4]
CS
: Shape coefficient
Ch
: Height coefficient
A
: Vertical projected area of each surface exposed to the wind [m2]
VW
: Design wind speed [m/sec]
The projected area exposed to the wind should include all columns, deck members, deck houses, trusses, crane booms, derrick substructure, and drilling derrick as well as that portion of the hull above the waterline. In calculating wind areas open truss work commonly used for derrick mast and booms may be approximated by taking 60 percent of the projected block area of one face. The wind force shape coefficients are given in the following table.
Table 5.1. Wind force shape coefficients © Commercially
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CS
Exposed Area Cylindrical shapes
0.50
Hull (surface above waterline)
1.00
Deck house
1.00
Isolated structural shapes (cranes, channels, beams, angles)
1.50
Under deck areas (smooth surfaces)
1.00
Under deck areas (exposed beams and girders)
1.30
Rig derrick
1.25
Wind velocity increases with height above the water. In order to account for this change, a wind force height coefficient, C h , is included. The wind force height coefficients are given in the following table. Table 5.2. Wind force height coefficients Height of area centroid above the water level (m) Not Exceeding
0
15.3
1.00
15.3
30.5
1.18
30.5
46.0
1.31
46.0
61.1
1.40
61.1
76.0
1.47
5.2. Current Forces © Commercially
Ch
Over
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There are many alternative ways to calculate current forces. The most widely accepted model are those recommended by the Oil Companies International Marine Forum (OCIMF 1997). The OCIMF model expresses the current forces as follows: X C C XC C VC2 A T 7600 YC C YC C VC2 A L 7600 N C C NC C VC2 A L L BP 7600 where L BP
: Length between perpendiculars [m]
AL
: Longitudinal underwater projection area [m2]
AT
: Transverse underwater projection area [m2]
XC
: Longitudinal current force [kN]
YC
: Lateral current force [kN]
NC
: Current yaw moment [kNm]
C XC
: Longitudinal current force coefficient
C YC
: Transverse current force coefficient
C NC
: Current yaw moment coefficient
C
: Mass density of sea water (1.025 kg/m3 at 20 0C)
VC
: Average current velocity acting over the draft [kn]
5.3. Wave Forces © Commercially
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The waves affect a manoeuvring vessel in two distinct ways;
First order oscillatory forces centred on the dominant wave encounter frequency, and
Second order drift forces which consist of a steady component and a low frequency component The first order forces are much larger in magnitude compared with the second order forces. A strip theory based approach is used to compute the first order hydrodynamic coefficients. The type and properties of the wave spectrum is specified by the user. The program calculates the six motion components for every time step. Second order wave forces are calculated by using the following semi-empirical formulae Longitudinal drift force
T H 2.5 D 0.311ρgB 2 11/ 3.5 1 ω em X 0.0388ρgBC B H 12/ 3 sin 2 L 2H 1 / 3 Lateral drift force
T 1 ω em sin β Y 0.388ρgLH12/ 3 sin 2 2 H 1 / 3
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T 1 ω em cos β sin β 0.03YL N 0.125ρgLTH12/ 3 sin 2 2 H 1 / 3 where L
: Length
B
: Breadth
T
: Draught
H1/3
: Significant wave height
β
: Wave heading
ω em
: Modal encounter frequency
g
: Gravitational acceleration
Each sea state is mathematically represented by a JONSWAP wave spectrum. Significant Wave Height (HS)
Modal Wave Period (TM)
1.20 m
4.52 s
5.00 m
10.19 s
6. MOORING ANALYSES (INTACT) © Commercially
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This section presents the results of the intact mooring analysis for the maximum allowable and survival environmental conditions. The environmental conditions are selected as follows:
Maximum Allowable Conditions Significant Wave Height
: 1.2 m
Wind Speed
: 13 m/s
Current Velocity
: 0.9 m/s
Survivability Conditions Significant Wave Height
: 5.0 m
Wind Speed
: 29 m/s
Current Velocity
: 1.2 m/s
For the analyses presented in this section all the mooring lines are assumed intact. As a worst case scenario the direction of wind, waves and current are assumed to be the same and the following directions resulting in a 3600 coverage are taken into consideration. North, North-East (North-West), East, South-East (South-West), South The results are presented in tabular and graphical format for each direction and environmental condition. Mooring simulations and load predictions were carried out by using the ITU-MOOR software which is developed at Istanbul Technical University. Typical input-output files are presented in the Appendix.
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LINE 7
18
LINE 8
LINE 1
LINE 2
LINE 6 LINE 5
LINE 3 LINE 4
Figure 6.2. Mooring lines for Installation 4 MODULE 3 configuration.
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Distances between the fairleads and the anchor positions and initial tension applied on each anchor line are as follows: Line No
İnitial tension (kN)
1
Distance between fairlead and anchor (m) 641
2
625
120
3
601
140
4
584
140
5
680
160
6
621
150
7
678
140
8
718
110
100
Line 1, 7 and 8 crosses pipelines at two points as shown below:
1st pipeline crossing from fairlead (m)
LINE 1 Distance (m) 153
LINE 7 Distance (m) 157
LINE 8 Distance (m) 124
2nd pipeline crossing from fairlead (m)
388
465
555
Anchor from fairlead (m)
641
678
718
The initial catenaries for each mooring line are presented in the following figures:
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Line No 1
Distance between fairlead and anchor (m) 641
İnitial tension (kN) 100
20
Remaining Line on Ground (m) 106
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400
500
600
x (m)
Line No 2
Distance between fairlead and anchor (m) 625
İnitial tension (kN) 120
Remaining Line on Ground (m) 436
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300 x (m)
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500
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Line No 3
Distance between fairlead and anchor (m) 601
İnitial tension (kN) 140
21
Remaining Line on Ground (m) 397
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400
500
x (m)
Line No 4
Distance between fairlead and anchor (m) 584
İnitial tension (kN) 140
Remaining Line on Ground (m) 380
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300 x (m)
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400
500
600
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Line No 5
Distance between fairlead and anchor (m) 680
İnitial tension (kN) 160
22
Remaining Line on Ground (m) 462
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400
500
600
x (m)
Line No 6
Distance between fairlead and anchor (m) 621
İnitial tension (kN) 150
Remaining Line on Ground (m) 442
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300 x (m)
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400
500
600
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Line No 7
Distance between fairlead and anchor (m) 678
İnitial tension (kN) 140
23
Remaining Line on Ground (m) 34
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400
500
600
x (m)
Line No 8
Distance between fairlead and anchor (m) 718
İnitial tension (kN) 110
Remaining Line on Ground (m) 36
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400 x (m)
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500
600
700
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Maximum Operational Allowable Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
North
13
0.9
1.2
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
62
47
71
103
238
239
219
144
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Maximum Operational Allowable Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
North-East
13
0.9
1.2
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
122
130
132
117
144
148
157
134
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Maximum Operational Allowable Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
East
13
0.9
1.2
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
98
184
236
229
121
80
49
41
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Maximum Operational Allowable Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
South-East
13
0.9
1.2
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
119
232
281
253
89
47
23
28
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Maximum Operational Allowable Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
South
13
0.9
1.2
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
143
208
220
180
92
75
72
79
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Maximum Operational Allowable Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
SouthWest
13
0.9
1.2
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
76
101
137
156
185
163
136
94
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Maximum Operational Allowable Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
West
13
0.9
1.2
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
101
66
63
68
201
229
248
190
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Maximum Operational Allowable Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
NorthWest
13
0.9
1.2
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
60
26
41
73
262
261
272
180
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SUMMARY OF MOORING LOADS FOR LOAD CASE 3 Maximum Operational Allowable Condition Load Case Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
13
0.9
1.2
MODULE3 Direction
Mooring Loads (kN) Line 1 62
North
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
47
71
103
238
239
219
144
NorthEast
122
130
132
117
144
148
157
134
East
98
184
236
229
121
80
49
41
SouthEast
119
232
281
253
89
47
23
28
South
143
208
220
180
92
75
72
79
SouthWest
76
101
137
156
185
163
136
94
West
101
66
63
68
201
229
248
190
NorthWest
60
26
41
73
262
261
272
180
Based on the above analyses maximum mooring loads are estimated as follows: INSTALLATION 4 MODULE 3
Maximum Operational Allowable Condition
Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
Load (kN)
143
232
281
253
262
261
272
190
Direction
S
SE
SE
SE
NW
NW
NW
W
Mooring line catenaries for the maximum operational allowable condition are presented in the following figures:
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Line No 1
Distance between fairlead and anchor (m) 641
Maximum operational allowable tension (kN) 143
33
Remaining Line on Ground (m) 76
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400
500
600
x (m)
Line No 2
Distance between fairlead and anchor (m) 625
Maximum operational allowable tension (kN) 232
Remaining Line on Ground (m) 361
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300 x (m)
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Line No 3
Distance between fairlead and anchor (m) 601
Maximum operational allowable tension (kN) 281
34
Remaining Line on Ground (m) 311
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400
500
600
x (m)
Line No 4
Distance between fairlead and anchor (m) 584
Maximum operational allowable tension (kN) 253
Remaining Line on Ground (m) 309
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300 x (m)
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Line No 5
Distance between fairlead and anchor (m) 680
Maximum operational allowable tension (kN) 262
35
Remaining Line on Ground (m) 400
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400
500
600
x (m)
Line No 6
Distance between fairlead and anchor (m) 621
Maximum operational allowable tension (kN) 261
Remaining Line on Ground (m) 413
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400 x (m)
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Line No 7
Distance between fairlead and anchor (m) 678
Maximum operational allowable tension (kN) 272
36
Remaining Line on Ground (m) 3
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400
500
600
x (m)
Line No 8
Distance between fairlead and anchor (m) 718
Maximum operational allowable tension (kN) 190
Remaining Line on Ground (m) 3
40
35
30
z (m)
25
20
15
10
5
0 0
100
200
300
400 x (m)
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Survival Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
North
29
1.2
5.0
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
105
0
0
0
333
494
637
468
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Survival Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
North-East
29
1.2
5.0
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
383
314
149
13
0
63
206
306
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Survival Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
East
29
1.2
5.0
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
312
537
478
281
0
0
0
24
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Survival Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
South-East
29
1.2
5.0
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
41
576
1019
1019
264
7
0
0
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Survival Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
South
29
1.2
5.0
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
140
476
639
546
1
0
0
0
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Survival Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
SouthWest
29
1.2
5.0
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
0
27
208
396
354
188
26
0
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Survival Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
West
29
1.2
5.0
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
0
0
0
22
526
568
489
245
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Survival Condition Load Case
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
MODULE3
NorthWest
29
1.2
5.0
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
0
0
0
0
747
811
676
302
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Survival Condition Load Case Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
29
1.2
5.0
MODULE 3 Direction
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
North
105
0
0
0
333
494
637
468
NorthEast
383
314
149
13
0
63
206
306
East
312
537
478
281
0
0
0
24
SouthEast
41
576
1019
1019
264
7
0
0
South
140
476
639
546
1
0
0
0
SouthWest
0
27
208
396
354
188
26
0
West
0
0
0
22
526
568
489
245
NorthWest
0
0
0
0
747
811
676
302
Based on the above analyses maximum mooring loads are estimated as follows: INSTALLATION 4 MODULE 3
Survival Condition
Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
Load (kN)
383
576
1019
1019
747
811
676
468
Direction
NE
SE
SE
SE
NW
NW
NW
N
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7. MOORING ANALYSIS (DAMAGED) This section presents the results of the damaged mooring analyses for the maximum allowable condition. One of the eight mooring lines is assumed to be broken and the mooring loads are calculated for the worst direction and load case as follows: Maximum mooring loads during installation of MODULE 3 for the operational allowable condition are predicted as follows:
INSTALLATION 4 MODULE 3
Maximum Operational Allowable Condition
Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
Load (kN)
143
232
281
253
262
261
272
190
Direction
S
SE
SE
SE
NW
NW
NW
W
As seen in the table maximum mooring loads should be expected on Line 3 in the South East direction. Therefore, Line 3 is assumed to be broken and mooring loads are calculated as follows:
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INSTALLATION 4 MODULE 3
47
Maximum Operational Allowable Condition
Damaged Line
Direction
Wind Speed (m/s)
Current (m/s)
Sig. Wave Height (m)
LINE 3
SouthEast
13
0.9
1.2
Mooring Loads (kN) Line 1
Line 2
Line 3
Line 4
Line 5
Line 6
Line 7
Line 8
143
84
-
331
70
15
213
205
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8. API RP 2SK REQUIREMENTS In accordance with the API RP 2SK (American Petroleum Institute - Design and Analysis of Station Keeping Systems for Floating Structures) regulations a tension limit can be expressed as a percentage of the minimum breaking strength (MBS) of the mooring component. MBS is defined as the breaking strength guaranteed by the mooring component manufacturer. Tension limits and equivalent safety for various conditions are provided in Table 8.1. Table 8.1. Tension limits and safety factors
Intact
Tension Limit (Percent of MBS) 50
Equivalent Factor of Safety 2.0
Damaged
70
1.43
Based on the results of the intact and damaged mooring analyses maximum mooring loads are estimated as follows:
Loading Condition
Line No
Direction
Mooring Load [kN]
Maximum Operational Allowable Condition (INTACT)
4
South East
281
Maximum Operational Allowable Condition (DAMAGED)
3
South East
331
Survival
4
South East
1019
The mooring system consists of 8 x 1000 m steel wire ropes of 44 mm diameter. Weight and strength characteristics of the mooring lines are as follows: Type
OD (mm)
MBS (kN)
Length (m)
Weight (kg/m)
Submerged Weight (kg/m)
Wire Rope
44
1500
1000
9.78
8.15
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In the following tables maximum mooring loads are compared with the tension limits recommended by API RP 2SK. Maximum Operational Allowable Condition (INTACT) Significant Wave Height
: 1.2 m
Wind Speed
: 13 m/s
Current Velocity
: 0.9 m/s
LINE NO
Max Mooring Load (kN)
MBS (kN)
Tension Limit (% of MBS)
Tension Limit (kN)
Max Tension (% of MBS)
API RP 2SK Satisfied?
Line 3
281
1500
50
750
18.7
YES
Maximum Operational Allowable Condition (DAMAGED) Significant Wave Height
: 1.2 m
Wind Speed
: 13 m/s
Current Velocity
: 0.9 m/s
LINE NO
Max Mooring Load (kN)
MBS (kN)
Tension Limit (% of MBS)
Tension Limit (kN)
Max Tension (% of MBS)
API RP 2SK Satisfied?
Line 4
331
1500
70
1050
22.1
YES
Survival Condition (INTACT) Significant Wave Height
: 5.0 m
Wind Speed
: 29 m/s
Current Velocity
: 1.2 m/s
LINE NO
Max Mooring Load (kN)
MBS (kN)
Tension Limit (% of MBS)
Tension Limit (kN)
Max Tension (% of MBS)
API RP 2SK Satisfied?
Line 4
1019
1500
100
1500
67.9
YES
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9. CONCLUSIONS This report presents the results of a mooring analysis study for the 1600 T PONTOON CRANE CAPTAIN LYCHKIN INSTALLATION 4 MODULE 3 in which a mooring layout is developed and analyzed in accordance with the rules and recommendations of API RP 2SK (American Petroleum Institute - Design and Analysis of Station Keeping Systems for Floating Structures). Based on the results of the intact and damaged mooring analyses maximum mooring loads for the maximum operational allowable condition and survival condition are estimated and compared with the limiting values recommended API RP 2SK as follows: The results presented in the tables clearly show that all strength criteria for the maximum operational allowable condition recommended by API RP 2SK are satisfied for each mooring line. Furthermore, as shown in Section 8, the mooring system has sufficient strength in survival conditions. Each mooring line is connected to a 10 ton HYD-14 HHP type anchor with an average holding capacity of 140 t in soft clay. Therefore each mooring line has a holding capacity of at least 1500 kN (anchor + wire rope), which is sufficient for the worst loading condition.
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APPENDIX TYPICAL INPUT / OUTPUT FILES FOR ITU-MOOR MOORING ANALYSIS SOFTWARE
******************************************* M O O R I N G S I M U L A T I O N
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1600 T PONTOON CRANE CAPTAIN LYCHKIN ******************************************* LOADING CONDITION
: LC3
--------------------------------------------------------M A I N P A R T I C U L A R S --------------------------------------------------------LENGTH (M) = 99.6 BREADTH (M) = 35.0 DRAUGHT (M) = 4.082 DISPLACEMENT (T) = 13312.4 LONG WIND AREA (M2) = 734.0 LAT WIND AREA (M2) = 1512.0 ----------------------------------------------------------------------------------------------------------------HEADING AND SHIP FAIRLEAD POSITIONS --------------------------------------------------------HEADING = 225. --------------------------------------------------------X Y --------------------------------------------------------1 43.107 27.376 2 44.818 20.008 3 -12.461 -37.263 4 -15.007 -39.809 5 -39.811 -15.002 6 -37.265 -12.456 7 20.014 44.815 8 27.382 43.103 ----------------------------------------------------------------------------------------------------------------A N C H O R P O S I T I O N S --------------------------------------------------------ANCHOR NO X Y --------------------------------------------------------ANCHOR 1 605.928 335.249 ANCHOR 2 661.324 -86.672 ANCHOR 3 358.082 -489.815 ANCHOR 4 -30.872 -640.607 ANCHOR 5 -660.802 -32.869 ANCHOR 6 -630.558 320.600 ANCHOR 7 -239.051 671.620 ANCHOR 8 132.507 753.438 ----------------------------------------------------------------------------------------------------------------MOORING LINE ANGLE AND DISTANCE --------------------------------------------------------LINE NO ANGLE [DEG] DISTANCE [M] --------------------------------------------------------LINE 1 28.680 641.524 LINE 2 -9.817 625.668 LINE 3 -50.691 584.897 LINE 4 -91.514 601.008 © Commercially
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LINE 5 -178.355 621.248 LINE 6 150.694 680.384 LINE 7 112.458 678.233 LINE 8 81.583 718.071 ----------------------------------------------------------------------------------------------------------------L I N E I N F O R M A T I O N --------------------------------------------------------LINE WATER LINE WEIGHT INITIAL NO DEPTH LENGTH DIAMETER PER M TENSION [M] [M] [MM] [KN] [KN] --------------------------------------------------------LINE 1 20.0 647.1 44.0 79.923 100.0 LINE 2 20.0 632.2 44.0 79.923 120.0 LINE 3 20.0 592.2 44.0 79.923 140.0 LINE 4 20.0 608.3 44.0 79.923 140.0 LINE 5 20.0 629.3 44.0 79.923 160.0 LINE 6 20.0 688.1 44.0 79.923 150.0 LINE 7 20.0 685.5 44.0 79.923 140.0 LINE 8 20.0 724.1 44.0 79.923 110.0 ----------------------------------------------------------------------------------------------------------------INITIAL TENSION COMPONENTS --------------------------------------------------------LINE NO TX [KN] TY [KN] TN [KNM] --------------------------------------------------------LINE 1 -28.1 -96.0 -4779.4 5.6 LINE 2 -98.1 -69.1 -3443.6 6.5 LINE 3 -139.3 13.9 690.7 7.3 LINE 4 -96.4 101.6 5058.0 7.3 LINE 5 109.8 116.4 5794.3 8.1 LINE 6 144.4 40.6 2020.8 7.7 LINE 7 129.3 -53.7 -2672.6 7.3 LINE 8 65.6 -88.3 -4398.7 6.1 --------------------------------------------------------TOTAL 87.3 -34.7 -1730.4 ----------------------------------------------------------------------------------------------------------------L I N E T E N S I O N S [K N] ----------------------------------------------------------------------------------------------------------------------------------------HEADING LINE1 LINE2 LINE3 LINE4 LINE5 LINE6 LINE7 LINE8 --------------------------------------------------------------------------------0. 0.000 0.000 0.000 22.030 525.988 568.157 488.696 245.251 45. 0.000 26.770 208.023 396.035 354.098 188.192 25.998 0.000 90. 139.943 476.253 638.521 546.104 1.085 0.000 0.000 0.000 135. 41.466 575.781 1018.737 1019.412 7.024 0.000 0.000 0.000 180. 312.119 537.362 477.502 280.849 0.000 0.000 0.000 23.813 225. 382.829 313.648 148.716 13.477 0.000 62.863 205.929 305.772 270. 104.572 0.000 0.000 0.000 333.385 493.658 636.838 468.255 315. 0.000 0.000 0.000 0.000 746.749 810.864 675.941 302.344
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