z00b Ti Cal 1 0552-04-09 Lychkin Mooring Module3

November 26, 2017 | Author: Akbar | Category: Naval Architecture, Wound, Hull (Watercraft), Waves, Analysis
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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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ILK CONSTRUCTION – 1600 T PONTOON CRANE CAPTAIN LYCHKIN INSTALLATION 4 MODULE 3 MOORING ANALYSES

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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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4

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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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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ILK CONSTRUCTION – 1600 T PONTOON CRANE CAPTAIN LYCHKIN INSTALLATION 4 MODULE 3 MOORING ANALYSES

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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400

500

600

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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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29

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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31

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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38

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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39

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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40

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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41

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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44

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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48

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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49

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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50

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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53

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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