Application for Variation of a Pipeline Licence – Pipeline Licence WA-19-PL

Feature Name

Easting

(MGA Zone 50)

Northing

(MGA Zone 50)

Flange to Midline PTS

249362

7807828

PLET

249457

7807821

KP 10

254116

7798972

KP 20

260468

7791274

KP 30

267052

7783748

KP 40

271134

7774693

KP 50

275464

7765750

KP 60

280958

7757417

KP 70

286466

7749082

Wheatstone Trunkline Crossing

289217

7744688

KP 80

291774

7740607

KP 90

297086

7732134

Halyard Umbilical Crossing

297081

7732142

KP 100

303484

7724625

KP 110

312658

7720690

KP 120

321786

7716617

East Spar Crossing

328757

7714025

Coastal Waters

329766

7713625

General Details

1.

Pipeline Name (meaningful to industry):

Jansz Commonwealth Waters Pipeline

2.

Start Point Description:

Midline PTS

3.

‘Start’ Point of Pipeline Coordinates (GDA94):

a)      Northing:

b)     Easting:

a)       Northing: 7807835 mN

b)      Easting: 249351 mE

4.

End Point Description:

3 Nm seaward of MLW

5.

‘End’ Point of Pipeline Coordinates (GDA94):

a)      Northing:

b)     Easting:

a)       Northing: 7713625 mN

b)      Easting: 329766 mE

6.

Substance to be Conveyed:

Wet Natural Gas

7.

Characteristics of Substance to be Conveyed:

a)      Gas Composition:

b)     Oil Viscosity (centistokes):

c)      Flashpoint of Oil:

d)     Operating Temperature Range °C

a)        Gas Composition

b)           N/A

c)            N/A

d)           -2 to 24 °C

Design Details

8.

Pipe Dimensions

a)      Outside Diameter (mm):

b)     Length of Pipeline (km):

a)       Outside diameters (mm)

772 mm (KP 0 – 30)

767 mm (KP 30 – 71.68)

862 mm (KP 71.68 – 128.5)

b)       128.6 km

9.

Nominal Wall Thickness

a)      Standard Wall (mm):

b)     Heavy Wall (mm):

a)   Standard Wall:

36.6 mm (KP 0 – 30)

34.2 mm (KP 30 – 71.68)

36.6 mm (KP 53.44 – 54.14)

31.2 mm (KP 71.68 – 128.5)

b)   Heavy Wall: N/A

10.

Joint Type (Welded, Mechanical etc):

Butt welded

11.

Design (at standard conditions)

a)      Initial Design Capacity (TJ/d):

b)     Maximum Design Capacity (TJ/d):

c)      Design Life (Years):

d)     Erosional Velocity (m/s):

a)       1582 MMscf/d

b)       1582 MMscf/d

c)       50 years

d)       30.5 m/s

12.

Pipeline Corrosion Allowance

a)      Internal (mm):

b)     External (mm):

a)       Internal:

4mm (KP 0 – 30)

3.0 mm (KP 30 – 128.6)

      b)  External: 0.0 mm

13.

Pipe Free Span (m) at Location (KP):

To be confirmed at “As Built”

14.

Pipe Steel Specification and Grade:

(a)   Pipeline:

(b)   Riser:

a)       Carbon steel

DNV-OS-F101

DNV SAWL 450 SFDU

b)       N/A

15.

Minimum Yield Strength of Pipe Steel (MPag):

450 MPag

Temperature & Pressure Details

16.

Design Temperature:

a)      Pipeline °C:

b)     Facilities °C:

a)       -7 to 50 °C

b)       N/A

17.

Maximum Operating Temperature

a)      Pipeline °C:

b)     Facilities/Stations °C (Normal):

a)       Pipeline

10° C (KP 0 – 30)

12 °C (KP 30 – 63)

24 °C (KP 63 – 128.6)

b)       Facilities: N/A

18.

Minimum Operating Temperature

a)      Pipeline °C:

b)     Facilities/Stations °C (Normal):

a)       Pipeline

3 °C (KP 0 – 30)

-2 °C (KP 30 – 63)

-1 °C (KP 63 – 128.6)

      b)  Facilities: N/A

19.

Design Pressure (MPag):

28.4 MPag @ 1350 m WD

20.

Inlet Pressure Range (kPag):

8,000 to 16,400 kPag

21.

Outlet Pressure Range (kPag):

8,000 to 16,400 kPag

22.

Field Test Pressure

a)      Proposed Field Test Pressure:

b)     Minimum Field Test Pressure

[  ] x MAOP = [  ] MPag:

a)       30.2 MPag @ 1350 m WD

b)       29.8 MPag @ 1350 m WD

23.

Maximum Allowable Operating Pressure (MAOP)

a)      MPag at      °C for Pipeline:

b)     MPag at      °C for Facilities/Station:

a)       28.4 MPag at maximum operating temperature @ -1350 m WD

b)       N/A

Pipeline Coatings

24.

Protective External Coating Specification and Thickness (mm):

3LPP (KP 0 – 71.68) 2.5 mm thick

FBE (KP 71.68 – 128.6) 0.735 mm thick

25.

Weight Coating Design Specification and Thickness (mm):

AS 1397

90-115 mm

26.

Field Joint Coating:

FBE (KP 0 – 71.68)

FBE + Infill (KP 71.68 – 128.6)

27.

Pipe-to-Pipe Joint Coating|:

FBE (KP 0 – 71.68)

FBE + Infill (KP 71.68 – 128.6)

Control Monitoring

28.

Pressure and Flow Controls Description:

Pipeline isolation shall be via the subsea isolation valves and the pipeline isolation valves located within the pig receiver station at the LNG plant.

29.

Safety and Emergency Shutdown Description:

If an emergency situation occurs that threatens a MODU working above producing subsea facilities (e.g. dropped object), activation of a hand switch or defined loss of communications from the MODU will initiate a MODU ESD. This isolates the Gorgon or Jansz wells and production flowline at the manifold where the MODU is working (the MODU has control of the well it is working on), to minimise any potential consequences. The MODU ESD is transmitted to the Gorgon GTP, isolating all wells on the manifold where the MODU is located.

30.

Telemetry Control:

Fibre-optic cables provide primary communication. Electric power cables provide power to the subsea equipment, and serve as the communications path for the backup copper-based communications system.

31.

Pigging Facilities:

a)      General Facilities:

b)     Description of Pigging Facilities:

a)       Permanent pig receiver is located in the inlet area of the LNG plant. Pig design pressure is 28000 kPag; Pig design temperature is 75 °C (max); -46 °C (min)

b)       Permanent pig receiver will be sized to accommodate the latest generation intelligent pig and shall be capable of launching and receiving.

32.

Provisions for cathodic protection of the pipeline:

Offshore:

Sacrificial anodes

33.

Cathodic Potential Monitoring:

Yes

34.

Cathodic Protection Test Posts:

N/A

Valves & Inline Facilities

35.

Fittings, Valves and Flanges Specifications

a)      Fittings:

b)     Valves:

c)      Flanges:

In accordance with DNV-OS-F101

a)       Fittings: ASMEB16.9

b)       Valves: API 6D, NACE MR0175

c)       Flanges: N/A

36.

Mainline Valves –

a)      Number of:

b)     Type

c)      Location (at KP):

d)     Details of Mainline Valves:

N/A

37.

Location of future Off-take Tees (at KP):

N/A

38.

Number of Pipeline Inlet Facilities:

1

39:

Pipeline Inlet Facilities Description:

Diverless PLET

40.

Number of Pipeline Outlet Facilities:

1

41.

Pipeline Outlet Facilities Description:

Butt Welded

42.

Compressor Stations (if applicable)

a)      Number of:

b)     Location (at KP):

N/A

43.

Other Inline Facilities:

Corrosion monitoring spool prior to inlet to flowline (on the tie-in spool)

Crossings & Pipeline Stabilisation

44.

Location of the crossing:

Crossing locations documented on Jansz Pipeline - Overview of Pipeline Route

45.

Pipeline Crossing Type:

Achieved using pipe supports (mattresses) to cross over Apache East Spar Pipeline. Rock dumped for stabilisation.

46.

Crossings Design Standard:

AS 2885.4

47.

Minimum Earth Cover or Other Means of Stabilisation:

Rock Dump

48.

Anchoring Details:

N/A

Pipeline Management

49.

Environmental Design Criteria Description:

Designed to withstand 100 year return period storm levels; Erosion mitigation measures based on hydrological surveys; Minimised flora disturbance based on vegetation surveys; ROW minimised to restrict land disturbance.

50.

Marine Growth Allowance (mm):

Less than 60 m WD = 30 mm

60 m to 150 m WD = 10 mm

More than 150 m WD = 0mm

51

Risk Management Description:

Gorgon Upstream has a Risk Management Policy aligned to the principles of AS/NZS4360: Risk Management.

Formal safety assessments and risk assessment will be in accordance with AS2885.1.

The Pipeline Risk Management is included in the Formal Safety Assessment; document number G1-NT-REP-J0005.