COMMONWEALTH OF AUSTRALIA
Section 708
Offshore Petroleum and Greenhouse Gas Storage Act 2006
APPLICATION FOR GRANT OF A PIPELINE LICENCE (GERYON TO JANSZ-IO PIPELINE) – OFFSHORE AREA OF WESTERN AUSTRALIA
I, STEVEN ROBERT TAYLOR, Delegate of the National Offshore Petroleum Titles Administrator, on behalf of the Commonwealth–Western Australia Offshore Petroleum Joint Authority hereby give notice pursuant to section 708 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 that an application has been received from
Chevron Australia Pty Ltd
(ACN 086 197 757)
Mobil Australia Resources Company Pty Limited
(ACN 000 113 217)
Shell Australia Pty Ltd
(ACN 009 663 576)
Osaka Gas Gorgon Pty Ltd
(ACN 139 074 847)
MidOcean Gorgon Pty Ltd
(ACN 138 592 042)
JERA Gorgon Pty Ltd
(ACN 140 107 464)
for the grant of a pipeline licence for the conveyance of petroleum in the offshore area of Western Australia, as set out below.
A person may make a written submission to the Titles Administrator about this application within 30 days from the date of this notice.
This notice takes effect on the day in which it appears in the
Australian Government Gazette.
Made under the Offshore Petroleum and Greenhouse Gas Storage Act 2006
of the Commonwealth of Australia.
STEVEN ROBERT TAYLOR
DELEGATE OF THE TITLES ADMINISTRATOR
ON BEHALF OF THE COMMONWEALTH-WESTERN AUSTRALIA
OFFSHORE PETROLEUM JOINT AUTHORITY
ROUTE OF THE PIPELINE
The pipeline route for the system of pipes is described in the tables hereunder and displayed in the attached map (Attachment 1). The production flowline commences at the Geryon and Eurytion (GE) Pipeline End Termination (PLET) Hub Face, where the GE-1B, GE-1C, GE-1D, GE-1E, GE-1F, GE-1G, GE Manifold (M)-1, GE M-2 and Pipeline Termination Structure (PTS) ties back into, ending at the Backfill Manifold (BFM) PLET Hub Face where the BFM and Subsea Compression Manifold (SCMS) ties back into. The Mono Ethylene Glycol (MEG) Pipeline commences at the GE MEG Pipeline End Termination Manifold (PLEM) Hub Face and ends at the Jansz Drill Centre (DC)-2 PLEM Hub Face. The umbilical commences at the Umbilical Termination Assembly (UTA) Centre and ends at the Field Control Station (FCS) J-Tube End. Coordinates are based on Geodetic Datum of Australia (GDA94)/MGA Zone 50.
Tie-In to GE DRILL CENTRE | ||
Feature Name | Easting (mE) | Northing (mN) |
GE PRODUCTION PLET | 278 691 | 7 793 872 |
GE PTS | 278 706 | 7 793 790 |
GE M-1 PRODUCTION | 278 623 | 7 793 801 |
GE M-2 PRODUCTION | 278 749 | 7 793 719 |
GE-1B | 278 570 | 7 793 761 |
GE-1C | 278 603 | 7 793 767 |
GE-1D | 278 610 | 7 793 737 |
GE-1E | 278 694 | 7 793 680 |
GE-1F | 278 724 | 7 793 685 |
GE-1G | 278 734 | 7 793 657 |
Tie-In to SCMS | |||
Feature Name | KP* | Easting (mE) | Northing (mN) |
BFM PLET HUB FACE | 35.46 | 249 293 | 7 808 015 |
BFM | - | 249 263 | 7 807 933 |
Adjacent to SCMS | - | 249 266 | 7 807 878 |
GE UMBILICAL – GE DC TO FCS | |||
Feature Name | KP* | Easting (mE) | Northing (mN) |
GE UTA CENTRE | 0 | 278 570 | 7 793 660 |
TP-01A | - | 276 225 | 7 795 185 |
TP-01B | - | 276 057 | 7 795 285 |
TP-02A | - | 274 951 | 7 795 887 |
TP-02B | - | 274 107 | 7 796 167 |
TP-03A | - | 260 035 | 7 798 163 |
TP-03B | - | 259 868 | 7 798 181 |
TP-04A | - | 255 739 | 7 798 485 |
TP-04B | - | 255 515 | 7 798 492 |
TP-05A | - | 252 891 | 7 798 449 |
TP-05B | - | 252 815 | 7 798 454 |
TP-06A | - | 252 471 | 7 798 502 |
TP-06B | - | 251 937 | 7 798 751 |
TP-07A | - | 251 531 | 7 799 120 |
TP-07B | - | 251 426 | 7 799 193 |
STATIC / DYNAMIC TRANSITION
| 28.8 | 250 906 | 7 799 463 |
FCS J-TUBE END | 30.279 | 249 594 | 7 800 146 |
GE MEG PIPELINE – GE DC TO JANSZ DC-2 | |||
Feature Name | KP* | Easting (mE) | Northing (mN) |
GE MEG PLEM HUB FACE | 0 | 278 652 | 7 793 642 |
TP-01A | - | 276 269 | 7 795 192 |
TP-01B | - | 276 000 | 7 795 353 |
TP-02A | - | 273 638 | 7 796 638 |
TP-02B | - | 273 146 | 7 796 955 |
TP-03A | - | 269 874 | 7 799 416 |
TP-03B | - | 269 583 | 7 799 616 |
TP-04A | - | 262 207 | 7 804 206 |
TP-04B | - | 262 130 | 7 804 255 |
TP-05A | - | 261 375 | 7 804 749 |
TP-05B | - | 261 234 | 7 804 846 |
TP-06A | - | 260 752 | 7 805 192 |
TP-06B | - | 260 555 | 7 805 324 |
TP-07A | - | 259 208 | 7 806 174 |
TP-07B | - | 258 770 | 7 806 413 |
TP-08A | - | 257 188 | 7 807 154 |
TP-08B | - | 256 602 | 7 807 491 |
TP-09A | - | 255 305 | 7 808 393 |
TP-09B | - | 255 195 | 7 808 467 |
JANSZ DC-2 PLEM HUB FACE | 30.126 | 253 233 | 7 809 735 |
GE PRODUCTION PIPELINE – GE DC TO SCMS | |||
Feature Name | KP* | Easting (mE) | Northing (mN) |
GE PLET HUB FACE | 0 | 278 692 | 7 793 872 |
BI-01 | - | 276 596 | 7 795 235 |
BI-02 | - | 275 228 | 7 796 405 |
BI-03 | - | 272 965 | 7 797 877 |
BI-04 | - | 270 685 | 7 799 827 |
BI-05 | - | 268 170 | 7 801 463 |
TP-01A | - | 267 114 | 7 802 366 |
TP-01B | - | 266 950 | 7 802 514 |
TP-02A | - | 265 687 | 7 803 722 |
TP-02B | - | 265 310 | 7 804 040 |
TP-03A | - | 263 368 | 7 805 484 |
TP-03B | - | 263 033 | 7 805 709 |
TP-04A | - | 262 058 | 7 806 291 |
TP-04B | - | 261 468 | 7 806 721 |
TP-05A | - | 260 612 | 7 807 474 |
TP-05B | - | 260 467 | 7 807 596 |
TP-06A | - | 259 981 | 7 807 984 |
TP-06B | - | 259 935 | 7 808 020 |
TP-07A | - | 259 312 | 7 808 503 |
TP-07B | - | 258 675 | 7 808 907 |
TP-08A | - | 257 645 | 7 809 431 |
TP-08B | - | 257 455 | 7 809 534 |
TP-09A | - | 256 702 | 7 809 970 |
TP-09B | - | 252 788 | 7 810 023 |
BFM PLET HUB FACE | 35.46 | 249 293 | 7 808 015 |
* Kilometre Point
SPECIFICATIONS
Design and Construction
The offshore pipeline and rigid spools/jumpers shall be designed and constructed in accordance with Industry Standard DNV-ST-F101 - Submarine Pipeline Systems, whereas the flexible jumpers of the production system shall be designed and constructed in accordance with API Specification 17J - Specification for Unbonded Flexible Pipe.
The system design life is variable, with flexible and rigid jumpers from Xmas Trees to GE PTS designed for 25 years, and the other Linepipe items from GE PTS to compression manifold (SCMS) designed for 40 years.
For erosional velocity, an erosion assessment was performed using the methodology described in DNV-RP-0501.
Basis of Design
The pipeline design shall be designed with the following parameters:
Item | From | To | Material and Grade | Min. Yield Strength (MPa) | Nominal Diameter (mm) | Joints (Note 4) | Nominal Wall Thickness (mm) | Corrosion Allowance (mm) | Coating (mm) | Design Pressure (barg) | Max. Operating Temp. (°C) | Design Temp. (°C) | Length (m) |
Flexible Jumper | XT | Prod. Manifold | Smooth Carcass: AISI 316L | N/A | ID 203.2 | N/A | N/A | N/A | N/A | 335 | 64 | -25 to 80 | 876 (6x 146) |
Rigid Jumper | Prod. Manifold | GE PTS | CRA 625 clad pipe CS: DNV MWPL 450 C FDU CRA: UNS N06625 | 450 | ID 350 | N/A | CS: 19.2 CRA: 3.0 | 0.0 | TSA: 0.25 | 335 | 64 | -20 to 80 | 252 (2x 126) |
Rigid Spool | GE PTS | GE PLET | CRA 625 clad pipe CS: DNV MWPL 450 C FDU CRA: UNS N06625 | 450 | ID 550 | N/A | CS: 40.0 CRA: 3.9 | 0.0 | TSA: 0.25 | 284 | 64 | -10 to 75 | 125 |
Prod. Flowline | GE PLET | GE PLET (TBC) | CRA 625 clad stress joint CS: DNV MWPL 450 C FDU CRA: UNS N06625 | 450 | ID 550 | TBC (Note 2) | CS: 40.0 CRA: 3.9 | 0.0 | FBE: 0.6 | 284 | 64 | -5 to 75 | TBC (Note 3) |
GE PLET (TBC) | KP 0.140 | CRA 625 clad pipe CS: DNV MWPL 450 C FDU CRA: UNS N06625 | Note 3 | CS: 28.1 CRA 625: 3.0 | 0.0 | FBE: 0.6 |
| 130 (minimum) | |||||
KP 0.140 | KP 1.010 | CRA 316L clad pipe CS: DNV MWPL 450 C FDU CRA: UNS S31603 | 68 | CS: 28.1 CRA 316L: 3.0 | 0.0 | FBE: 0.6 (Note 1) | 64 | 870 | |||||
KP 1.010 | KP 4.010 | Heavy WT CS pipe DNV SAWL 450 FDU | 250 | 34.6 | 6.0 | 3LPP: 3.8 | 50 | 3 000 | |||||
KP 4.010 | KP 35.340 | Standard WT CS pipe DNV SAWL 450 FDU | 2 603 | 32.3 | 3.0 | 3LPP: 3.8 | 45 | 31 330.00 | |||||
KP 35.340 | BFM PLET (TBC) | CRA 625 clad pipe CS: DNV MWPL 450 C FDU CRA: UNS N06625 | Note 3 | CS: 28.1 CRA 625: 3.0 | 0.0 | FBE: 0.6 | 12 | 109.8 (minimum) | |||||
BFM PLET (TBC) | BFM PLET | CRA 625 clad stress joint CS: DNV MWPL 450 C FDU CRA: UNS N06625 | TBC (Note 2) | CS:40.0 CRA: 3.9 | 0.0 | FBE: 0.6 | 12 | TBC (Note 2) | |||||
Rigid Spool | BFM PLET | BFM | CRA 625 clad pipe CS: DNV MWPL 450 C FDU CRA: UNS N06625 | 450 | ID 550 | N/A | CS: 40.0 CRA: 3.9 | 0.0 | NORSOK M501 System 7C: 0.35 | 284 | 12 | -20 to 50 | 109 |
Rigid Spool – Compression | BFM | SCMS | CRA 625 clad pipe CS: DNV MWPL 450 C FDU CRA: UNS N06625 | 450 | ID 550 | N/A | CS: 40.0 CRA: 3.9 | 0.0 | NORSOK M501 System 7C: 0.35 | 284 | 12 | -10 to 50 | 106 |
Rigid Spool – Bypass | BFM | SCMS | CRA 625 clad pipe CS: DNV MWPL 450 C FDU CRA: UNS N06625 | 450 | ID 550 | N/A | CS: 40.0 CRA: 3.9 | 0.0 | NORSOK M501 System 7C: 0.35 | 284 | 12 | -10 to 50 | 91 |
General note: List is not including CRA/CS transition joints and/or bends.
Note 1: CRA clad pipe is coated with dual layer FBE, however last 3 joints of 316L clad pipe before CRA/CS transition is coated with thick 3LPP / multi-layer solid polypropylene (MLSPP) to reduce U-value.
Note 2: PLET stress joint length to be defined after PLET design completion, which is on hold of pipeline installation's contractor award.
Note 3: Total amount of joint for CRA 625 clad pipe is 21, to be divided in both ends of the Linepipe.
Note 4: Joint quantities are approximate based on base quantity defined in MTO and represent a best estimate, as installation considerations may affect the final count.
Item | From | To | Design Capacity (MMscfd) | Inlet and outlet facilities | Fitting, valve and flange specifications | Fluid to be transported | Pigging facilities | Cathodic protection (Note 2) | Hydrate Management | |
Type | Quantity (units) | |||||||||
Flexible Jumper | XT | Prod. Manifold | Note 1 | Inlet 6x XTs: Shut In Tubing Head Pressure varying from 27.7 and 27.9 MPa
Outlet Maximum operating pressure: 19.0 MPa SCMS Design Pressure: 28.4 MPa | End fitting (Termination Hub Connector 10H82) designed in accordance with API 17J | Wet hydrocarbon gas and condensate | No pigging facilities - for pigging strategy, refer to Pigging Strategy [GS3-US00-UFA-PLN-WOR-000-00001-00] | Aluminium-zinc-indium alloy bracelet anodes | 24 in total (4 in each jumper) | Use of Monoethylene Glycol (MEG) as hydrate inhibitor. Same approach being used in existing system. |
Rigid Jumper | Prod. Manifold | GE PTS | 1420 | UCON-H-14 Connectors: designed and manufactured in accordance with ISO-12628-4 / API 17D and ISO 10423 / API 5 (PSL 3 and PSL 3G) and API RP 17R | 4 in total (2 in each jumper) | |||||
Rigid Spool | GE PTS | GE PLET | Stabcon Connectors: designed by API 6A / 17D (predominant design codes) | 3 | ||||||
Production Flowline | GE PLET | GE PLET (TBC) | N/A | 1 anode every 3 joints with additional 2 off anodes at beginning of pipeline to cover unspecified current drain | ||||||
GE PLET (TBC) | KP 0.140 | 1 anode every 3 joints with additional 2 off anodes at beginning of pipeline to cover unspecified current drain | ||||||||
KP 0.140 | KP 1.010 | 1 anode every 3 joints with additional 2 off anodes at beginning of pipeline to cover unspecified current drain | ||||||||
KP 1.010 | KP 4.010 | 1 anode every 38 joints - no anodes within 150m either side of buckle initiators | ||||||||
KP 4.010 | KP 35.340 | 1 anode every 38 joints - no anodes within 150m either side of buckle initiators | ||||||||
KP 35.340 | BFM PLET (TBC) | 1 anode every 2 joints with additional 2 off anodes at end of pipeline to cover unspecified current drain | ||||||||
BFM PLET (TBC) | BFM PLET | 1 anode every 2 joints with additional 2 off anodes at end of pipeline to cover unspecified current drain | ||||||||
Rigid Spool | BFM PLET | BFM | Stabcon Connectors: designed by API 6A / 17D (predominant design codes) | 5 | ||||||
Rigid Spool – Compression | BFM | SCMS | Stabcon Connectors: designed by API 6A / 17D (predominant design codes) | 4 | ||||||
Rigid Spool – Bypass | BFM | SCMS | Stabcon Connectors: designed by API 6A / 17D (predominant design codes) | 5 | ||||||
General note: List is not including CRA/CS transition joints and/or bends.
Note 1: Design capacity for flexible jumpers is defined per temperature and pressure they are design for, and the maximum flowrate assessed in erosion analysis (320 MMscfd for a period of 1.5 years).
Note 2: For details of how the condition of the anodes will be monitored and tested, refer to Cathodic Protection Offshore Survey Specification [SSF-UG00-UFR-SPC-CVX-000-00010-00].
The following items are not applicable to this scope: mainline valves, compressor stations and Pump stations, tank stations or valve stations.
Attachment 1