COMMONWEALTH OF AUSTRALIA
Sections 226 and 708
Offshore Petroleum and Greenhouse Gas Storage Act 2006
APPLICATION FOR VARIATION OF A PIPELINE LICENCE –
PIPELINE LICENCE WA-2-PL
I, GRAEME ALBERT WATERS, the National Offshore Petroleum Titles Administrator, on behalf of the Commonwealth–Western Australia Offshore Petroleum Joint Authority hereby give notice pursuant to sections 226 and 708 of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 that an application has been received from
Woodside Energy Ltd.
(ACN 005 482 986)
Woodside Energy (North West Shelf) Pty Ltd
(ACN 004 514 489)
BP Developments Australia Pty. Ltd.
(ACN 081 102 856)
Chevron Australia Pty Ltd
(ACN 086 197 757)
Japan Australia LNG (MIMI) Pty. Ltd.
(ACN 006 303 180)
Shell Australia Pty Ltd
(ACN 009 663 576)
for the variation of Pipeline Licence WA-2-PL in the offshore area of Western Australia, as set out below.
Pursuant to subsection 226(3) of the Act, 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 on which it appears in the
Australian Government Gazette.
Made under the Offshore Petroleum and Greenhouse Gas Storage Act 2006
of the Commonwealth of Australia.
GRAEME ALBERT WATERS
TITLES ADMINISTRATOR
ON BEHALF OF THE COMMONWEALTH–WESTERN AUSTRALIA
OFFSHORE PETROLEUM JOINT AUTHORITY
APPLICATION FOR VARIATION OF PIPELINE LICENCE WA-2-PL
The application seeks to effect the following amendments to the licence:
- The FIRST SCHEDULE (Route of the Pipeline) is varied by deleting all the current text and replacing with the following:
“The IFL subsea pipeline system starts at the downstream flange of GWA RESDV 31151 and ends at the outboard flange of NRA RESDV 9921. The route of the IFL pipeline commences from the GWA spool / pipeline tie-in flange at 387 907.3 Easting, and 7 826 661.1 Northing and stops at the NRA SSIV tie-in flange at 409 542.1 Easting and 7 834 204.8 Northing as shown in IFL Pipeline Route 199804-SK-001 (Attachment 1). The route includes a tie-in flange interface to 2TL (WA-10-PL) located at 409 251.1 Easting and 7 834 150.1 Northing, and a tie-in flange interface to WCGEL flexible jumper located at 409580.2 Easting and 7834207.5 Northing.”
Pipeline Licence WA-2-PL Feature Points Coordinates | |||||
Feature | Description | KP | Easting (m) | Northing (m) | Depth (m LAT) |
Start | Downstream/outboard flange of GWA riser RESDV 31151 | N/A | - | - | +17.20 |
Flange | GWA SSIV&SSBV assembly / spool tie-in flange | N/A | 387 853.6 | 7 826 676.4 | -126.7 |
Flange | Spool / pipeline tie-in flange | 0.000 | 387 907.3 | 7 826 661.1 | -129.9 |
Tee | 2TL barred tee | 23.031 | 409 250.4 | 7 834 152.2 | -124.6 |
2TL Interface | 2TL tie-in flange | N/A | 409 251.1 | 7 834 150.1 | -124.4 |
Flange | NRA SSIV tie-in flange | 23.348 | 409 542.1 | 7 834 204.8 | -125.1 |
WCGEL Interface | WCGELtie-in interface | N/A | 409 580.2 | 7 834 207.5 | -124.9 |
Flange | NRA riser tie-in flange | 23.439 | 409 583.4 | 7 834 253.7 | -123.1 |
End | Outboard flange of NRA riser RESDV 9921 | N/A | - | - | +18.35 |
2. The SECOND SCHEDULE of the Licence is varied by deleting all the current text and replacing with the following:
SPECIFICATIONS
Design and Construction
Except as otherwise stated in this schedule the pipeline shall be designed, constructed, tested and operated in accordance with the Australian Standard 2885:SAA Gas and Liquid Petroleum Pipelines.
Basis of Design
The pipeline design is based on the following parameters:
Item | Item Description | Details |
1 | Outside diameter of pipe | 762 – 775 mm |
2 | Wall thickness of pipe | 19.1 – 25.4 mm |
3 | Length of pipeline | 23.6 km |
4 | Design life | 45 years The licencee intends to continue operating the GWA-IFL pipeline system for a further 15 years of operation beyond the originally planned end of life. Life extension is confirmed according to ISO/TS 12747. |
5 | Pipeline Steel Grade | API 5L X60 and X65 |
6 | Pipeline Specification | Seam welded |
7 | Joint Type | Butt welded |
8 | Minimum yield strength | 413 and 448 MPa |
9 | Design Pressure | 14.44 MPa |
10 | Maximum operating inlet pressure | 14.2 MPa |
11 | Field test pressure | 18.05 MPa |
12 | Fitting and Valves Specification | ANSI Class 900 |
13 | Water Depths | Maximum: 133 m Minimum: 125 m |
14 | Corrosion Coating | 6 mm Asphalt Enamel coating |
15 | Weight Coating | 45 – 57 mm Concrete |
16 | Inlet Pressure | 12.5 MPa (at Goodwyn ‘A’ and /or North Rankin ‘A’ Platforms) |
17 | Cathodic Protection | Sacrificial Zinc Anodes |
18 | Maximum Inlet Temperature | 45°C (at Goowwyn ‘A’ Platform) 60oC (at North Rankin ‘A’ Platform) |
19 | Minimum Operating Temperature | 18°C |
20 | Characteristics of substance proposed to be conveyed | 2-phase dehydrated natural gas and condensate Maximum gas phase density: 130 kg/m3 Maximum liquid phase density: 750 kg/m3 |
21 | Pipeline Specific Gravity – Minimum | 1.24 |
22 | Pipeline Specific Gravity – Maximum | 1.69 |
23 | Maximum CO2 content Maximum Water content | 3.5 Mol % 75% |
24 | Design Capacity | The maximum flow in the line shall be such that the fluid velocity be limited to the pipe erosional velocity calculated using the latest edition of American Petroleum Institute Recommended Practice 14E. |
Conditions
(A) Pipeline Construction
(i) Pipe-lay Vessel
The pipeline shall be laid from a vessel adequately equipped with anchoring, tensioning, roller stations and stinger facilities to enable the pipeline to be laid safely in the depths encountered.
Before construction commences the licensee shall draw to the attention of all construction personnel the requirements the requirements of the Act, the Directions issued under the Act and the requirements of this licence.
(ii) Waste Disposal
The licensee shall be responsible for ensuring that no materials, other than food scraps or sanitary effluents, are disposed of overboard from the construction vessels.
All materials inadvertently lost or dropped overboard shall be recovered as soon as is reasonably practicable.
(iii) Treated Test Water
Proposals for the disposal of treated water used for testing the pipeline shall be approved by the Director.
(iv) Drying
Proposals for the drying of the pipeline shall be approved by the Director.
(B) Pipeline Route
The licensee shall, during the course of construction cause a precise survey to be made to establish the location of the pipeline. Within three months of completion of the construction of the pipeline the licensee shall lodge a copy of this survey with the Director.
(C) Alterations to Pipeline
The licensee altered the pipeline by inserting a flanged tie-in connection complete with barred tee at 409 250.4 Easting and 7 834 152.2 Northing on Pipeline Licence WA-2-PL as shown in Attachment A.
(D) Interference with Navigation, Fishing, Conservation of Living Resources or Scientific Research
(i) Upon completion of construction of the pipeline, the licensee shall cause a survey to be carried out over an area f 25 metres either side of the surveyed route of the pipeline by means of a sidescan sonar or other method approved by the Director in order to determine the location and nature of any seabed obstructions. Construction debris shall be removed prior to operation of the pipeline or by such other time as is approved by the Director.
(ii) Where the Director requires, the licensee shall make good any damage to the seabed or subsoil of the construction area.
(E) Additional Submissions
Before Construction of the pipeline commences the licensee shall submit, to the Director for his written approval:-
(i) Detail of the marine and diving spreads to be used.
(ii) Evidence that all contractors have been advised of the necessity to comply with the Act, the Directions issued under the Act and the requirements of this licence.
(iii) Instructions to be issued to contractors relating to waste disposal.
(iv) The safety and emergency response manuals covering the operation of the pipe laying marine spread.
(v) A stress analysis showing that the pipeline will not be over-stressed during pipe lay, including the corresponding parameters such as roller arrangement, pipeline tension, and stinger configuration. This analysis shall be verified by a Verifying Body approved by the Director.
(vi) Procedure for corrosion coating of field joints.
Attachment 1