COMMONWEALTH OF AUSTRALIA
Sections 226, 264 and 708
Offshore Petroleum and Greenhouse Gas Storage Act 2006
VARIATION OF PIPELINE LICENCE VIC/PL15
(COBIA TO HALIBUT)
I, STEVEN ROBERT TAYLOR, Delegate of the National Offshore Petroleum Titles Administrator, on behalf of the Commonwealth–Victoria Offshore Petroleum Joint Authority hereby vary Pipeline Licence VIC/PL15 as set out below.
The variation takes effect on the day on which a notice of the variation is published in the Commonwealth 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–VICTORIA
OFFSHORE PETROLEUM JOINT AUTHORITY
- The text of the Renewal of Pipeline Licence on Page 1 is varied by:
- deleting the words:
“and subject to the conditions set out hereunder”
b. deleting the words:
“the renewal of Pipeline Licence VIC/PL15, to have effect for a period of twenty-one (21) years from and including the 20th day of September 1989”.
and replacing with:
“the renewal of Pipeline Licence VIC/PL15, in the offshore area of Victoria, subject to:
a) the conditions set out in this licence;
b) the provisions of the Act; and
c) the provisions of the Regulations;
to construct and operate a pipeline for the conveyance of petroleum, of the design, size and capacity specified herein, along the route specified herein, in relation to the seabed specified herein, and to operate the pumping stations, tank stations and valve stations specified in the positions herein, to have effect from and including the 20th day of September 1989.
The licensee shall at all times comply with the provisions of the Act and Regulations (as amended from time to time).
2. The ‘INTERPRETATION’ on Page 2 of the Licence is varied by deleting the current text under the heading ‘INTERPRETATION’
and
substituting under the heading the following:
“In this document:
“the Act” means the Offshore Petroleum and Greenhouse Gas Storage Act 2006, and includes any Act with which that Act is incorporated, and words used in this document have the same respective meanings as in the Act.
“the Regulations” means regulations made under the Act.
“Pipeline” has the meaning given in the Act.
3. The FIRST SCHEDULE of the Licence is varied by deleting the current text below the heading ROUTE OF PIPELINE
and
substituting under the heading ROUTE OF PIPELINE the following:
ROUTE OF REDUNDANT DN300 STEEL PIPELINE
The route of the pipeline is described in the table below, and displayed in the map below, commencing at the cut spool location at the Cobia platform and terminates at the cut spool location at the Halibut platform. Coordinates are based on Geodetic Datum of Australia (GDA94).
ID | DESCRIPTION | 2D KP | EASTING | NORTHING | Bend Radius (m) |
CBA End | Start of the Redundant DN300 pipeline (cut spool location) | 0.00 | 614227.4 | 5743523.4 |
|
TP1a | Start of curve No 1 | 0.10 | 614153.8 | 5743579.6 | 190 |
IP1 | Intersection Point IP1 | 0.19 | 614114.1 | 5743666.1 | |
TP1b | End of curve No 1 | 0.29 | 614121.1 | 5743760.8 | |
HLA SVS | Halibut Side Valve Assembly | 4.38 | 615232.6 | 5747695.7 |
|
TP2a | Start of curve No 2 | 4.99 | 615400.6 | 5748279.9 | 225 |
IP2 | Intersection Point IP2 | 5.05 | 615400.5 | 5748346.3 | |
Crossing | New DN150 flexible pipeline crossing | 5.10 | 615388.9 | 5748386.5 | |
TP2b | End of curve No 2 | 5.20 | 615330.7 | 5748476.6 | |
HLA End | End of the Redundant DN300 pipeline (cut spool location) | 5.23 | 615311.1 | 5748498.6 |
|
Coordinate set above is based on GDA94 / MGA Zone 55.
ROUTE OF DN150 (6”) FLEXIBLE PIPELINE
The route of the pipeline is described in the table below, and displayed in the map below, commencing at the downstream flange on the Cobia platform riser Last Valve Off (LVO) isolation valve and terminating at the upstream flange to the Halibut platform riser First Valve On (FVO) isolation valve within a 10 metre corridor centered on the pipeline. Coordinates are based on Geodetic Datum of Australia (GDA94).
ID | DESCRIPTION* | 2D KP** | EASTING | NORTHING | Bend Radius (m) |
CBA Riser | Cobia Riser tie-in | 0.00 | 614231.7 | 5743524.1 |
|
TP6b | End of pipeline curve TP6b | 0.0688 | 614170.2 | 5743493.3 | 50 |
IP6 | Intersection Point IP6 |
| 614095.1 | 5743455.7 | |
TP6a | Start of pipeline curve TP6a | 0.1722 | 614097.8 | 5743539.6 | |
TP5b | End of pipeline curve TP5b | 0.3852 | 614104.7 | 5743752.6 | 50 |
IP5 | Intersection Point IP5 |
| 614104.9 | 5743758.7 | |
TP5a | Start of pipeline curve TP5a | 0.3974 | 614106.6 | 5743764.5 | |
TP4b | End of pipeline curve TP4b | 2.4488 | 614664.1 | 5745738.8 | 50 |
IP4 | Intersection Point IP4 |
| 614665.5 | 5745743.8 | |
TP4a | Start of pipeline curve TP4a | 2.4591 | 614666.9 | 5745748.7 | |
TP3b | End of pipeline curve TP3b | 3.5214 | 614945.0 | 5746773.9 | 50 |
IP3 | Intersection Point IP3 |
| 614948.9 | 5746788.4 | |
TP3a | Start of pipeline curve TP3a | 3.5514 | 614953.3 | 5746802.7 | |
TP2b | End of pipeline curve TP2b | 4.0938 | 615110.9 | 5747321.8 | 50 |
IP2 | Intersection Point IP2 |
| 615113.8 | 5747331.2 | |
TP2a | Start of pipeline curve TP2a | 4.1135 | 615116.5 | 5747340.6 | |
Crossings | Crossing of Redundant CBA300 pipeline and HLA100 Fuel Gas pipeline | 5.1574 | 615400.2 | 5748345.2 |
|
TP1b | End of pipeline curve TP1b | 5.1941 | 615410.2 | 5748380.6 | 50 |
IP1 | Intersection Point IP1 |
| 615418.9 | 5748411.7 | |
TP1a | Start of pipeline curve TP1a | 5.2515 | 615394.2 | 5748432.4 | |
HLA Riser | Halibut Riser tie-in | 5.3616 | 615309.9 | 5748503.3 |
|
Coordinate set above is based on GDA94 / MGA Zone 55.
* The flexible pipeline will be laid from the Halibut to Cobia platforms, hence the curves are in the reverse order from the KPs that start at the Cobia platform and which are in the direction of the process flow.
** KP = Kilometre Point (start point defined as the riser tie-in location at Cobia)
4. The SECOND SCHEDULE of the Licence is varied by:
- deleting the current text under Part I SPECIFICATION
and
substituting under the heading SPECIFICATION the following:
Design and Construction
The CBA platform riser, the HLA platform riser and the redundant offshore DN300 steel pipeline are designed and constructed in accordance with the Australian Standard AS 1958-1976: SAA Submarine Pipeline Code supplemented by the licencees’ pipeline licence application dated 29 September 1981 and amendments sought from time to time. The DN150 flexible pipeline shall be designed, manufactured and installed to API Specification 17J, API RP 17B and Esso Australia Limited supplementary specification requirements.
Basis of Design - Cobia and Halibut Platform risers
The design of the Cobia and Halibut Platform risers are based on the following parameters:
Item | Item Description | Details |
1 | Outside diameter of pipe | Pipeline risers: 323.9 mm |
2 | Wall thickness of pipe | Pipeline risers: 19.1 mm |
3 | Length | CBA riser 200 m (approximate) HLA riser 100 m (approximate) |
4 | Design life | Requalified in December 2013 to 2030 |
5 | Pipeline Material and Grade | The Cobia and Halibut riser pipe is API 5L X52 Grade in accordance with the requirements of the American Petroleum Institute Specification – API Spec 5LX, 22nd Edition for Grade X52 seamless pipe and Esso Australia Limited Supplemental pipe specification accompanying the pipeline licence application. |
6 | Minimum yield strength of riser pipe steel | 358.5 MPa |
7 | Weight Coating | The CBA and HLA risers are not weight coated. |
8 | Protective Coating | Protection of the riser pipework shall be maintained with a coating in accordance with the coating Specification No. 4.3 ‘Protective Coatings for Onshore Plants, Offshore Platforms and other Marine Structures or other systems.’
In the splash zones, the HLA riser is wrapped in a
Riser piping above the splash zones at both HLA and CBA platforms is protected with Ultra High Build Epoxy coating. |
9 | Internal design pressure | 13,962 kPag |
10 | Maximum Allowable Operating Pressure | 13,100 kPag
|
11 | Specific Gravity | Not applicable |
12 | Design Capacity | 12,400 m3 oil per day (77,994 bbl oil per day) |
13 | Maximum Operating Temperature | Not applicable |
14 | Maximum Design Temperature | Not applicable
|
15 | Minimum Design Temperature | Not applicable |
16 | Characteristics of substance proposed to be conveyed | Liquid hydrocarbons (and associated produced water) |
17 | General plans and descriptions of pump stations, tank stations or valve stations and their equipment | None provided |
18 | General plans and description of pigging facilities | None provided |
19 | Valves and Fittings | Not applicable |
20 | Connections to Pipeline | The DN150 flexible pipeline is connected to the lower end of both the CBA and the HLA risers with a mechanical end connector and an approximately |
21 | Cathodic Protection | Transformer rectifier units on Cobia and Halibut platforms shall provide protection to the subsea portion of the risers and the DN150 flexible pipeline.
Insulating flanges and gaskets or monolithic isolation joints shall be maintained on the pipeline topsides pipework to electrically isolate the risers from the platform CP systems. |
Basis of Design – DN150 Flexible Pipeline
The DN150 flexible pipeline design is based on the following parameters:
Item | Item Description | Details |
1 | Inside diameter of pipe | 152.4 mm ±5mm |
2 | Wall thickness of pipe | 31.1 mm total comprising multiple layers |
3 | Length | 5.5 km (approximate) |
4 | Design life | 15 years |
5 | Pipeline Material and Grade | The DN150 pipeline will be designed, manufactured and installed to API Specification 17J, API RP 17B and EAPL supplementary specification requirements. It will be supplied with a stainless steel carcass, a Cross-Linked Polyethylene (XLPE or PEX) pressure sheath, steel pressure and tensile armour wire layers and a Polyethylene (PE) external sheath. |
7 | Weight Coating | None |
8 | Corrosion Protection | The DN150 pipeline shall be constructed with an internal corrosion resistant carcass to protect against internal corrosion and shall be protected by an external Polyethylene sheath |
9 | Internal design pressure | 13,962 kPag |
10 | Maximum Allowable Operating Pressure | 13,100 kPag
|
11 | Specific Gravity | Minimum 1.8 (including contents) |
12 | Design Capacity | 5000 m3 oil per day (31,450 bbl oil per day) |
13 | Maximum Operating Temperature | Normal Operations - 82°C Peak Operating - 92°C |
14 | Maximum Design Temperature | Maximum continuous operation 90°C Short term excursions of up to 92°C |
15 | Minimum Design Temperature | 2°C |
16 | Characteristics of substance proposed to be conveyed | Liquid hydrocarbons (and associated produced water) |
17 | General plans and descriptions of pump stations, tank stations or valve stations and their equipment | None provided |
18 | General plans and description of pigging facilities | None provided |
19 | Valves and Fittings | No valves are provided.
Flanges and fittings shall be ANSI 900 or 1500 RTJ flanged or compact Hub connectors.
The Mechanical End Connectors installed on the risers shall meet the requirements of API Specification 6H ‘Specification on End Closures, Connectors and Swivels’ and are designed in accordance with Section VIII of the ASME Boiler & Pressure Vessel Code ‘Rules for Construction of Pressure Vessels’. |
20 | Connection to Pipeline | Connection of the DN150 pipeline to the existing DN300 risers by Mechanical End Connectors and approximately 1 m long DN300 (12”) to DN150 (6”) reducer transition spools. |
21 | Cathodic Protection | Transformer rectifier units on Cobia and Halibut platforms shall provide protection to the subsea portion of the risers and the DN150 pipeline.
Insulating flanges and gaskets or monolithic isolation joints shall be maintained on the pipeline topsides pipework to electrically isolate the risers from the platform CP systems. |
22 | Crossings | The DN150 pipeline will cross two existing pipelines within 300 m of HLA platform; these are the redundant CBA300 pipeline and the HLA100 fuel gas secondary line. The minimum requirements for these crossings shall be: • Minimum crossing angle to the pipelines of • 300 mm clearance between the DN150 pipeline and each crossed pipeline. • Ensure abrasion damage to the DN150 pipeline or damage to the crossed pipelines will not occur. • Include restraints so that the DN150 pipeline cannot slip off the crossing. • Include means to ensure the DN150 pipeline is stable on the crossing. |
Basis of Design – Redundant DN300 Steel Pipeline
The redundant DN300 steel pipeline design is based on the following parameters:
Item | Item Description | Details |
1 | Outside diameter of pipe | 323.8 mm |
2 | Wall thickness of pipe | 12.7 mm |
3 | Length | 5.5 km (approximate) |
4 | Design life | The DN300 steel pipeline is redundant and is not planned to be reused. |
5 | Pipeline Material and Grade | The line pipe shall be in accordance with the requirements of the American Petroleum Institute Specification – API Spec 5LX, 22nd Edition for Grade X52 seamless pipe and Esso Australia Limited Supplemental pipe specification accompanying the pipeline licence application. |
6 | Minimum yield strength of pipe steel | 358.5 MPa |
7 | Weight Coating | DN300 pipeline is provided with 25 mm concrete weight coating. The specification for the steel mesh reinforced weight coating and the shop application of this material to the pipe shall be in accordance with the Esso Australia Limited Protective Coatings Specifications accompanying the 1981 pipeline licence application. |
8 | Protective Coating | The line pipe shall be protected by a coating of fusion bonded black polyethylene having a minimum coating thickness of 2.2 mm and applied in accordance with the Esso Australia Limited specification accompanying the 1981 pipeline licence application. |
9 | Internal design pressure | 13,962 kPag |
10 | Maximum Allowable Operating Pressure | Not provided
|
11 | Specific Gravity | Minimum 1.3 (including contents) |
12 | Design Capacity | 12,400 kilolitres per day (12,400 m3 per day or 77,994 bbl per day) |
13 | Maximum Operating Temperature | Not provided |
14 | Maximum Design Temperature | Not provided
|
15 | Minimum Design Temperature | Not provided |
16 | Characteristics of substance proposed to be conveyed | Liquid hydrocarbons (and associated produced water)
|
17 | General plans and descriptions of pump stations, tank stations or valve stations and their equipment | None provided |
18 | General plans and description of pigging facilities | None provided |
19 | Valves and Fittings | All valves and fittings shall be in accordance with the appropriate American National Standards Institute Specification, Manufacturers Standardisation Society Specification or API 6D Specification, with Class 900 rating.
Low pressure (2.5 MPag) mechanical pipe plugs shall be installed at each end of the DN300 pipeline. |
20 | Connection to Pipeline | Tow Sled Assemblies The redundant steel pipeline is connected to the bottom tow sleds which were used for installation of the pipeline in 1982. These tow sleds remain connected to the seabed level bracing of HLA and CBA platforms.
Side Valve Assembly The redundant steel pipeline includes a side valve assembly situated approximately 850 m upstream of the Halibut end of the pipeline. |
21 | Cathodic Protection | Transform rectifier units on Cobia and Halibut platforms provide protection to the tow sleds which remain connected to the seabed level bracing of HLA and CBA platforms, but do not provide cathodic protection to the redundant DN300 steel pipeline.
Provision has been made for the connection of sacrificial anodes at the mid-length of the pipeline and 1000 metres on either side of the mid-length location as detailed in the Cathodic Protection System Design Specification which accompanied the 1981 pipeline licence application. |
a) deleting all Part II Further Conditions, Sections A to E.
The rest of the Second Schedule remains as stated in the licence instrument dated 20 July 1990.