Offshore installations regulations

Healthy, safe and productive lives and enterprises. Please Note Our website uses cookies to enhance your browsing experience and to collect information about how you use this site to improve our service to you.

Accept all cookies Manage Cookies. Managing Safety and Health in Schools. Teacher Support and Classroom Resources. Safety and Health Initiatives in Education. Health and Safety Courses Online. Trenched and Buried flexible pipelines, umbilicals, spools and jumpers will be removed to shore for recycling or appropriate treatment and disposal February Topaz Decommissioning Programme PDF , 2. September Subsea Installations Removal to shore for recycling or re-use. September Pipelines Removal to shore of surface laid pipelines.

Limited - Brent Alpha Jacket Jacket to be removed to The exposed sections will be remediated by either cut with removal to shore, trench and burial or rock cover. Exposed mattresses will be removed to shore for re-use, recycling or disposal. Limited - Topside and Jackets Removal to shore for recycling or re-use May Pipelines NW Bell pipelines will be recovered to shore for re-use or recycling.

March Subsea Installations Partial removal of the mooring anchor piles. The mooring chain will be cut locally to the mooring pile and buried to 1m below seabed. Removal of manifolds and wellhead protection structures. March Pipelines Removal to shore. Limited - Subsea installations The anchors will be decommissioned in situ. All other installations will be removed to shore for either re-use or recycling November Pipelines All buried pipeline, flowlines and umbilicals will be removed for recycling and disposal November Goldeneye PDF , 3.

Footings to remain in situ. Remediation for any exposed sections. All other pipelines to be removed. Spirit Energy Nederland B. Footings to remain in situ August Pipelines Export pipeline decommissioned in situ with remedial rock placement.

Revision to approved decommissioning programme: completion of the removal of the Wellhead Protection Structure extended to 30 June ; year of revised approval: Pipelines Decommissioned in situ; pipeline sections outside trenches removed to shore. Revision to approved decommissioning programme: completion of the abandonment of the pipelines extended to 30 June ; year of revised approval: Indefatigable Shell PDF , Revision to approved decommissioning option: removal to shore for dismantling and recycling Following this, OPRED will decide one of the following: we are content with the proposals for monitoring and maintaining the out-of-use pipeline we request additional information or further remedial action we request a formal decommissioning programme The Interim Pipeline Regime is intended to ensure out of use lines do not pose a risk to other users of the sea or the environment and that they are covered by an appropriate surveying and maintenance regime from the point when they are taken out of use until approval of the formal decommissioning programme, which is usually at the end of field life.

Cost recovery OPRED will charge a fee in respect of offshore oil and gas installations and pipelines decommissioning programmes under the Petroleum Act Explore the topic Climate change and energy Infrastructure and decommissioning. Is this page useful? Maybe Yes this page is useful No this page is not useful. Thank you for your feedback. Report a problem with this page.

What were you doing? What went wrong? Email address. Removal of FPSO and mooring lines to shore for recycling.

Subsea installations will be fully removed and recovered to shore for reuse, recycling or disposal. Removal of all subsea installations, purge spool and valve skid structure to shore for recycling.

All topsides and jackets will be recovered to shore for re-use or recycling. The FPSO will be removed from station and recovered to shore for recycling unless alternative re-use options can be found.

Subsea installations will be returned to shore for recycling or disposal. Platform will be recovered to shore for reuse or recycling. Wellhead protection structure will be recovered to shore for re-use, recycling or disposal. Removal of Brae Alpha and Brae Bravo jackets to the top of the footings. Trenched pipelines will be left in situ. Buried pipelines will be left in situ with exposed ends cut and removed. Surface laid pipelines will be cleaned, flushed and fully removed. Existing rock dump will be left in situ.

The topsides will be transported ashore for dismantling. Subsea installations will be returned to shore for recycling or appropriate treatment and disposal. Trenched and buried stable pipelines will be left in situ. The end of the pipelines will be cut, and additional rock cover will be added to cut ends to reduce snagging risk.

Trenched and buried pipelines and trenched and buried Flexible Flowlines Failed and umbilical will be left in situ. Buried pipelines associated with PP will be left in situ and the riser sections of pipelines will be removed to shore for re-use or recycling with the PP and PR jackets.

The pipelines will be partially removed, the exposed sections adjacent to the platforms will be removed and recycled or disposed onshore.

Buried and stable pipelines will be left in situ. Surface laid pipelines will be removed to shore for re-use, disposal or recycling. Trenched and buried rigid, stable pipelines will be left in situ.

Trench and Buried flexible pipelines, umbilicals, spools and jumpers will be removed to shore for recycling or appropriate treatment and disposal. The Balmoral FPV will be towed to a suitable location for re-sale, re-use, recycling or disposal. Trenched and Buried flexible pipelines, umbilicals, spools and jumpers will be removed to shore for recycling or appropriate treatment and disposal.

The subsea installation, a Wellhead Protection Structure, will be returned to shore for recycling or appropriate treatment and disposal. This Decommissioning Programme is specifically for preparation work scopes relating to the Fulmar and Auk North installations. Jacket to be removed to Pipelines will remain in-situ. A port operator required to have a maritime security plan must give to each port facility operator conducting operations within the security regulated port:.

Penalty: 20 penalty units. In addition to the matters required under regulation 3. A maritime security plan for a port operator must set out:. A maritime security plan for a port operator must address, in addition to the matters required under regulation 3. Note: A maritime security plan for a port operator must be accompanied by a map covering the whole security regulated port and showing the port security zones established within the port see subsections 49 2 and 3 of the Act and regulation 3.

A maritime security plan for a port operator must set out, in relation to maritime security level A maritime security plan for a port operator must set out, in relation to maritime security levels 2 and 3, the additional security measures that the operator will implement if the Secretary declares that maritime security level 2 or 3 is in force for the port.

A maritime security plan for a port operator must provide for:. A maritime security plan for a port operator must set out security measures and procedures to monitor and control access to ship security zones, including measures to detect and deter unauthorised access to those zones.

A maritime security plan for a port facility operator must be accompanied by a document setting out the following information:. A maritime security plan for a port facility operator must be accompanied by a document setting out the name of, and contact details for, the PSO of the security regulated port in which the facility is located. A maritime security plan for a port facility operator must set out:.

Note: A maritime security plan for a port facility operator must be accompanied by a map showing any port security zones established within the facility see paragraph 49 2 a of the Act and regulation 3. A maritime security plan for a port facility operator must set out, in relation to maritime security level A maritime security plan for a port facility operator must set out, in relation to maritime security levels 2 and 3, the additional security measures that the operator will implement if the Secretary declares that maritime security level 2 or 3 is in force for the port.

A maritime security plan for a port facility operator must provide for:. A ship security plan must be accompanied by a document setting out the following information about the ship:.

Note: For the definition of official number , see subregulation 1. A ship security assessment for a regulated Australian ship must include the following matters:. A ship security plan must address the following matters:. A ship security plan must set out, in relation to maritime security level A ship security plan must set out, in relation to maritime security levels 2 and A ship security plan must provide for:. A ship security plan must give sufficient guidance on how the security of the ship will be maintained in exceptional circumstances such as search and rescue operations, humanitarian crises, extreme weather conditions and other emergencies.

Note: Section 6 of the Navigation Act defines overseas voyage as follows:. A ship security plan must set out procedures for:. Note: A ship operator may be guilty of an offence under section 63 Offence—failing to comply with ship security plan of the Act if security equipment that is not correctly calibrated is used on board the ship.

A ship security plan must include a statement to the following effect:. The ship operator for a regulated Australian ship must ensure that the ship security plan for the ship is protected against unauthorised access, amendment and disclosure. A details of the intended route; and.

B any intended ports of call along the route; and. For subsection 61A 3 of the Act, the following matters are prescribed:. The ISSC for a regulated Australian ship must be made available for inspection at the request of a person who is authorised by a contracting government to request information about, or in connection with, whether a valid ISSC is in force for the ship.

Note: For the power of maritime security inspectors and duly authorised officers to inspect ISSCs, see subparagraphs 2 e i and 2 c i of the Act, respectively. For subsection 79A 3 of the Act, the following matters are prescribed:.

Part 5 — Regulated foreign ships. If it is reasonable and practicable to do so, the Secretary must consult with the following about giving a control direction that relates to the movement of ships within, or in or out of, a security regulated port:. The Secretary must give a control direction to the ship operator for, or the master of, a regulated foreign ship:.

Note: Under subsection 99 5 of the Act, a control direction has no effect until the Secretary commits the direction to writing. Part 5A — Offshore security plans. A security assessment for an offshore security plan must include the following matters:. An offshore security plan for an offshore industry participant must set out:. The operator of an offshore facility must give to each offshore service provider conducting operations at the facility:.

An offshore service provider that is required to have a security plan must give to the operator of each offshore facility to which the service provider conducts operations:.

For section H of the Act, this Subdivision prescribes the matters that are to be dealt with in an offshore security plan for an offshore facility operator. Note: An offshore facility operator that has more than 1 facility may prepare 1 plan for each facility, or 1 plan covering a number of facilities that are in the same area, and are physically and operationally similar, and that have identical risk assessments.

An offshore security plan for an offshore facility operator must be accompanied by a document setting out the following information:. An offshore security plan for an offshore facility operator must be accompanied by a document setting out the name of, and contact details for, the OSPSO of each offshore service provider conducting operations at each facility. An offshore security plan for an offshore facility operator must set out:. An offshore security plan for an offshore facility operator must set out, in relation to maritime security level An offshore security plan for an offshore facility operator must set out, in relation to maritime security levels 2 and 3, the additional security measures that the operator will implement if the Secretary declares that maritime security level 2 or 3 is in force for a facility of the operator.

An offshore security plan for an offshore facility operator must provide for:. An offshore security plan for an offshore facility operator must set out security measures and procedures to monitor and control access to ship security zones, including measures to detect and deter unauthorised access to those zones. For section I of the Act, this Subdivision sets out requirements for the preparation of an offshore security plan.

The information that must accompany an offshore security plan for an offshore facility operator must:. Note: Section E of the Act deals with the activities of offshore industry participants being covered by offshore security plans of other offshore industry participants. For section H of the Act, this Subdivision prescribes the matters that are to be dealt with in an offshore security plan for an offshore service provider.

An offshore security plan for an offshore service provider must be accompanied by a document setting out the following information:. An offshore security plan for an offshore service provider must be accompanied by a document setting out the name of, and contact details for:. In addition to the matters required under regulation 5A. An offshore security plan for an offshore service provider must set out:.

It is also recognised that gathering nesting bird data for offshore installations is challenging. As a first step OPRED asked the Joint Nature Conservation Committee JNCC to provide an advice note on kittiwake survey methods for offshore installations and this is now available in the guidance section below with the associated recording forms available as a separate Word document.

It is recognised that the survey methods need full testing offshore and where necessary updates will be considered based on feedback provided. Industry should consider their specific circumstances and discuss potential survey plans as they are being developed with the appropriate OPRED Environmental Manager, particularly if there are any proposed changes from the JNCC advised kittiwake survey methods or if survey methods for other bird species are being considered.

JNCC have also provided OPRED with a signposting document containing information and resources for black-legged kittiwakes that should be used by industry in the relevant environmental applications. The inclusion of other, more recent evidence is also encouraged in applications.

The kittiwake signposting document is available in the guidance section below. EPS injury or disturbance licences are currently only required for acoustic surveys where the Joint Nature Conservation Committee JNCC or another Statutory Nature Conservation Body has advised that the applicant for a consent for a geological survey must also obtain an EPS injury or disturbance licence.

Under such circumstances, the reporting requirements detailed in the survey consent are sufficient to additionally cover the EPS injury or disturbance licence requirements, and there are no additional reporting requirements. Habitats Regulations Assessments undertaken by the Department for acoustic geological surveys are detailed in the entry for the Offshore Petroleum Activities Conservation of Habitats Regulations , and the assessments relating to EPS will include injury or disturbance assessments.

For further information please contact the Business Support Team by e mail at bst beis. This assistance will include seeking information from installation operators relating to mercury waste generated on offshore installations and, if requested by the competent authorities, inspect offshore installations to investigate any alleged contraventions of the Regulations.

The information available on this website only provides guidance on the provisions of the Regulations where OPRED provides assistance to competent authorities specific to the offshore oil and gas industry. Readers should consult the relevant competent authorities SEPA and EA websites for additional information such as the competent authorities approach to enforcement and offences. The Energy Act makes provision under Part 1, Chapter 2 for the regulation of gas importation and storage through a licensing and enforcement regime for combustible gas.

The Energy Act also makes provision under Part 1, Chapter 3 for the regulation of the storage of carbon dioxide with a view to its permanent disposal or as an interim measure prior to its permanent disposal , through a licensing and enforcement regime. The Storage of Carbon Dioxide Licensing etc. Regulations , made under Part 1 of the Energy Act , came into force on the 01 October Following enactment of the Energy Act Consequential Modifications Offshore Environmental Protection Order , which came into force on 01 July the provisions of the following regulations now also apply to gas unloading and storage, and carbon dioxide storage as they do to oil and gas activities.

This extension is, however, subject to geographical limitations to reflect the different devolution settlements relating to offshore activities. For further information please contact the Business Support Team by email at bst beis. The MCAA provided a regulatory framework for a new marine licensing regime that included consideration of works that could be detrimental to safe navigation.

Although the MCAA licensing regime applies to a number of offshore oil and gas operations, including the disturbance of the seabed and deposit and removal of substances or articles during the course of decommissioning operations, Section 77 of the MCAA excludes the vast majority of offshore oil and gas operations and carbon dioxide storage operations controlled under the Petroleum Act PA or the Energy Act EA.

The granting of a CtL to an individual or organisation by the Secretary of State under Part 4A of the EA allows the installation of an offshore structure or the carrying out of offshore operations providing they are undertaken in accordance with the consent conditions.

It allows the Department to require the provision of navigational markings that are considered appropriate for the proposed structure or operations. Separate requirements relating to the clear identification of installations are included in the Offshore Installations and Pipeline Works Management and Administration Regulations The Department revised the procedures that were in place under the CPA , to ensure that the consenting process under Part 4A of the EA reflected the specific requirements of the operations that are covered by the MCAA exclusion.

The revision accounted for requirements set out in Part 4A of the EA and the development of offshore practices that were not envisaged when the CPA was drafted. It also took account of the views of the bodies consulted on navigational matters. Detailed guidance is currently being developed to replace the consultation documentation. It will address comments received further to the consultation, and issues that have been identified since the implementation of the EA regime.

Pending publication of the guidance, if you require additional information please contact the Business Support Team by e-mail at bst beis. The SMS and the conditions attached to the consents are currently being reviewed, and the above document will be replaced when the new schedule proposals have been agreed with relevant navigational consultees. Applications submitted to the Department and the associated decisions made by the Department can be viewed at on the GOV. UK website at Oil and Gas: submissions and determinations:.

For further information please contact the Business Support Team by e-mail at bst beis. ESOS is a mandatory energy assessment and energy saving identification scheme applicable to the offshore oil and gas industry sector. The scheme requires an audit to be undertaken once every four years to identify cost-effective energy efficiency measures.

Phase 2 commenced on 6 December , with the qualification date for participants of 31 December , and the compliance date of 5 December Compliance must be notified to the Scheme Administrator Environment Agency using the online notification system. The online notification system will be available for scheme participants to notify completion of the required audit. If scheme participants are unable to meet a compliance deadline, this should be recorded in advance of the deadline using the online form, explaining why the compliance deadline will be missed and when you expect to be compliant.

Participants should also hold a record of the action taken to date to achieve compliance, including details of the appointment of a lead assessor, and retain a copy of the late notification submission, as they may be requested to provide the evidence pack to confirm that they are working towards compliance.

Scheme participants that qualify who do not notify a delay in compliance will be in breach of the ESOS Regulations and will risk enforcement action. Although the Directive was not incorporated into UK law until , SEAs have been carried out since in accordance with its requirements.

Any implementing acts which have not been replaced will remain in force and continue to apply unless and until repealed by new delegated or implementing acts adopted by the Commission pursuant to Regulation EU No.

This guidance document is currently under review and will be updated to include the Regulations. Defra has also published detailed guidance which can be accessed below. You must submit a notification within 2 working days of the non-compliance being identified. However, it was retained in Scottish territorial waters to provide licensing powers in relation to reserved offshore energy activities that are the responsibility of the Offshore Petroleum Regulator for Environment and Decommissioning OPRED.

This was necessary because:. A FEPA Part II licence is only required for the deposit of substances or articles in the sea or under the seabed in relevant areas of the territorial sea adjacent to Scotland. For offshore energy activities in Scottish controlled waters, please contact the Marine Scotland, Licensing Operations Team. Interested parties can review records relating to applications and decisions made under FEPA Part II at the Oil and gas: environmental submissions and determinations page.

It is a Europe-wide cap and trade scheme, which started in The only Annex 1 Activities that are relevant to offshore installations are combustion installations with a maximum rated thermal input exceeding 20 megawatts. The current phase of the EU ETS builds upon the previous two phases and is significantly revised to make a greater contribution to tackling climate change including: an EU-wide cap on the number of available allowances and an increase in auctioning of those allowances.

The EU cap will reduce the number of available allowances by 1. The trajectory calculated from the mid-point of Phase II and will describe a declining cap from onwards. The Phase also brings harmonised EU allocation methodologies. Carbon leakage is a term used to describe the prospect of an increase in global greenhouse gas emissions when production or investment is moved outside of the EU because they are unable to pass on the cost increases resulting from the EU ETS to their customers without significant loss of market share.

There remains no change to the extraction of oil. In preparation for Phase IV, baseline data was collected to form the basis of a free allocation in the first allocation period of An application for a free allocation had to be submitted via ETSWAP by 30th June and include the baseline data template, monitoring methodology plan and verification report as well as any supporting documents.

Installations that were not operational within the baseline period but were operational before 30 June are still required to submit the data. The offshore guidance for the NIMs baseline data collection and a FAQs was produced to assist in the completion of the templates.

OPRED also provided guidance via an industry workshop. Failure to meet the submission timing means the installation is no longer eligible for a free allocation for the first period. Updates will be made to this page throughout the change process. Applications must include details of all the relevant activities specified in Annex 1 of the Directive and include details of any directly associated activities.

ETSWAP is an electronic workflow and messaging system that allows regulators, operators and verifiers to manage EU ETS permitting, improvement planning, notifications, permit variations, annual emissions reporting, verification, and enforcement.