Awarded Orders

Divex selected ABLE Instruments & Controls Ltd to provide the level control technology for fluid measurement on the Navy’s Astute class of attack submarines. The Astute is the latest class of nuclear-powered submarines in service of the British Royal Navy. The class sets a new standard for the Royal Navy in terms of weapons load, communication facilities and stealth. The boats are being constructed by BAE Systems Maritime – Submarines at Barrow-in-Furness. Seven boats will be constructed. The first of class, Astute, was launched in 2007 and commissioned in 2010, and the second, Ambush, was launched on 6 January 2011, and commissioned on 1 March 2013. Astute was declared fully operational in May 2014, while both she and Ambush have sailed for their maiden deployments.

In considering this highly critical measurement application, ABLE proposed the tank level indicators (TLI) due to their highly reliable float technology and their ability to operate flawlessly in tanks with curved walls or other shapes without clear vertical access, where other liquid level technologies may be unable to function.

Cayley was discovered in 2007 by the well 22/17-3 which was drilled about 10km west of Montrose at water depths of 91m. The field will be developed through two production wells.
Shaw was discovered in 2009 by the well 22/22a which was drilled by Talisman in collaboration with Marubeni. The field is located about 17km north of Montrose and will be developed through three production wells and two water injectors. The wells will be ultimately tied to the new Montrose bridge-linked platform (BLP).
Project details of the MonArb area redevelopment
A bridge-linked platform will be constructed and attached to the redeveloped Montrose Alpha Platform, which was originally installed in 1976. The bridge-link will measure 71m in length and weigh 350t.
The subsea development works will include the fabrication and installation of two 5km pipeline bundles. The pipeline bundle system will tie back the Cayley production wells to the new BLP at the Montrose Platform. The works will also involve the fabrication and installation of a 17.5km production pipeline, water injection pipeline, gas lift pipeline and control umbilical which will connect Shaw Field to the BLP.
The pipeline bundle will be installed at its offshore location using the Controlled Depth Tow Method. The development will also involve the drilling of six additional infill wells from the Montrose platform using a modular rig.
The BLP jacket, which will weigh 5,400t and measure 118m in length, is expected to be delivered in 2014. The modification works for the bridge at Montrose are also expected to be carried out in 2014. The topsides for the BLP and the bridge installation works are expected to be completed in 2015.
Oil will be exported using an existing flowline into BP’s Forties Pipeline system and further to the Cruden Bay Pipeline using an existing export riser at Montrose. Gas will be transported through a new riser into the existing WAGE (Wood And Gas Export) module at the Montrose Platform, which will be tied into BP’s Central Area Transmission System (CATS) that runs to Teesside.

The SCP project was sanctioned for construction and operation as part of the Shah Deniz Stage 1 development in February 2003. The construction on the project was launched in 2004 and completed in the last quarter of 2006 with an investment of about $1bn.

The pipeline runs parallel and proximate to Baku-Tbilisi-Ceyhan (BTC) crude oil pipeline. The SCP originates at the Sangachal Terminal, which is located approximately 45km south of Baku, and traverses Azerbaijan and Georgia before terminating at Erzurum in eastern Turkey. The lengths of Georgia’s and Turkey’s sections are 442km and 248km respectively.

The pipeline is buried throughout the route and is designed for an operational life of 30 years. It has a diameter of 42in and is designed to transmit 7bcm of gas annually. It is protected against corrosion by applying a combination of three-layer polyethylene (PE) coating system and an impressed current cathodic protection (CP) system.

In addition to the pipeline’s construction, the SCP project involved a number of above ground installations including two compressor stations (one each in Azerbaijan and Georgia), an intermediate pigging station (cleaning and inspection purposes) and 11 small block valves.

The upgrade is designed to meet the improved environmental standards required by the Environment Agency (EA). The improvements will enable the site to treat 44% more sewage than it does currently, significantly reducing the amount of storm sewage that overflows into the River Thames during heavy rainfall when the site’s treatment capacity is exceeded. This scheme will also allow for a 10% population increase in the area being served.

The new, additional stream at Crossness will mirror the existing works to provide optimised wastewater treatment. Being one of the largest treatment works in the UK, Crossness STW, along with its sister site, Beckton STW, represent the two largest wastewater improvement projects to be delivered for Thames Water in AMP5.

As part of a £140M enhancement to the site, designed to extend sewage treatment capacity by 50 per cent, Mogden has upgraded its boundary monitoring network of industry leading Jerome Hydrogen Sulphide Analysers to the current generation Model J605. All 15 analyser systems are housed in thermostatically controlled IP67 environmental enclosures.

The improvements have significantly reduced the amount of storm sewage that overflows into the tidal stretches of the River Thames when the site becomes overloaded during heavy rainfall and helped Thames Water to meet tighter quality standards for the effluent they discharge.

To accommodate the new equipment installations, Thames reshaped the western embankment, inside the existing site boundary. The landscape to the west of the site has been enhanced, benefiting local wildlife.

As well as significantly reducing sewage discharges, these improvements are helping to reduce odour at the site, as the use of storm tanks has decreased during heavy rain, and new and existing equipment has been covered over.

The extension produces up to 40 per cent of its power requirements via renewable energy. This is achieved by generating electricity from the burning of methane derived from sewage.

NOPL comprises approximately 52 kilometres of 24” pipeline with Above Ground Installations (AGI) at Rumuji and Imo River. NOPL will follow partially the route of the existing Shell Petroleum Development Company (SPDC) pipelines between the aforementioned.

Statoil has extensive heavy oil experiences from offshore fields in Norway and Brazil. The Mariner field was discovered in 1981 and Statoil entered the license as operator in 2007 with the aim of finally unlocking the resources.

Statoil expects to start production from Mariner in 2017. The field is estimated to produce for 30 years, with average production of around 55,000 barrels of oil per day over the plateau period from 2017 to 2020.

The Mariner Field consists of two shallow reservoirs, the Maureen Formation and the Heimdal Sandstones of the Lista Formation, with nearly 2 billion barrels of oil in place and expected reserves of more than 250 million barrels of oil. Both formations yield heavy oil of around 12 to 14 API.

The heavy oil project will require pioneering technology in order to be developed. Since its discovery in 1981, the Mariner field has been subject to a number of development studies by different operators prior to Statoil becoming the operator in 2007. The field will be developed with a production, drilling and quarters (PDQ) platform, based on a steel jacket, with 50 active well slots, and a floating storage unit (FSU) of 850,000 bbls capacity. In addition a jack-up rig will be used for the first 4 – 5 years.

The Mariner Field is located on the East Shetland Platform of the UK North Sea approximately 150km east of the Shetland Isles. Statoil acquired 44.44% and operatorship for Mariner from Chevron in 2007. Statoil acquired a further 20.6667% of Mariner from Nautical Petroleum in 2010. JX Nippon Exploration and Production (U.K.) Ltd(28.89%) and Alba Resources Limited, (6%) are partners in Mariner. Alba Resources Limited are a wholly owned subsidiary of Cairn Energy PLC.

The Martin Linge project in the Norwegian sector of the North Sea opens new doors for Total through technology innovations that reduce environmental impacts and enhance safety. The pioneering solutions defined to reduce CO2 emissions represent a new era of sustainable oil and gas production in the Norwegian North Sea.

The development of this offshore oil and condensate gas field lying under 115 m of water began in early 2012. It involves the construction of an integrated wellhead, production and accommodations platform. Gas from the field will be exported to the UK via the FUKA gas pipeline.

The project will set a precedent for sustainability by supplying the field’s power needs from the Norwegian mainland grid via a 170-km subsea cable. This innovation will reduce CO2 emissions by two million metric tons.