Projects

Based in Queensland, Australia, the GLNG project involves gas field developments in southeast Queensland and an LNG plant on Curtis Island, near Gladstone.

Sanctioned in January 2011, GLNG includes the development of coal seam gas (CSG) resources in the Bowen and Surat Basins, construction of a 420-km underground gas transmission pipeline to Gladstone, and two LNG trains with a combined nameplate capacity of 7.8 mtpa on Curtis Island.

The project has an estimated gross capital cost of US$18.5 billion and is on track for first LNG in the second half of 2015.

The Offshore Technology Conference 2015 (OTC 2015) set for May 4-7 at NRG Park in Houston will bring together more than 100,000 industry leaders and buyers from 130-plus countries, all of whom want to explore how technology, best practices and emerging trends can provide the energy needed for the world.

Pembina Pipeline Corp. plans to expand the Vantage pipeline system for an estimated $85 million. The expansion entails increasing Vantage's mainline capacity from 40,000 bpd to 68,000 bpd through the addition of mainline pump stations and the construction of a 80-km, 8-inch gathering lateral.

The mainline expansion is supported by a long-term, fee-for-service agreement, with a substantial take-or-pay component. The gathering lateral is underpinned by a fixed return on invested capital agreement. The expansion is expected to be in-service in early 2016.

Sempra Energy announced that its IEnova and Sempra LNG units have signed a Memorandum of Understanding (MOU) with a subsidiary of Pemex, Mexico's state-owned petroleum company, for development of a natural gas liquefaction project at the Energía Costa Azul receipt terminal in Ensenada, Mexico. Pemex would have the opportunity to become a customer, natural gas supplier and investor.

"This is an important first step in working with Pemex on the development of liquefaction facilities at Energía Costa Azul," said Mark A. Snell, president of Sempra Energy.

Tallgrass Development, LP and AGL Resources Inc. concluded the non-binding open season for the proposed Prairie State Pipeline. The system would move natural gas from supply connections in central Illinois to the Chicago Market Center and points in between. Prairie State Pipeline is being jointly developed by Tallgrass and AGL Resources and is expected to have ownership participation by both companies should binding commitments be finalized with interested market participants.

Recently EnLink Midstream invited me out to West Texas to see my first pipeline spread – the Martin County Extension Pipeline. On the way to the line we stopped by the Deadwood gas plant where I met Chris Coleman, EnLink Midstream’s senior landman. He was amiable, genuine and welcoming, even letting me ride shotgun in his work truck, which I had to jump to get into. As we drove across the flat Texas land, kicking up a flurry of red dirt, he began telling me about his job.

In summer 2011, executives at super-major ExxonMobil were telling financial analysts during a quarterly earnings conference call about an amazing 70% boost in a year’s time of the energy giant’s unconventional natural gas-weighted portfolio to 76 Tcfe. The reason was simple, according to David Rosenthal, the current controller at ExxonMobil and at the time its investor relations chief. He summed it up in three letters, X-T-O.

The Mountain Valley Pipeline (MVP) will provide 2 Bcf/d of natural gas transportation capacity from the the Marcellus and Utica production areas to the Mid- and South-Atlantic regions by the end of 2018 if all goes as planned.

The 300-mile pipeline, a joint venture of EQT Midstream Partners and NextEra U.S. Gas Assets, will run from northwest West Virginia to southern Virginia, extending the Equitrans transmission system to Transcontinental Gas Pipeline Company’s compressor station in Pittsylvania County, VA. EQT Midstream will operate the pipeline and own a majority interest.

BP, on behalf of the Kinnoull field co-venturers, announced the start of production from the Kinnoull field in the central North Sea. Kinnoull was BP’s seventh and final major upstream project start-up in 2014.

The Kinnoull reservoir, developed as part of a wider rejuvenation of the Andrew field area, is tied back to BP’s Andrew platform, 230-km east of Aberdeen, and is expected to enable production there to be extended by a further decade.

In order to access the reservoir, a new subsea system has been installed, together with a 700 ton topside processing module on the Andrew platform. Production is now carried from the Kinnoull field to the Andrew platform via a 28-km subsea pipeline bundle – the longest such system in the world – for processing and onward export via the Forties pipeline system (oil) and the CATS pipeline system (gas).

CNOOC Limited recently began production from its Liuhua 34-2 gas field in the Eastern South China Sea. The field is located in water depths ranging from 850 to 1,250 meters and consists of one producing well and shares the existing facilities of Liwan 3-1 gas field for overall development. The gas field is producing approximately 30 MMcf/d and is expected to reach its designed peak production of approximately 45 MMcf/d in 2015.

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