Japan's JERA in talks for LNG contract with no destination limits
TOKYO (Reuters) — Japan's JERA Co, the world's biggest importer of LNG, is set to sign a new LNG contract soon that would be free of destination restrictions as it looks to secure volumes to replace some expiring long-term deals, its top official said on Wednesday.
JERA has been pushing to drop the so-called destination clause in long-term contracts that limits where a cargo can be delivered, after Japan's Fair Trade Commission (FTC) ruled that such restrictions are anti-competitive.
Faced with that ruling, sellers of long-term LNG have been willing to remove the destination clauses, President Yuji Kakimi said in an interview at the Reuters Global Commodities Summit.
He added that JERA has made progress in talks with existing long-term LNG sellers to revise clauses that would require splitting the profits from reselling LNG cargoes between JERA and the original seller.
Talks on the new term contract come as JERA faces the expiry of long-term contracts with Malaysia, Abu Dhabi and Qatar in 2018, 2019 and 2021 respectively, each with annual volumes of around 4 MMt.
JERA, a joint venture between Tokyo Electric Power and Chubu Electric Power, takes in around 35 MMtpy of LNG.
Those contracts, which industry sources have said include destination restrictions, are not to be renewed automatically, Kakimi said at the Summit, held at the Reuters office in Tokyo.
He said for the moment JERA's supply contracts closely match its demand.
"But some time ahead, there is some room (for new LNG) and we are in talks with some select sellers and expect to have a deal soon that is free of destination clauses," he said.
He did not reveal the seller, volume or term of the contract under discussion, which would be JERA's first since the Fair Trade Commission's ruling.
JERA plans to cut the volume of gas it buys under long-term contracts by 42% by 2030 from current levels, Kakimi told Reuters last year.
He said sellers of LNG from older projects who want to sign new contracts can afford to be more flexible in their offers than proposed new LNG projects that need to lock in long-term deals to secure financing for their multi-billion dollar plans.
"Existing sellers (of long-term LNG), who have recouped their investments, can make various proposals to buyers not limited to long-term but also mid-term and short-term. We would like to see a wide range of proposals from them," Kakimi said.
"There are sellers that truly need long-term contracts, and it is a natural course to take to dedicate the long-term portion of our LNG purchases to those sellers."
Kakimi expects that JERA's annual coal price negotiations will also become tougher as upstream assets have become concentrated in fewer hands. He pointed to Glencore's recent purchase of Yancoal's Hunter Valley, Australia, assets as an example of a company with a dominant presence in coal mining, particularly high-quality coal.
"As is true with LNG, upstream assets in coal are seeing oligopolization," he said. "It is true that the negotiations would become more difficult for buyers."
To reduce the concerns about high prices for coal purchases, JERA's parent companies are turning toward using a more diverse range of coal, including lower quality coal with less heat content, he said.
"Our parent firms used to rely on high-quality mines for 70% to 80% of total in the past, but now the ratio has declined to around 30% to 40%," he said.
JERA's parent companies consume about 20 MMt of coal annually.
Reporting by Osamu Tsukimori; Additional reporting by Yuka Obayashi, Kentaro Hamada and Aaron Sheldrick; Editing by Christian Schmollinger
At CERAWeek by IHS Markit, held in Houston in March, IEA Director Fatih Birol said that the world would soon see a major second wave of shale gas production from the US in response to higher energy prices and growing demand from India and China.
Mozambique and Tanzania hold an estimated 180 Tft3 and 57 Tft3 of proven natural gas reserves, respectively.
Maximize Profitability with Advanced Analytics at Natural Gas Processing Plants
Incorporating economic data into process modeling is key to optimizing operations and maximizing profits at gas processing plants. However, maintaining optimal operations are often challenging due to changing market dynamics, contract structures and increasing process flexibility. Today, gas processors are leveraging Predictive Control and First Principles models to accurately determine and control the optimal operating targets in real time based on the most current plant conditions and profitability, optimizing recovery of natural gas liquids. Learn how real-time analytics, combined with decision support tools, empower companies to:
•Improve processing margins by up to 5%
•Maximize NGL production through improved availability and optimized process conditions
•Improve compositional control to operate closer to product specifications
May 22, 2018 10am CDT