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Collaborating Authors
Liquified natural gas (LNG)
ExxonMobil announced the completion of a transaction by ExxonMobil Development Africa BV to acquire a 25% indirect interest in Mozambique's gas-rich Area 4 block from Eni and assume responsibility for midstream operations. ExxonMobil will lead the construction and operation of all future natural gas liquefaction and related facilities, while Eni will continue to lead the Coral floating LNG project and all upstream operations. ExxonMobil said the operating model will enable the use of best practices and skills with each company focusing on distinct and clearly defined scopes while preserving the benefits of an integrated project. The deepwater Area 4 block contains an estimated 85 Tcf of natural gas in place.
The US Energy Information Administration (EIA) reported that an increase in online liquefied natural gas (LNG) terminals has spurred on a subsequent increase in LNG export volumes. In August 2017, total US natural gas liquefaction capacity in the Lower 48 states increased to 2.8 Bcf/D following the completion of the fourth liquefaction unit at the Sabine Pass LNG terminal in Louisiana. With increasing liquefaction capacity and utilization, the EIA said that US LNG exports are now averaging 1.9 Bcf/D, and capacity utilization has averaged 80% for the year based on data through the end of November. Located on the coast of the US Gulf of Mexico (GOM) near the Louisiana-Texas border, Sabine Pass comprises four existing natural gas liquefaction units, or trains, with a fifth train currently under construction. When complete, Sabine Pass will have a total liquefaction capacity of 3.5 Bcf/D.
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Oil & Gas > Midstream (1.00)
Total is expanding its global LNG presence by acquiring assets from Engie for up to $2.04 billion. The deal will provide the French supermajor with 2.5 million tonnes per annum (mtpa) of liquefaction capacity, including a 16.6% interest in Louisiana's Cameron LNG export terminal, where three trains are under construction and two more can be added, as well as a 5% interest in the first train of Egypt's Idku LNG project. Total will expand its portfolio of LNG purchase-and-sale contracts, adding supply from Algeria, Nigeria, Norway, Russia, Qatar, and the US with outlets between Europe and Asia. The firm also will gain access to 14 mtpa in regasification capacity in Europe and add 10 LNG tankers to its three existing carriers. Total will pay $1.49 billion for the assets and up to $550 million more if the oil market improves in the coming years.
- Europe (1.00)
- North America > United States > Louisiana (0.27)
- Asia > Middle East > Qatar (0.27)
- (2 more...)
Abstract The ADGAS plant facilities include three LNG trains (Trains-1 & 2 commissioned in 1977 and Train-3 commissioned in 1994), Offshore Associated Gas (OAG) and Integrated Gas Development (IGD) facilities along with utilities and other associated facilities such as storage tankage, jetties for export of the products, etc. The gas feedstock comes from various offshore oil and gas fields surrounding Das Island. The feed gas, delivered to the plant at different pressure levels is compressed through different stages and purified before liquefaction. The feed gas contains impurities like CO2 (Carbon Di Oxide) and H2S (Hydrogen Sulphide), which are removed by gas sweetening process. H2S removed by the sweetening process is converted into liquid Sulphur in the Sulphur Recovery Units. After sweetening, the hydrocarbon gas mixture is cooled in stages followed by fractionation and liquefaction to produce different hydrocarbon products ranging from LNG (a mixture of methane and ethane) to Paraffinic Naphtha. ADGAS commissioned the OAG and IGD facilities in 2010 and 2013 respectively, enabling gas export from Das Island to onshore Habshan facilities through a subsea pipeline. The primary objective of OAG facility is to process additional quantities of LP Gases that has become available at Das Island from ADMA-OPCO, following increase in oil production. The process involves compression of LP Gases, Dehydrate and dispatch 211 mmscfd of Gas & Condensate through marine pipeline to GASCO facility at Habshan. OAG (two processing trains) processes about 200mmscfd gas whereas The IGD was commissioned in the year 2013. This comprises of three Trains capable of delivering 900 mmscfd of dry compressed HP Gas at 155 Bara through marine pipeline to GASCO facility at Habshan.
Abstract This presentation will discuss Four Energy Efficiency initiatives were taken in 2016 in one of the biggest NGL Producing Plants in the UAE (GASCO-Bu Hasa). They are: C3+ Recovery Enhancement: Increased the discharge pressure of HP compressor (2K-103/203) by 1 bar over the current operating pressure of 27.2barg. As an output, overall C3+ recovery increased by 0.3-0.4wt% depending on consistent operation at test run conditions. Utilizing 36" HP Line for Residue Gas: 36" BHGP line designed for diverting the excess HP gas, this was innovatively utilized for diverting excess Lean Gas and avoiding residue gas flaring. Savings through Advanced Process Control (APC): Advanced Process Control (APC) was implemented in Bu Hasa in 2009. During Jan & May-2015 tuning exercise initiated for all APC Controllers through GASCO in-house team. Savings through Internal & External Leak Survey: GASCO Bu Hasa NGL plant has taken the proactive approach to reduce hydrocarbon leaks by implementing an Internal and External Leak Detection and Repair Program.
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
- Facilities Design, Construction and Operation > Processing Systems and Design > Compressors, engines and turbines (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
- (2 more...)
Abstract The present article collects the main activities carried out by Eni on FLNG in the past years. As such, it reports Eni’s view of the FLNG technology and it constitutes a subjective assessment and evaluation of the involved technologies and the associated risks. The same evaluation and assessment may lead to very different results when based on a different risk perception, which is proper of each Oil Company. At time of writing, Coral South FLNG Project has obtained Final Investment Decisions from all the Project Partners and the FLNF EPC contract has been awarded, with consequent commencement of detailed engineering and construction activities. The paper will present the activities carried out in Eni about FLNG in the past years, then used to validate and enable the development of Coral South FLNG Project. In particular, it will briefly present the main technological features studied and selected by eni for the Coral South Project. It will summarise the main studies carried out and the main advantages and disadvantages considered by Eni when selecting the technologies adopted in the Coral South FLNG Project. As a conclusion, the paper will summarise the main technological configuration of Coral South FLNG facilities based on the validation activities carried out. Coral South FLNG Project finds its basis in an extensive preparation activities, as FLNG technology has been studied in Eni since 2008, when some stranded oil&gas fields required valorisation with offshore LNG technology. A series of activities and project-based pre-feasibility and feasibility studies have been carried out in the following four years, preparing the ground and unlocking Coral South Project in Mozambique. The main technologies studied and screened are: –Liquefaction process technology; –Refrigerant make-up production technology selection; –LNG offloading system configuration; –Mechanical drivers for liquefaction compressors and generators; –Heating medium system; –Containment system including sloshing issues; –Mooring system; For each of these systems, a rigorous and common technology validation approach has been adopted, consisting in a screening of different technical alternatives with a qualitative analysis. When necessary a quantitative evaluation has been carried out, including a detailed engineering assessment, scale tests and a cost and risk comparison. The final selection has been made taking into account safety, costs and operability. For each technology, a preferred one has been selected firstly as Eni Corporate and then checked and validated for the specific Coral South FLNG Project application. As result of the extensive application of the technology validation procedure, the originally selected technologies for the generic Eni FLNG have all been confirmed for the Coral South FLNG Project even if in some cases scale tests have been required to further assess the identified criticalities. When it comes to FLNG application, even the most common and widely adopted technology can be considered as a novelty as there are no previous floating and/or LNG application for it. Eni approach to this novelty-in-complexity environment is based on an internal ad-hoc developed technology validation procedure which has been demonstrated to be very effective even when applied a real demanding Project like Coral South FLNG.
- Asia (0.68)
- Africa > Mozambique > Cabo Delgado (0.28)
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Midstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (0.46)
- Africa > Mozambique > Cabo Delgado Province > Indian Ocean > Mozambique Channel > Rovuma Basin > Area 4 Block > Mamba Field (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BS-3 > Coral Field > Guarujá Formation (0.98)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
Abstract Objectives/Scope Kuwait energy company has started to explore and develop oil and gas reserves since 2010 in East Abu-Sennan concession under production sharing agreement with the Egyptian General Petroleum Corporation. This concession is located in the Western Desert of Egypt, Production was commenced in July 2012 with 4 wells, oil production in this field was restricted due to gas flaring limitations in the agreement to 1 MMSCF/Day. Therefore, Kuwait energy initiated a challenging objective for the best gas utilization method in 2014. The project to be executed must pass the barriers of economic model with pessimistic reserve inputs and relatively short execution duration. Methods, Procedures, Process Three scenarios were considered for Gas compression station: Brand new equipment, Rental Facility and Idle Used equipment. Risk assessment and economical modeling were performed and showed that Idle Used equipment existing in the country is the most economically feasible option. 16 years old idle equipment were located within EGPC custody, onsite inspection and data collection to determine efficiency and repair requirements followed by engineering work to recheck design calculations and HAZOP Studies. Equipment manufacturer agents performed the overhauling for rotating parts and upgrades for electric control panels. Meanwhile a two-phase agreement with a qualified contractor was initiated for dismantling the equipment inside active plant, transportation and installation in the project location. Results, Observations, Conclusions The project was completed and commissioned within allocated budget and time frame of 6 months leading to increased average daily production from 1,864 BOEPD in 2014 to 5,988 BOEPD in 2015 in addition to zero flaring target achievement. The plant has been running for more than two years without any failures or shut downs. Novel/Additive Information From this project planning, execution and results; we can claim that if Risk assessments, detailed scope of work, time management with contractors/suppliers and cost effective choices were addressed carefully; shall result in outstanding performance.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Africa Government > Middle East Government > Egypt Government (0.34)
- Africa > Middle East > Egypt > Western Desert > Kharita Formation (0.99)
- Africa > Middle East > Egypt > Western Desert > Greater Western Dester Basin > Abu Gharadig Basin > Abu Sennan Concession > El Salmiya Field > El Salmiya-2 Well (0.99)
- Africa > Middle East > Egypt > Western Desert > Greater Western Dester Basin > Abu Gharadig Basin > Abu Gharadig Field (0.99)
- (3 more...)
Innovation and Technology Advancements in Measurement of Ultralow Sulfur in Natural Gas Products
Veerakumar, Ukkirapandian (Abu Dhabi Gas Liquefaction Co Ltd) | Lallan, Sanjay Singh (Abu Dhabi Gas Liquefaction Co Ltd) | BaHamaish, Zeyad Nasser (Abu Dhabi Gas Liquefaction Co Ltd) | Abbas, Ahmad (Abu Dhabi Gas Liquefaction Co Ltd)
Abstract Objectives Objective of this project is to identify right technology and equipment for measurement of sulfur in natural gas products and adapt configuration changes of the system to avoid co-elution and for accurate measurement of individual sulfur compounds at ultralow level in the matrix of butane, propane and LNG. This involves standardization, validation and trials with plant samples. Methods and procedures There are different techniques by which sulfur impurities are measured. Some of them are lead acetate paper, air oxidation and combustion, potentiometric titration and gas chromatography (GC) with sulfur chemiluminescence detector (SCD) or Pulse Flame photometric detector (PFPD) or atomic emission detector (AED). We have worked extensively to identify, validate and adopt a new and advanced analytical technique for measurement of sulfur impurities in LNG and LPG products. As the level of quantification goes to ppb level it is very important that the measurement methods must be reliable, stable and acceptable to all customers. Results and discussion GC with SCD has been identified as the best suitable one, for our products to determine individual sulfur compounds such as hydrogen sulfide, carbonyl sulfide, methyl, ethyl, propyl, butyl mercaptans and total sulfur. Several trails were performed with certified butane, propane and LNG standards at very low concentration levels and with real plant samples to validate and check for matrix effect and co-elution of COS with propane. The use of methyl mercaptan as calibration standard simplifies the calibration process as all sulfur compounds in our products have equimolar response in SCD. The innovation and advancement made in the instrument configuration with right separation column, dual plasma burner and improved vacuum level by frequent maintenance of pumps improved the accuracy level of determination of sulfur compounds. The products from plant were tested and monitored for these sulfur impurities daily and their level was much lower than the specification limit delivering high quality products to customer. Conclusions Closely monitoring the quality of in-process and finished products from plant helped operators to make corrective actions immediately, in case there is increasing trend in these impurities or total sulfur. This has resulted in improvement of quality and their satisfaction giving more value for customers. Lower the level of sulfur impurities in our products, lower will be the environmental pollution through domestic usage or in power generation. It enhances the reputation of the company and generates more business and revenue. Novel / additive information The measurement of sulfur components is important for health, environmental and industrial (corrosion) protection. Environmental regulation require a gradually further decreasing emission of pollutants. The advancements developed have been documented and are suitable for monitoring quality and improvement. This is a valuable knowledge which will benefit other companies in oil and gas sector.
- Production and Well Operations (1.00)
- Health, Safety, Environment & Sustainability > Environment > Air emissions (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
Abstract An ADNOC operating company, GASCO is one of the world's largest natural and associated gas processing companies, with a processing capacity of 8 billion cubic feet of feed gas per day. Processing associated and non-associated gas, GASCO operates 3 desert plants for gas processing and natural gas liquids (NGL) extraction, a Natural Gas Liquids Fractionation facility and a pipeline distribution network. GASCO plays a strategic role in the ADNOC and UAE hydrocarbon chain, which makes it a vital enabler of industrial and economic progress of UAE. Gas yields substantial revenues from exports and is key for the country's electricity generation and water desalination. In a carbon constrained world, interest in its use is growing rapidly by all users, whether residential, commercial or industrial. As GASCO delivers on its responsibility as an economical and sustainable supplier of gas and related products, it seeks to drive operational excellence by focusing on people, performance, profitability and efficiency. The GASCO schematic is presented below for your reference.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > UAE Government (0.45)
- Asia > Middle East > UAE > Abu Dhabi > Rub' al Khali Basin > Ruwais Diyab Unconventional Gas Concession > Block 1 > Ruwais Field > Thamama Group Formation (0.93)
- Asia > Middle East > UAE > Abu Dhabi > Rub' al Khali Basin > Bu Hasa Field > Thamama Group > Shuaiba Formation (0.93)
- Asia > Middle East > UAE > Abu Dhabi > Rub' al Khali Basin > Asab Field > Thamama Group Formation (0.93)
- Production and Well Operations (1.00)
- Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (0.75)
- Data Science & Engineering Analytics > Information Management and Systems > Knowledge management (0.69)
- (2 more...)
Abstract PETRONAS has developed a Floating Liquefied Natural Gas (FLNG) to capitalize and monetize on the availability of the gas resulting from the development of several gas fields in Malaysia. FLNG is a concept where there is an integration of the floating production, storage and offloading unit with LNG production facilities on the deck. It refers to liquefied natural gas (LNG) operations employing technologies designed to enable the development of natural gas resources located offshore. Floating near to an offshore natural gas field, the FLNG facility will be able to produce, liquefy, store and carry out ship-to-ship transfer of LNG at sea before LNG carriers ship it directly to markets. Since everything is carried out at sea, there is no need to construct any jetty, breakwater ar even LNG tank farms. PETRONAS has taken a bold decision to embark on the first of its kind offshore LNG liquefaction facility. FLNG signifies PETRONAS’ technology advancement solution which adds value to marginal and stranded offshore gas resources which otherwise would be uneconomical to be developed, hence becomes a benchmark for the execution of similar-scale FLNG facility. PETRONAS Floating LNG concept was envisaged to monetise stranded gas resources. The two floaters namely PFLNG1 & PFLNG2 for offshore Sarawak and Sabah respectively will increase the country's LNG production capacity by approximately 8% (2.5 MTPA). This paper will highlight the first FLNG developed by PETRONAS; the PETRONAS Floating LNG Satu (PFLNG1). The PFLNG1 is designed based on a new built vessel rated for 1.2 MTPA LNG production capacities. The facility will receive feed gas from an identified gas fields which is operated by PETRONAS through a subsea pipeline at the water depth of about 77 meters. The design is based on a new built vessel with LNG storage capacity of 177,000 m3, condensate storage capacity of 20,000 m3. The design life for both hull and topside is for 20 years without the requirement for dry-docking. The hull was design in the ship-shaped form and adopted relevant marine standards and techical requirements. Earlier, the PFLNG1 was constructed at a shipyard located in South Korea. Upon the completion of the construction phase, the facility was towed to site before it was hooked up to the sea bed using the turret mooring system. The facility will have a weathervaning capability which allows it to rotate 360 degree around the turret to ensure right heading during its operation.
- Government > Regional Government > Asia Government > Malaysia Government (1.00)
- Energy > Oil & Gas > Midstream (1.00)