Located approximately 46 miles (75 km) off the coast of Pointe-Noire in water depths ranging from 2,400 to 4,000 feet (750 to 1,200 meters), Moho Bilondo Phase 1b is part of the Moho Nord joint development project, the largest-ever oil and gas project undertaken in the Republic of Congo. The Moho Bilondo Phase 1b project includes 11 wells tied back to an existing floating production unit and is expected to produce a total of 40,000 barrels of oil per day.

“First oil from the Moho Bilondo Phase 1b development is the latest successful start-up in our diverse portfolio of deepwater projects, which we expect to generate value for years to come,” said Jay Johnson, executive vice president Upstream, Chevron Corporation.

“The successful development of Phase 1b demonstrates our ongoing commitment to the Republic of Congo and is a testament to industry and government cooperation,” said Ali Moshiri, president of Chevron Africa and Latin America Exploration and Production Company. “The project integrates the unique skills and expertise of multiple partners to deliver challenging projects and new energy production.”

The Phase 1b development targeted reserves in the southern portion of the Moho Bilondo permit area. The Moho Nord subsea development, which will be the second phase of the Moho Nord joint development project, is in the northern part of the area.

The Moho Nord development project involves a tension-leg platform, a floating production unit with a processing capacity of 100,000 barrels of oil per day, and a 50-mile (80-kilometer) pipeline to the onshore Djeno Terminal.

Chevron Overseas (Congo) Limited has a 31.5 percent working interest in the Moho Bilondo permit area, along with Total E&P Congo (53.5 percent working interest and operator) and the national oil company, Société Nationale des Pétroles du Congo (15 percent working interest).

• Chevron Confirms First Production from the Moho Bilondo Phase 1b Development Offshore the Republic of Congo

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The agreements will lead to investment for more than $2 billion for the realization of projects to be implemented in the next 4 years and will contribute effectively to the increasing energy needs of Egyptian local demand. Furthermore, they represent the positive conclusion of a first set of agreements that were defined in the Heads of Agreement (HoA) signed during the Egypt Economic Development Conference in Sharm El Sheikh last March. Other three agreements included in the HoA have been already finalized whereas the approval process is expected to be completed before the year-end. Some of the activities envisaged are currently in the execution phase and one additional well in Baltim Concession is already in production.

Eni has been present in Egypt since 1954, where it operates through its subsidiary IEOC. The company is the leading producer in the country with an equity production of approximately 180 thousand barrels of oil equivalent per day.

• Eni signs concession and amendment agreements for petroleum exploration in Egypt

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Located 65 miles (105 km) offshore in approximately 3,000 feet (900 meters) of water, Lianzi is Chevron’s first operated asset in the Republic of Congo and the first cross-border oil development project offshore Central Africa. The project is expected to produce an average of 40,000 barrels of crude oil per day.

“This milestone demonstrates that we continue to make steady progress on delivering major development projects,” said Jay Johnson, executive vice president Upstream, Chevron Corporation. “We have the industry’s strongest queue of major capital projects that are expected deliver significant value and production growth.”

“As the first offshore energy development spanning national boundaries in the Central Africa region, Lianzi represents a unique cooperative approach to share offshore resources and may serve as a model for the development of similar cross-border fields between two countries,” said Ali Moshiri, president of Chevron Africa and Latin America Exploration and Production Company.

The field, discovered in 2004, includes a subsea production system and a 27 mile (43 km) electrically heated flowline system, the first of its kind at this water depth. The system transports the oil from the field to the Benguela Belize–Lobito Tomboco platform in Angola’s Block 14 and utilizes a Direct Electrical Heating (DEH) system to ensure fluid flow under a wide range of conditions.

Chevron Overseas (Congo) Limited is operator of the Lianzi Field and has a 15.75 percent interest, along with its affiliate Cabinda Gulf Oil Company Limited (15.5 percent), Total E&P Congo (26.75 percent), Angola Block 14 BV (10 percent), Eni (10 percent), Sonangol P&P (10 percent), SNPC (the Republic of Congo National Oil Company - 7.5 percent), and GALP (4.5 percent).

• Chevron Announces First Production from the Lianzi Development Offshore the Republic of Congo and Angola

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Eni has been awarded a 37.5% participating interest and operatorship in North El Hammad, where it partners with BP (37.5%) and Total (25%), and a 50% participating interest in North Ras El Esh, where it partners with BP (50%) which will act as operator.

The two blocks, which will be managed by Eni’s subsidiary IEOC, are in the shallow waters of the Mediterranean Sea, facing the Nile Delta and located southwest of the Temsah area and west of the Baltim area, where Eni operates existing fields and production facilities.

The North El Hammad and North Ras El Esh blocks cover areas of 1,389 and 1,927 square kilometers respectively.

These two new concession agreements follow the recent award of the deep water Karawan and North Leil blocks, strengthening Eni’s presence in Egypt, a country of historic and strategic importance for the Company, and further relaunching its exploration activities after the recent and important successes of Nidoco NW and Zohr.

Eni has been present in Egypt since 1954 and is the main producer in the country with an equity of approximately 190,000 barrels of oil equivalent per day.

• Eni awarded two new exploration licenses in the Egyptian offshore of the Mediterranean Sea

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Andrew Brown, Shell’s Upstream International Director, said: “This new start up is another important milestone for Bonga, adding valuable new production to this major facility.”

Bonga Phase 3 is an expansion of the Bonga Main development, with peak production expected to be some 50,000 barrels of oil equivalent. This will be transported through existing pipelines to the Bonga floating production storage and offloading (FPSO) facility, which has the capacity to produce more than 200,000 barrels of oil and 150 million standard cubic feet of gas a day.

The Bonga field, which began producing oil and gas in 2005, was Nigeria’s first deep-water development in depths of more than 1,000 metres. Bonga has produced over 600 million barrels of oil to date.

The Bonga project is operated by SNEPCo as contractor under a production sharing contract with the Nigerian National Petroleum Company, which holds the lease for OML 118, in which the Bonga field is located. SNEPCo holds a 55% contractor interest in OML 118. The other co-venturers are Esso Exploration & Production Nigeria Ltd (20%), Total E&P Nigeria Ltd (12.5%) and Nigerian Agip Exploration Ltd (12.5%).

• Shell commences production from Bonga Phase 3 project in Nigeria

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This field is located approximately 350 kilometers north of Luanda, at water depths of 450-600 meters. The contract covers project management and manufacture of about 15 kilometers of dynamic and static steel tube umbilicals.

Technip Umbilicals facility in Lobito, Angola, with support from Technip Umbilicals in Newcastle, UK, will manufacture the umbilicals that are scheduled to be completed in the second half of 2016. This project follows on Technip Umbilicals’ successful completion of many deep water West African projects seen in recent years.

Sarah Cridland, Managing Director of Technip Umbilicals, said: “This award of Block 15/06 East Hub Development is a recognition of the quality and performance of the umbilicals provided by Technip. We are proud to be awarded this contract and will utilize our expertise across multiple Technip Umbilicals sites whilst strengthening our relationship with ENI.”

Reinforcing Technip’s relationship with ENI, this new contract follows another project awarded to Technip last year for the fabrication and installation of flexible and rigid pipelines at Block 15/06.

• Technip awarded umbilical supply contract by ENI

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The Erha North Phase 2 project is a deepwater subsea development located 60 miles offshore Nigeria in 3,300 feet of water and four miles north of the Erha field, which has been producing since 2006. The Erha North Phase 2 project includes seven wells from three drill centers tied back to the existing Erha North floating production, storage and offloading vessel, reducing additional infrastructure requirements.

The project is estimated to develop an additional 165 million barrels from the currently producing Erha North field. Peak production from the expansion is currently estimated at 65,000 barrels of oil per day and will increase total Erha North field production to approximately 90,000 barrels per day.

“Executing successful projects such as Erha North Phase 2 ahead of schedule and under budget results from ExxonMobil’s disciplined project management approach and expertise,” said Neil W. Duffin, president of ExxonMobil Development Company. “We are able to create additional shareholder value by optimizing existing infrastructure, which reduces capital spending requirements and improves capital efficiency.”

Duffin said the ahead-of-schedule startup was supported by strong performance from Nigerian contractors, which accounted for more than $2 billion of project investment for goods and services, including subsea equipment, facilities and offshore installation.

“These contracts are bringing direct and indirect benefits to the Nigerian economy through project spending and employment, consistent with project objectives,” Duffin said.

ExxonMobil expects to increase its global production volumes this year by 2 percent to 4.1 million oil-equivalent barrels per day, driven by 7 percent liquids growth. The volume increase is supported by the ramp up of projects completed in 2014 and the expected startup of major developments in 2015.

The Erha North field was discovered in 2004 and initial production commenced in 2006. Operator Esso Exploration and Production Nigeria Limited holds a 56.25 percent interest in Erha North Phase 2, while Shell Nigeria Exploration and Production Company holds the remaining 43.75 percent share.

• ExxonMobil Starts Oil Production at Erha North Phase 2 Project Ahead of Schedule and Well Under Budget

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According to the well and seismic information available, the discovery could hold a potential of 30 trillion cubic feet of lean gas in place (5.5 billion barrels of oil equivalent in place) covering an area of about 100 square kilometres. Zohr is the largest gas discovery ever made in Egypt and in the Mediterranean Sea and could become one of the world’s largest natural-gas finds. This exploration success will give a major contribution in satisfying Egypt’s natural gas demand for decades.

Eni will immediately appraise the field with the aim of accelerating a fast track development of the discovery that will utilise at best the existing offshore and onshore infrastructures.

Zohr 1X NFW was drilled to a total depth of approximately 13,553 feet (4,131 metres) and hit 2,067 feet (630 metres) of hydrocarbon column in a carbonate sequence of Miocene age with excellent reservoir characteristics (400 metresplus of net pay). Zohr’s structure has also a deeper Cretaceous upside that will be targeted in the future with a dedicated well.

Eni’s CEO, Claudio Descalzi, has recently travelled to Cairo to update Egypt’s President, Abdel Fattah Al-Sisi, on this important success, and discuss this discovery with the Prime Minister, Ibrahim Mahlab, and the Minister of Petroleum and Mineral Resources, Sherif Ismail.

“It’s a very important day for Eni and its people. This outstanding result confirms our expertise and our technological innovation capacity with immediate operational application, and above all shows the strength of the cooperation spirit amongst all the company’s units which are at the foundation of our great successes. Our exploration strategy allows us to persist in the mature areas of countries which we have known for decades and has proved to be winning, reconfirming that Egypt has still great potential. This historic discovery will be able to transform the energy scenario of Egypt in which we have been welcomed for over 60 years. The exploration activities are central to our growth strategy: in the last 7 years we have discovered 10 billion barrels of resources and 300 million in the first half of the year, confirming Eni’s leading position in the industry. This exploration success acquires an even greater value as it was made in Egypt which is strategic for Eni, and where important synergies with the existing infrastructures can be exploited allowing us a fast production startup‘, Claudio Descalzi commented.

Eni, through its subsidiary IEOC Production B.V., holds a 100% of the Contractor’s working interest in the Shorouk Block and is the operator of the concession. Eni has been present in Egypt since 1954 through its subsidiary IEOC, a company which has always been a frontrunner in exploring and exploiting gas resources in Egypt since the discovery of the Abu Maadi Field in 1967.

By adopting new exploration concepts, leading edge technologies and operational approaches, through AGIBA and Petrobel, operating companies participated by IEOC and EGPC, Eni has successfully managed to double production of oil from the Western Desert and the GOS Abu Rudeis Concessions in the last three years as well as to revamp production from the Abu Maadi plays in the Nile Delta area following the recently announced Nidoco NW 2 discovery (Nooros prospect) currently already in production.

Eni is the main hydrocarbon producer in Egypt, with a daily equity production of 200,000 barrels of oil equivalent.

• Eni discovers a supergiant gas field in the Egyptian offshore, the largest ever found in the Mediterranean Sea

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The value of the consultancy contract, to be delivered by experts in Amec Foster Wheeler’s Reading office, has not been announced.

The specialist consultancy work will support Sonatrach’s aim to operate the Hassi R’Mel gas field well into the future, enabling Algeria to remain a major exporter of gas. The engineering design services involve a major flow assurance exercise using Amec Foster Wheeler’s proprietary software to identify future bottlenecks in the gas field gathering network. In addition, the team will undertake detailed pipeline design, compression studies and the multi-disciplined specification of the additional infrastructure required to allow continued production.

Roberto Penno, Amec Foster Wheeler’s Group President for Asia, Middle East, Africa & Southern Europe, said: “We are delighted to be working with Sonatrach again on this major development using our considerable upstream and pipelines expertise, and hope to further build the relationship by supporting them with their future plans in the region.”

• Amec Foster Wheeler awarded consultancy contract by Sonatrach in Algeria

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The investment has an estimated total value of 1.5 billion US dollars, aims at maximizing diesel production, will introduce the most modern refinery technologies in Upper Egypt and satisfies the growing local demand from petroleum products.

According to the agreement announced today, Technip will now start activities for the project, as well as providing support to ensure project financing. SACE is ready to evaluate a possible intervention to support the project.

In due course, Technip will take responsibility for the EPC phase of the project.

This agreement was signed during the visit of the Egyptian Government in Italy, in the presence of the Egyptian Prime Minister Ibrahim Mahlab, the Italian Prime Minister Matteo Renzi, the Egyptian Minister of Petroleum and Mineral Resources Sherif Ismail, the Italian Deputy Minister of Economic Development Carlo Calenda and the Representatives of the involved Companies: Mohamed Taher Hafez, Deputy CEO for Planning and Projects of EGPC, Mohamed Allam Ahmed, Chairman of ASORC and Marco Villa, CEO of Technip Italy S.p.A.

• Technip, EGPC And Asorc Agreement For The Assiut Refinery

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The investment has an estimated total value of 1.4 billion US dollars and aims at improving the production quality of the plant, considered the most advanced of the African continent, by increasing its refining capacity from 100,000 to 160,000 barrels of crude oil per day.

According to the agreement announced today, SACE commits to launch the evaluation process in order to ensure an export credit facility to support the project. Technip will in parallel start the activities on the project.

In due course, Technip will take responsibility for the EPC phase of the project.

This agreement was signed during the visit of the Egyptian Government in Italy, in the presence of the Egyptian Prime Minister Ibrahim Mahlab, the Italian Prime Minister Matteo Renzi, the Egyptian Minister of Petroleum and Mineral Resources Sherif Ismail, the Italian Deputy Minister of Economic Development Carlo Calenda and the Representatives of the involved Companies: Mohamed Abdel Aziz Chairman and CEO of Midor, Marco Villa, CEO of Technip Italy S.p.A. and Alessandro Castellano CEO of SACE.

• Technip, Sace And Midor Agreement For The Alexandria Refinery

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“The Dalia FPSO came on stream nearly nine years ago and with the addition of Phase 1A will still produce around 200,000 b/d. It is the latest milestone in the success story of Block 17, Total’s most prolific license with cumulative production reaching two billion barrels in May 2015,” explained Arnaud Breuillac, President Exploration & Production. “Dalia Phase 1A demonstrates Total’s commitment to maximizing value through the optimal use of existing facilities. These types of profitable satellite tie-back developments play an important role in maintaining production levels and generating additional free cash flow for the Group.”

The Dalia Phase 1A project involves the drilling of seven infill wells tied back to the Dalia Floating Production Storage and Offloading (FPSO) unit.

Total Exploration & Production in Angola

Total celebrated its 60th anniversary in Angola in 2013. In 2014, the Group’s equity production reached 200,000 barrels of oil equivalent per day (boe/d), coming essentially from Blocks 17, 0 and 14. In early 2015, Total’s operated production exceeded 700,000 boe/d, making it the country’s leading oil operator.

Total operates Block 17 with a 40% interest alongside Statoil (23.33%), Esso Exploration Angola Block 17 Ltd (20%) and BP Exploration Angola Ltd (16.67%). Sonangol is the concessionaire of the license. The Group operates four FPSO units on the major production zones of the block: Girassol, Dalia, Pazflor and CLOV.

Total also operates with a 30% interest the ultra deep offshore Kaombo development located on Block 32. A final investment decision was made in April 2014 to develop Kaombo’s estimated reserves of 650 Mb via two converted FPSOs with a total production capacity of 230,000 b/d.

• Angola: Total starts up production from Dalia Phase 1A on deep offshore Block

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Preliminary estimates of the discovery account for a potential of 15 billion cubic meters of gas in place with upside, plus associated condensates.

Eni achieved the important exploration success through the Nidoco NW2 Dir NFW well, which reached a total depth of 3,600 meters and encountered a 60 meters thick gas bearing sandstone interval of Messianian age with excellent petrophysical properties, further of other gas layers in the overlying Pliocene section.

The new discovery will be put into production in two months’ time through a tie-in to the existing Abu Madi gas treatment plant, located 25 kilometers south-east.

This discovery is the result of the new Eni’s strategy to re-focus its activity on near field and incremental exploration opportunities with high potential value, which allow in case of success their quick exploitation through the already existing and synergic nearby infrastructures.

Eni, through its subsidiary Ieoc Production BV, holds a 75% of working interest in the West Abu Madi development lease, with BP as a partner with 25%. Petrobel, equally owned by Ieoc (50%) and EGPC (50%), is the operator of the concession.

Eni has been present in Egypt since 1954 through its Ieoc subsidiary and is the main hydrocarbon producer in the country, with a daily equity production of 180,000 barrels of oil equivalent.

• Eni: important gas discovery in the Egyptian Nile Delta

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The operator Total has a 30% share on Block 32. The other partners are Sonangol Pesquisa & Produção (30%), Sonangol Sinopec International Limited (20%), Esso (15%) and Galp (5%).

Scope of supply is for two identical produced water treatment systems that will each process 170,000 BPD produced water. The systems comprise Alderley’s AP20 de-oiling hydrocyclones, Alderley’s AP25 de-sanding hydrocyclones, Compact Flotation Unit (CFU), a sand wash vessel and an additional oily water reject treatment stage.

The complete produced water treatment system is designed to meet the oil-in-water discharge levels of <20mg/l and 0.5% by weight, oil on sand.

Tony Mansfield, Managing Director, Alderley Process Technologies, comments, “Alderley have delivered a number of produced water treatment packages specifically designed for an FPSO environment. We recognise the strategic importance of this flagship project for Total and its partners and we are proud to be able to leverage on our extensive experience to offer the best technologies for their produced water requirements.”

The systems are being designed and engineered by Alderley Process Technologies team in the UK and manufacturing will take place in the Middle and Far East.

Alderley Process Technologies is part of the Alderley Group and provides the full range of services for engineering, supply and operation of produced water treatment solutions globally.

• Awarded FPSO Produced Water Treatment Packages

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Bumi Armada, an international offshore services provider based in Malaysia, is building the FPSO by reconfiguring the former Armada Ali supertanker (now renamed the Armada Olombendo FPSO), which has a storage capacity of 1.8 million barrels. The Italian energy company Eni is chartering the vessel.

Illustration of an FPSO

It will be positioned over the Cabaça North and Cabaça Southeast fields, about 350 kilometers northeast of Luanda, and producing up to 80,000 barrels a day by the end of 2016. With fields so far off shore and 500 meters below the ocean’s surface, the vessel will control the entire extraction process, storing oil and gas until they can be offloaded to shuttle tankers.

To enable and monitor safe and reliable operations, ABB will deliver complete e-house solutions - which house medium voltage and low voltage switchgear - and systems for integrated electrical distribution, control, safety and power management, including ABB’s 800xA distributed control system.

“FPSO vessels offer a competitive solution for the development of deep water and remote oil and gas fields, such as those in the West of Africa. We are pleased to contribute to Bumi Armada Berhad’s latest FPSO project to ensure safe and reliable floating production,” said Stein Guldbrandsoy, ABB’s Global Market Segment Manager for Floating Production Units.

“We aim for long-term partnerships with customers through successful project execution, innovative offshore technology and an extensive service footprint," said Per Erik Holsten, Managing Director for ABB's Oil, Gas and Chemicals business.

Electrical house (e-house) delivery from ABB

ABB’s systems will distribute and manage power necessary to inject 120,000 barrels of water a day into the reservoir and to compress up toDocument Link Icon 120,000 million cubic feet of natural gas.

This order is the fourth collaboration between ABB and Bumi Armada, the fifth largest FPSO supplier in the world. Past projects include a modular e-house package for FPSO vessels operating off India’s west coast, the Kraken oil field in the North Sea and a complete automation package for an FPSO vessel operating in the Balnaves oil field off western Australia.

Eni is the concessionaire of the Cabaça fields, which were discovered in 2009. They’re estimated to have a capacity of some 230 million barrels. The total value of Bumi Armada Berhad’s contract to supply, operate and maintain the FPSO is about $2.9 billion.

• ABB to provide power and automation solutions for new Angolan oil field

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For this project, Axens offered:

• Naphtha Hydrotreater (NHT).
• Continuous catalytic Reformer (CCR) using Axens Octanizing™ technology.
• C5/C6 isomerization unit with deisohexanizer recycle unit.
• In addition Axens, will provide catalysts, adsorbents, equipment and technical support. The capacity of the project is 660,000 tons per year of naphtha processed.

Assiut Oil Refining Company (ASORC)

Assiut Oil Refining Company (ASORC) is subsidiary of Egyptian General Petroleum Corporation (EGPC) was established in October 1984 to meet upper Egypt's needs of petroleum products, the location of ASORC is 400 Km south of Cairo and it's built over 1037 Acres, the grass-roots refinery was 2.5 MM T/Y of distillation crude and has increased to 4.5 MM T/Y by adding the second crude distillation unit in 2002, ASORC starts building a new Naphtha complex (NHT, CCR and Isomerization unit) with a capacity 660,000 T/Yto Provide high octane gasoline& different grades of gasoline for Upper Egypt.

• Axens to provide technologies for the production of high octane gasoline in Upper Egypt

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The discovery was made through the A1-1/1 well, drilled at a water depth of 125 meters, which encountered gas and condensates in the Metlaoui Group of Eocene age. During the production test, constrained by surface facilities, the well flowed 1,340 Boepd with a “64/64‘ choke size. In production configuration, the well is estimated to deliver in excess of 3,000 Boepd.

The well represents the second discovery made by Eni in Libyan offshore Area D since the beginning of 2015.

Eni, through its subsidiary Eni North Africa BV, is operator of Contract Area D with 100% working interest in the exploration phase. Eni has been present in Libya since 1959 and currently produces more than 300,000 barrels of oil equivalent per day in the Country.

• Eni: new gas and condensates discovery offshore Libya

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The well was drilled by ExxonMobil affiliate, Esso Exploration and Production Guyana Ltd., and encountered more than 295 feet (90 meters) of high-quality oil-bearing sandstone reservoirs. It was safely drilled to 17,825 feet (5,433 meters) in 5,719 feet (1,743 meters) of water. Stabroek Block is 6.6 million acres (26,800 square kilometers).

“I am encouraged by the results of the first well on the Stabroek Block,” said Stephen M. Greenlee, president of ExxonMobil Exploration Company. “Over the coming months we will work to determine the commercial viability of the discovered resource, as well as evaluate other resource potential on the block.”

The well was spud on March 5, 2015. The well data will be analyzed in the coming months to better determine the full resource potential.

Liza-1 well encounters more than 295 feet of high-quality oil-bearing sandstone reservoirs

Esso Exploration and Production Guyana Ltd. holds 45 percent interest. Hess Guyana Exploration Limited holds 30 percent interest and CNOOC Nexen Petroleum Guyana Limited holds 25 percent interest.

• ExxonMobil Announces Significant Oil Discovery Offshore Guyana

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The selection of CCS JV is subject to negotiation and entry into a definitive agreement prior to Anadarko and its co-venturers taking a Final Investment Decision (FID).

The initial scope of work for the onshore LNG park includes two LNG trains, each with a capacity of six million tonnes per annum, two LNG storage tanks, condensate storage, multi-berth marine jetty and associated utilities and infrastructure.

CCS JV has a long-term relationship with Anadarko and its partners for the planning and development of this project and will bring the three companies’ substantial LNG experiences to successfully complete the onshore LNG park in Mozambique.

• Saipem Joint Venture with Chiyoda and CB&I Selected as Contractor for Mozambique LNG Development

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Dangote Oil Refining Company selected UOP technology for a world-scale integrated refinery and petrochemical plant to be built in Lekki, near the capital of Lagos in southwestern Nigeria.

Nigeria has the second-largest amount of proven oil reserves in Africa – an estimated 37.2 billion barrels, according to Oil & Gas Journal. However, the country currently imports most of its refined product requirements due to lack of domestic refining capacity.

"UOP has been designing state-of-the-art refineries and petrochemical plants for more than a century, so we are well-equipped to help Nigeria develop a massive new installation to meet its domestic needs," said Pete Piotrowski, senior vice president and general manager of UOP's Process, Technology and Equipment business. "This project will enable Dangote to improve Nigeria's oil refining capabilities, reduce the country's dependence on imports, and work to revive and transform the Nigerian economy."

The Dangote Group is the largest industrial conglomerate in West Africa and one of the largest in Africa. The company has a number of interests, including cement, real estate, oil, natural gas, telecommunications, fertilizer and steel. The Group focuses on local, value-added products and services that meet the needs of the African population.

In addition to processing crude oil to produce high-quality gasoline, diesel and jet fuel that meet Euro V specifications for reduced emissions, the new facility will produce world-scale quantities of polypropylene, a key petrochemical used in plastics and packaging.

UOP technologies at this facility will include:

• The UOP Resid Fluid Catalytic Cracking process to produce transportation fuels from crude oil. It will also supply propylene, which will be used as a feedstock for polypropylene.
• The CCR Platforming™ process to produce high-octane gasoline blending components.
• The Unicracking™ process to produce diesel.
• The Penex™ process to produce high-octane gasoline.
• The crude distillation unit (CDU) design, which will be provided by UOP's alliance partner, Process Consulting Services

In addition to technology licensing and design services, the UOP organization is working with Dangote Oil Refining Company to provide catalysts, adsorbents and proprietary equipment for the project.

• Technology From Honeywell's UOP To Run Largest Refinery In Africa

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