Eni has been present in Angola since 1980. In 2013, Eni’s production amounted to 87 kboe/d. Eni’s activities are concentrated in the conventional and deep offshore, over a developed and undeveloped acreage of 21,489 square kilometers (4,443 square kilometers net to Eni).
The main producing blocks with Eni’s participation are: (i) Block 0 in Cabinda (Eni’s interest 9.8%) North of the Angolan coast; (ii) Development Areas in the former Block 3 (Eni’s interest 12%) in the offshore of the Congo Basin; (iii) Development Areas in the Block 14 (Eni’s interest 20%) in the deep offshore west of Block 0; (iv) Development Areas in the former Block 15 (Eni’s interest 20%) in the deep offshore of the Congo Basin; and (v) Block 15/06 (Eni operator with a 35% interest) with ongoing development activities.
Eni retains interests in other non producing concessions, particularly the Lianzi Development Area (Block 14K/A Imi Unit Area - Eni’s interest 10%), Block 35/11 (Eni operator with a 30% interest) and in Block 3/05-A (Eni’s interest 12%), onshore Cabinda North (Eni’s interest 15%) and the Open Areas of Block 2 awarded to the Gas Project (Eni’s interest 20%).
Exploration and production activities in Angola are regulated by concessions and PSAs.
In the next four years, management expects to increase Eni’s production in Angola reflecting additions from ongoing development projects.
Production Block 0 is divided into Areas A and B. In 2013, production from this block amounted to approximately 303 kbbl/d (approximately 30 kbbl/d net to Eni). Oil production from Area A, deriving mainly from the Takula, Malongo and Mafumeira fields amounted to approximately 19 kbbl/d net to Eni. Production of Area B derives mainly from the Bomboco, Kokongo, Lomba, N’Dola, Nemba and Sanha fields, and amounted to approximately 11 kbbl/d net to Eni.
Development Activities progressed to reduce flaring gas at the Nemba field in the Area B. In 2015 once completed flared gas is expected to decrease by approximately 85% from current level. In the Area A, the development activities of the Mafumeira field included the installation of production and treatment platforms and underwater linkage. Start-up is expected by the end of 2015. Infilling activities and near-field exploration are underway on the whole block in order to mitigate the natural field production decline.
Production Block 3 is divided into three production offshore areas. In 2013, production from this block amounted to approximately 50 kbbl/d (approximately 3 kbbl/d net to Eni).
Development Concept Definition studies are underway in the Punja and Caco-Gazela discoveries.
Production In 2013, Development Areas in Block 14 produced approximately 139 kbbl/d (approximately 18 kbbl/d net to Eni), accounting for approximately 20% of Eni’s production in Angola. It is one of the most fruitful areas in the West African offshore, recording 9 commercial discoveries to date. Its main fields are: (i) Kuito, started-up in 1999, flowing at approximately 3 kbbl/d net to Eni in 2013; (ii) Landana and Tombua, started-up in 2009, flowing at approximately 9 kboe/d net to Eni. Production is supported by a Compliant Piled Tower (CPT) provided with treatment facilities; (iii) Benguela-Belize/Lobito-Tomboco, started-up in 2006, flowing at approximately 6 kbbl/d net to Eni. Production from these fields is supported by a CPT provided with treatment facilities for Benguela-Belize and an underwater linkage system for Lobito-Tomboco. Oil produced is treated at the Malongo plant. Associated gas of the area will be re-injected in the Nemba reservoir and later it will be delivered via a transport facility to the A-LNG liquefaction plant (see below).
Development The activities concerned mainly the Lianzi field in the Block 14K/A Imi (Eni’s interest 10%), through the linkage to the existing facilities. Concept Selection activities are ongoing at the Malange and Lucapa recent discoveries.
Production The Block produced approximately 385 kbbl/d (approximately 33 kbbl/d net to Eni) in 2013. Block 15 is considered the most interesting area in the West African offshore with recoverable reserves estimated at 2.55 bbbl of oil. Production derives mainly from the Kizomba discovery area with: (i) the Hungo/Chocalho fields, started-up in August 2004 as part of phase A of the global development plan of the Kizomba reserves; (ii) the Kissanje/Dikanza fields, started-up in July 2005, as part of Phase Kizomba B; (iii) satellites Kizomba Phase 1 project, started-up in 2012. These fields are operated by FPSO units. In 2013, the fields of Kizomba area produced approximately 278 kbbl/d (approximately 27 kbbl/d net to Eni).
Other main fields in Block 15 are Mondo and Saxi/Batuque fields which produced approximately 107 kbbl/d (approximately 6 kbbl/d net to Eni) in 2013.
In the medium term, phased development of satellite discoveries will mantain the current production plateau of the area.
Development The second phase of Kizomba satellites progressed as planned. The project provides to put into production three additional discoveries that will be linked to the existing FPSO. Start-up is expected at the end of 2015.
The activities concerned the development of two West Hub projects, sanctioned in 2010, and East Hub project, sanctioned in 2013.
The West Hub project includes the development of the Sangos, Cinguvu and Mpungi discoveries that will be added in the consecutive phase of the Vandumbu discoveries, which increases the potential of the hub to up to 200 mmbbl. First phase of West Hub project provides for the drilling of 21 subsea wells (12 producers and 9 injectors) linked to an FPSO unit with a capacity of 100 kbbl/d with start-up expected at the end of 2014 that will be added of the Vandumbu discoveries connected to the same FPSO. Peak production is expected at 80 kbbl/d in 2016.
The East Hub project provides for the development of the Cabaça South-East discovery with potential resources estimated at over 230 mmbbl. Development activity provides for the drilling of 10 subsea wells which will be linked to an FPSO unit with a capacity of 80 kbbl/d. Peak production is expected at 55 kbbl/d in 2017.
Further development phases are planned to start-up nearby discoveries.
Exploration activities yielded positive results in the area with the oil Vandumbu 1 discovery.
The LNG business in Angola
During the year, the LNG plant managed by the Angola LNG consortium (Eni’s interest 13.6%) started-up and delivered its first cargo in June 2013. LNG plant has a processing capacity of approximately 1.1 bcf/d of natural gas, producing 5.2 mmtonnes/y of LNG and over 50 kbbl/d of condensates and LPG. The plant envisages the development of 10,594 bcf of gas in 30 years.
Eni is part of the Gas Project (Eni’s interest 20%) that will apprise and explore further potential gas discoveries to support the feasibility of a second LNG train or other alternative projects to market gas and associated liquids.
Eni has been present in Congo since 1968. In 2013, production amounted to 120 kboe/d net to Eni. Eni’s activities are concentrated in the conventional and deep offshore facing Pointe-Noire and onshore covering a developed and undeveloped acreage of 4,725 square kilometers (3,125 square kilometers net to Eni).
In 2013 Eni acquired the operatorship of Ngolo exploration block, which is part of the Cuvette Basin, in the joint venture with the Congolese state company Société Nationale des Pétroles du Congo (SNPC). Exploration activities will take place over a period of 10 years. The Cuvette Basin is one of the new themes of frontier exploration activities in Africa.
During the year, Eni redefined with the relevant authorities the extension of Madingo, Marine VI and Marine VII exploration permits, with the aligning of expiring date within the period 2034-2039, the dilution of Eni’s stake and an acquisition interest in new high potential area. The approval of the relevant authorities is in progress.
Exploration and production activities in Congo are regulated by PSAs.
In the medium term, management expects to increase Eni’s production in Congo due to ongoing development projects.
Production Eni’s main operated oil producing interests in Congo are the Zatchi (Eni’s interest 65%), Loango (Eni’s interest 50%), Ikalou (Eni’s interest 100%), Djambala, Foukanda and Mwafi (Eni’s interest 35%), Kitina (Eni’s interest 65%), Awa Paloukou (Eni’s interest 90%), M’Boundi (Eni’s interest 83%), Kouakouala (Eni’s interest 75%), Zingali and Loufika (Eni’s interest 85%) fields, with a production of approximately 90 Kboe/d in 2013. Non operated fields are located in the PEX, Pointe Noire Grand Fond and Likouala permits (Eni’s interest 35%), with an overall production of approximately 30 kboe/d in 2013.
Development Activities on the M’Boundi (Eni operator with 83% interest) field moved forward with the application of Eni advanced recovery techniques and a design to monetize associated gas. Gas is sold under long-term contracts to power plants in the area including the CEC Centrale Electrique du Congo (Eni’s interest 20%) with a 300 MW generation capacity. These facilities will also receive in the future gas from the offshore discoveries of the Marine XII permit (Eni operator with a 65% interest). In 2013 M’Boundi contractual supplies were approximately 106 mmcf/d (approximately 17 kboe/d net to Eni). Additional gas production will be re-injected within the Eni’s zero gas flaring programs.
During the year activities progressed to support the population in M’Boundi area. The social project for 25,000 people provides to improve education, production capacity in agriculture, health, access to water and energy.
Development program progressed at the Litchendjili sanctioned project in the Marine XII permit. The project provides for the installation of a production platform, the construction of transport facilities and of an onshore treatment plant. The start-up is expected by the end of 2015, with a production plateau of approximately 12 kboe/d net to Eni. Production will also feed the CEC power station.
Exploration Exploration activities yielded positive results in the offshore block Marine XII with the oil and gas discovery and the appraisal of the Nenè Marine field and with the appraisal of gas and condensates discovery of Litchendjili field. The overall discoveries potential is estimated in 2.5 billion boe in place. The block has a further significant oil and gas potential that will be assessed by the next exploratory and delineation campaign. The proximity to existing facilities, good productivity of reservoir and low cost will allow to fast track development, targeting start-up in 2015.
Eni has been present in Mozambique since 2006. Eni is operator of Area 4 Block located in the offshore Rovuma Basin, which represents a new frontier in oil and gas industry thanks to extraordinary gas discoveries made during intense two-year exploration campaign. To date, resource base reached 2,650 bcm located in the different sections of the area.
On July 26, 2013, Eni concluded the sale of a 28.57% interest in Eni East Africa (EEA) to China National Petroleum Corporation (CNPC). EEA retains a 70% interest in the Area 4 mineral property, located offshore of Mozambique. CNPC indirectly acquires, through its equity investment in Eni East Africa, a 20% interest in Area 4, while Eni retains operatorship and a 50% interest through the remaining stake. The total consideration was equal to €3,386 million. The exploration campaign of the year regarded the appraisal of the Mamba and Coral discoveries. In particular, the delineation of Mamba discovery used the results of the implementation of the propriety process, which includes a study on reservoir characterization, data processing (e-dva™) and analyses of seismic scale.
In 2013 Eni made the Agulha discovery, the tenth discovery in a new exploration prospect located in the southern part of Area 4. In 2014, Eni will continue appraisal activities, particularly regarding the new exploration prospect, where the drilling of two to three additional wells is planned.
Leveraging on Eni’s cooperation model, the construction of a gas fired power plant for domestic consumption is being planned with the support of the Mozambican government.
In addition, a significant program of ecosystems evaluation and the analysis of biodiversity in the Country were started. This program will be included in the development project of recent discoveries. Eni continues its recruitment and local training program in order to support the activities of hydrocarbons exploration in the Country. In particular the training program that started with the University of Mozambique involved 75 students during the year.
Eni has been present in Nigeria since 1962. In 2013, Eni’s oil and gas production amounted to 125 kboe/d over a developed and undeveloped acreage of 36,286 square kilometers (7,646 square kilometers net to Eni) located mainly in the onshore and offshore of the Niger Delta.
In the development/production phase Eni operates onshore Oil Mining Leases (OML) 60, 61, 62 and 63 (Eni’s interest 20%); and offshore OML 125 (Eni’s interest 85%) and OPL 245 (Eni’s interest 50%), holding interests in OML 118 (Eni’s interest 12.5%) and in OML 119 and 116 Service Contracts.
As partners of SPDC JV, the largest joint venture in the Country, Eni also holds a 5% interest in 22 onshore blocks and a 12.86% interest in 5 conventional offshore blocks.
In the exploration phase Eni operates offshore OML 134 (Eni’s interest 85%) and OPL 2009 (Eni’s interest 49%); onshore OPL 282 (Eni’s interest 90%) and OPL 135 (Eni’s interest 48%). Eni also holds a 12.5% interest in OML 135.
In the year, Eni launched: (i) programs to support local development for improving access to health, initiatives in agriculture development and access to education; (ii) technical support from the ESP Excellence Centre for data performance analysis in different production site of the Country. Real-time monitoring at the producing wells allowed to avoid possible disruptions.
Exploration and production activities in Nigeria are regulated mainly by production sharing agreements and concession contracts as well as service contracts, in two blocks, where Eni acts as contractor for state-owned company.
Blocks OMLs 60, 61, 62 and 63
Production Onshore licenses OMLs 60, 61, 62 and 63 produced approximately 53 kboe/d and accounted for 43% of Eni’s production in Nigeria in 2013. Liquid and gas production is supported by the NGL plant at Obiafu-Obrikom with a treatment capacity of approximately 1 bcf/d and by the oil tanker terminal at Brass with a storage capacity of approximately 3.5 mmbbl. A large portion of the gas reserves of these four OMLs is destined to supply the Bonny Island liquefaction plant (see below). Another portion of gas production is employed in firing the combined cycle power plant at Kwale-Okpai with a 480 MW generation capacity. In 2013, supplies to this power station were an overall amount of approximately 70 mmcf/d, corresponding to approximately 10 kboe/d (approximately 2 kboe/d net to Eni).
Development Main activities progressed to support gas production to feed the Bonny liquefaction plant. In particular, the Ogbainbiri flowstation was completed with a decline in flared gas of approximately 5 mmcf/d. This facility ensured to treat natural gas production of Ogbainbiri field. In the year, flaring down program includes a reduction of approximately 50 mmcf/d of gas flared leveraging on the upgrade of Idu flowstation completed at the end of 2012; as well as flaring down of Akri with a reduction of approximately 25 mmcf/d of gas flared.
Block OML 118
Production The Bonga oil field produced approximately 13 kbbl/d of oil net to Eni in 2013. Production is supported by an FPSO unit with a 225 kbbl/d treatment capacity and a 2 mmbbl storage capacity. Associated gas is carried to a collection platform on the EA field and, from there, is delivered to the Bonny liquefaction plant.
Development The activities of the year concerned Bonga NW field. The development project provides for the drilling and completion of producing and infilling wells.
Block OML 119
Production Production derived mainly from the Okono/Okpoho fields which yielded approximately 2 kbbl/d of oil net to Eni in 2013. Production is supported by an FPSO unit with an 80 kbbl/d treatment capacity and a 1 mmbbl storage capacity.
Block OML 116
Production Production derived mainly from the Agbara field which yielded approximately 3 kbbl/d of oil net to Eni in 2013.
Block OML 125
Production The Abo field production amounted to approximately 19 kbbl/d of oil net to Eni in 2013. Production is supported by an FPSO unit with a 45 kbbl/d capacity and an 800 kbbl storage capacity.
The Abo - Phase 3 project started-up, with production of approximately 5 kboe/d net to Eni. This project was sanctioned at the end of 2012 and was used an innovative technology for the installation of the intelligent control at the producing wells for simultaneous production start-up from the different reservoir levels. This technology allowed a fast track installation with significant savings.
SPDC Joint Venture (NASE)
In 2013, production from the SPDC JV accounted for approximately 28% of Eni’s production in Nigeria (35 kboe/d).
In Block OML 28 (Eni’s interest 5%), within the integrated oil and natural gas project in the Gbaran-Ubie area, the drilling and development campaign was concluded. The development plan provides for the construction of a Central Processing Facility (CPF) with treatment capacity of approximately 1 bcf/d of gas and 120 kbbl/d of liquids. Further development phases are planned to put in production the residual mineral potential in the area.
Other activity during the year concerned the Forkados-Yokri field (Eni’s interest 5%). The project includes the drilling of 24 producing wells, the upgrading of existing flowstations and the construction of transport facilities.
Eni holds a 10.4% interest in the Nigeria LNG Ltd which runs the Bonny liquefaction plant, located in the Eastern Niger Delta. The plant has a design treatment capacity of approximately 1,236 BCF/y of feed gas corresponding to a production of 22 mmtonnes/y of LNG on six trains. The seventh unit is being engineered as it is in the planning phase. When fully operational, total capacity will amount to approximately 30 mmtonnes/y of LNG, corresponding to a feedstock of approximately 1,624 bcf/y. Natural gas supplies to the plant are provided under gas supply agreements with a 20-year term from the SPDC joint venture (Eni’s interest 5%) and the NAOC JV, the latter operating the OMLs 60, 61, 62 and 63 Blocks with an overall amount of 2,825 mmcf/d (268 mmcf/d net to Eni corresponding to approximately 49 kboe/d). LNG production is sold under long-term contracts and exported to European and American markets by the Bonny Gas Transport fleet, wholly owned by Nigeria LNG Co.
Eni holds a 17% interest in Brass LNG Ltd Co for the construction of a natural gas liquefaction plant to be built near the existing Brass terminal, 100 kilometers west of Bonny. This plant is expected to start with a production capacity of 10 mmtonnes/y of LNG corresponding to 590 bcf/y (approximately 45 net to Eni) of feed gas on two trains for twenty years. Supply to this plant will derive from the collection of associated gas from nearby producing fields and from the development of gas reserves in the onshore OMLs 60 and 61.