A Barrel Fulll Archive

 September 5, 2017 Canadian Natural Resources Limited (“Canadian Natural” or the “Company”) announces that is has entered into an agreement to acquire assets in the Greater Pelican Lake region and other miscellaneous assets in northern Alberta with production of approximately 19,600 BOE/d, for gross cash consideration of $975 million. The transaction is targeted to close on or before September 30, 2017, subject to normal closing conditions and approvals. For more information on this core area acquisition, please see the Company’s website at www.cnrl.com. Canadian Natural is a senior oil and natural gas production company, with continuing operations in its core areas located in Western Canada, the U.K. portion of the North Sea and Offshore Africa.

August 31, 2018 Canadian Natural Resources Limited (“Canadian Natural” or the “Company”) announces that it has entered into an agreement to acquire a 100% working interest in the Joslyn oil sands project for a total consideration of $100 million cash on closing and annual cash payments of $25 million over each of the next five years. The Joslyn lease, which is located directly south of the Company’s current Horizon Oil Sands Mining and Upgrading project (“Horizon”), adds significant value to the Company’s already extensive portfolio of high quality long life low decline assets and will allow for more effective lease-line development opportunities between the Horizon and Joslyn projects. The transaction, subject to regulatory approval, is targeted to close on September 28, 2018.

09/01/2015 Total announces the start-up of production from the Surmont 2 oil sands project , located 63 kilometers southeast of Fort McMurray in the Athabasca region of Alberta, Canada. As a result of the technology that will be implemented, production will ramp up through 2016 and 2017, adding 118,000 barrels of oil per day gross capacity. Total gross capacity for Surmont 1 and 2 is expected to reach 150,000 barrels of oil per day. “This is Total’s fifth startup since the beginning of the year, and it contributes to our upstream growth” said Arnaud Breuillac, President Exploration & Production. “Surmont will produce substantial reserves, with a long plateau that will generate cash flow for decades to come.” Surmont uses steam-assisted gravity drainage (SAGD) technology to heat the reservoir, allowing oil to flow and be recovered with top-tier energy efficiency. The Surmont project is a joint venture between ConocoPhillips (50%, operator) and Total (50%).

January 29, 2018 Total announces that the Fort Hills oil sands project located in Alberta, Canada, 90 kilometers north of Fort McMurray, has achieved first oil. Production will ramp up over the next months to reach a plateau of 180,000 barrels per day. The project is operated by Suncor and owned by Suncor (53.06%), Total (26.05%) and Teck (20.89%). “We are pleased to see Fort Hills achieving first oil after a challenging construction program of several years in a difficult climatic environment and we congratulate the operator Suncor for having brought to bear all of its expertise to carry out this project”, stated Arnaud Breuillac, President Exploration & Production at Total. In line with its strategy, which aims at focusing its capital allocation on low breakeven oil projects and managing its investment effort with discipline on the most profitable projects, and in agreement with the other partners of the project, Total reduced gradually since 2015 its interest from 39.2% to 26

January 27, 2023 In the context of its future spin-off, TotalEnergies EP Canada Ltd announces that it has exercised its preemption right to acquire an additional 6.65% interest in the Fort Hills Energy Limited Partnership and associated sales and logistics agreements from Teck Resources Limited, for a consideration of 312 million Canadian Dollars. Fort Hills is located 90 kilometers North of Fort McMurray in the Province of Alberta. Prior to the transaction, TotalEnergies EP Canada held a working interest of 24.58% in the Fort Hills project, and after the transaction it will hold 31.23%. TotalEnergies EP Canada also holds a 50% working interest in the Surmont project located in the region. In line with its low-carbon strategy, TotalEnergies announced in September 2022 its intention to exit Canadian oil sands by spinning off TotalEnergies EP Canada in 2023. Through the acquisition of an additional interest in Fort Hills, TotalEnergies EP Canada is building the future for the spin-off e

August 3, 2021 Today, Irving Oil announces the divestiture of its 25% ownership interest in Canaport LNG , with full ownership to be assumed by the existing majority owner, Repsol SA (BME: REP.) Over the past number of months, the parties have been working together to finalize this transaction and today announce its conclusion. Irving Oil extends its best wishes to Repsol for success in the future. Confidentiality provisions prohibit Irving Oil from commenting further at this time.

July 13, 2022 Delfin Midstream Inc (“Delfin”) has finalized a binding liquified natural gas (“LNG”) sale and purchase agreement (“SPA”) with Vitol Inc. (“VIC”), the Americas-based affiliate of Vitol, which is the world’s largest independent trader of energy. In addition to the SPA, Vitol has finalized a strategic investment in the company.  Under the SPA, Delfin will supply 0.5 million tonnes per annum (“mtpa”) on a free on-board (“FOB”) basis at the Delfin Deepwater Port 40 nautical miles off the coast of Louisiana to VIC for a 15-year period. The SPA is indexed to Henry Hub benchmark. The agreement is valued at approximately $3 billion in revenue over 15 years.  “Recent events have only accelerated the need for a wider array of potential buyers to source reliable low-cost energy from the safety of the U.S. at compelling prices and Delfin is perfectly positioned to serve this growing need. After evaluating multiple projects and running an extensive diligence process, Vitol’s decision

09/16/2022 At the end of August, EUROPIPE GmbH received an order from TC Energy (TCE) to supply the Southeast Gateway Pipeline in the Gulf of Mexico. In partnership with the Mexican state-owned power utility Comisión Federal de Electricidad (CFE), TCE is building a new offshore gas pipeline to secure the power supply in southeastern Mexico. The 715 km deepwater pipeline is a $4.5 billion investment to supply energy to millions of Mexicans. Around half of the very demanding 36" (DN 914 mm) thick-wall pipeline pipes will be supplied by EUROPIPE Mülheim. The order includes the supply of 265,000 tons of pipe (365 km) including anti-corrosion coating. The Southeast Gateway Pipeline, which is scheduled to come on stream in mid-2025, will run from Tuxpan (state of Veracruz) through the Gulf of Mexico to Coatzacoalcos (state of Veracruz) and Dos Bocas (state of Tabasco) and will transport around 37 million cubic meters of natural gas per day. The raw material for the pipe production is p

November 11, 2015 TransCanada Corporation (TSX, NYSE: TRP) (TransCanada) today announced that it has been chosen to build, own and operate the Tuxpan-Tula Pipeline in Mexico. Construction of the pipeline is supported by a 25-year natural gas transportation service contract with the Comisión Federal de Electricidad (CFE), Mexico’s state owned power company.  "The Tuxpan-Tula Pipeline demonstrates our continued commitment to developing Mexico’s energy infrastructure to meet the need for increased natural gas supply,” said Russ Girling, TransCanada’s president and chief executive officer.  TransCanada expects to invest approximately US$500 million in the 36-inch diameter pipeline and anticipates an in-service date in the fourth quarter of 2017. The pipeline will be approximately 250 kilometres (155 miles) long and have contracted capacity of 886 million cubic feet a day (MMcf/d).  The pipeline will originate in Tuxpan in the state of Veracruz and extend through the states of Puebla

July 16, 2018 TransCanada Corporation  today announced its Topolobampo Pipeline project has been placed into service in northern Mexico, providing capacity for 670 million cubic feet of natural gas per day to markets in the states of Chihuahua and Sinaloa. The project represents an investment of approximately US$1.2 billion and provides the upstream interconnection with the company’s Mazatlan Pipeline . The project involved the construction of approximately 560 kilometres (348 miles) of 30-inch diameter pipeline from El Encino, near the city of Chihuahua, to Topolobampo, near the city of Los Mochis, Sinaloa. Combined, the Topolobampo and Mazatlan pipelines form a system that adds over 870 kilometres (540 miles) of critical energy infrastructure that will play a fundamental role in providing natural gas to power plants, industrial and urban markets for the economic development of the northwest region of Mexico. "The completion of the Topolobampo and Mazatlan pipeline system is an

21 September 2022 Allseas has been awarded a substantial construction contract by TC Energy for a major offshore pipeline delivering natural gas to southeast Mexico. Our state-of-the-art pipelay vessels will install the 36-inch pipeline, which will run approximately 700-kilometres south along the coast from Tuxpan connecting the ports of Coatzacoalcos and Dos Bocas. The Southeast Gateway pipeline is the first major natural gas infrastructure project to emerge from a new strategic alliance between TC Energy and Mexico’s state utility CFE. Allseas is pleased to be playing a key role in this strategic project, which will serve the growing need for safe, reliable and affordable energy supply in the southeast region of Mexico. Pipelay is expected to commence end of 2023, with the pipeline in service by the mid-2025. Southeast Gateway is Allseas second pipeline in Mexico. In 2017, we installed the 685 km-long Sur de Texas-Tuxpan pipeline, which moves natural gas supply from basins in Texas

Aug. 4, 2022 News Release – TC Energy Corporation and the CFE, Mexico’s state-owned electric utility, have agreed to forge a strategic alliance to accelerate the development of natural gas infrastructure in the central and southeast regions of Mexico. TC Energy and the CFE have agreed to consolidate previous TSAs executed between TC Energy’s Mexico-based subsidiary TGNH and the CFE in connection with our natural gas pipeline assets in central Mexico under a single, U.S. dollar-denominated take-or-pay contract that extends through 2055. This new TSA will also govern related new infrastructure projects to be developed in conjunction with the CFE. “We are pleased to have been selected by the CFE as its partner and to forge this strategic and important public-private partnership, a first-of-its-kind in the CFE’s 85-year history.” said François Poirier, President and CEO, TC Energy. “This alliance capitalizes on each of our strengths. Together, TC Energy and the CFE will develop critical en

20 October 2022 Sembcorp Marine Ltd (“Sembcorp Marine” or “SCM”), through its wholly-owned subsidiary, Sembcorp Marine Rigs & Floaters Pte Ltd, entered into Master Service Agreements with New Fortress Energy Inc. (NASDAQ: NFE) affiliates for the engineering and conversion of two Sevan cylindrical drilling vessels to Floating LNG (“FLNG”) liquefaction facilities, including the fabrication and integration of LNG topside modules. One of the vessels is to be used in the  Lakach FLNG Export Terminal . The hull conversion and fabrication of topsides for the first FLNG liquefaction facility is scheduled for delivery in the first half of 2024 through the Work Engagement Contract awarded by NFE. Work on the second FLNG liquefaction facility project is expected to be contracted through further Work Engagement Contracts to Sembcorp Marine at a later date. The two FLNG liquefaction units will host the NFE-designed Fast LNG liquefaction production facility with a capacity of approximately 1.4 m

Nov. 22, 2022 New Fortress Energy Inc. (NASDAQ: NFE) (“NFE” or the “Company”) announced today that it has finalized its agreements with Petróleos Mexicanos (“Pemex”), Mexico’s state-owned oil company, to develop and operate an integrated upstream and natural gas liquefaction project off the coast of Veracruz in Southeastern Mexico. The agreements comprise a long-term strategic partnership, expressly supported by His Excellency Andrés Manuel López Obrador, the President of Mexico, to complete the development of the Lakach deepwater natural gas field, one of the largest non-associated gas fields in the Gulf of Mexico. NFE will invest in the continued development of the Lakach field over a two-year period by completing seven offshore wells. In addition, NFE will deploy to the Lakach field its 1.4 MTPA Sevan Driller FLNG unit , which is currently undergoing conversion in a shipyard in Singapore, to liquefy the majority of the produced natural gas. “We are pleased to finalize our strategic

Mar. 10, 2022 MODEC, Inc. (“MODEC”) announced today that the FPSO MIAMTE MV34 (“the FPSO”), operating in the Offshore Area 1 block in the Gulf of Mexico achieved the First Oil production on February 23, 2022. This is MODEC’s first project for Eni Mexico, a subsidiary of the integrated energy company Eni. MODEC was appointed by Eni Mexico for the supply, charter and operations of the FPSO in the Eni-operated Offshore Area 1 block in the Bay of Campeche in 2018. The charter contract will run for an initial 15 years, with options for extension every year thereafter up to five (5) additional years. Moored in a water depth of approximately 32 meters some ten (10) kilometers off Mexico's coast, the FPSO is capable of handling 90,000 barrels of oil per day, 75 million cubic feet of gas per day and 120,000 barrels of water injection per day with a storage capacity of 700,000 barrels of oil. The FPSO boasts a Disconnectable Tower Yoke Mooring System (“DTYMS”), a first-of-its-kind design in

Jul 21 2022 SBM Offshore is pleased to announce it has completed the project financing of FPSO ONE GUYANA for a total of US$1.75 billion. The project financing was secured by a consortium of 15 international banks. The Company expects to draw the loan in full, phased over the construction period of the FPSO. The financing will become non-recourse once the FPSO is completed and the pre-completion guarantee has been released. The project loan is in line with the duration of the charter hence a two-year tenor post-completion and carries a variable interest rate based on SOFR plus 2.2% margin. The FPSO ONE GUYANA builds on the experience to date of FPSOs Liza Destiny, Liza Unity and Prosperity. As such, the design is based on SBM Offshore’s industry leading Fast4Ward® program that incorporates the Company’s new build, multi-purpose hull combined with several standardized topsides modules. The FPSO will be designed to produce approximately 250,000 barrels of oil per day, will have associat

August 2, 2021 Petróleo Brasileiro S.A. – Petrobras informs that it signed today a Letter of Intent with the company SBM Offshore for the chartering and provision of services of the FPSO Alexandre de Gusmão , to be installed in the Mero field , located in the pre-salt of the Santos Basin. The FPSO, which stands for floating production, storage and oil transfer unit, will be the fourth platform in the definitive system for the Mero field and will have the capacity to process 180 thousand barrels of oil and 12 million cubic meters of gas per day. Production is scheduled to start in 2025. The chartering and service contracts will last 22 years and 6 months from the unit's final acceptance.  The project foresees the interconnection of 15 wells to the FPSO, 8 of which are oil producers, 6 water and gas injectors, and 1 convertible well from producer to gas injector, through a subsea infrastructure composed of rigid production and injection pipelines and flexible service pipelines.  The

December 18, 2017 Petróleo Brasileiro SA - Petrobras, the Libra Consortium operator, announces that it signed, on November 14th, a contract with the Modec group to charter a FPSO platform (a Floating Production Storage and Offloading unit), the first definitive production system of Mero Field , which will be used in the Mero Pilot project. The project includes the interconnection of up to 17 wells to the platform and the start of the production is planned for 2021.   The FPSO will have a daily operational capacity rate up to 180,000 barrels of oil (bpd) and 12 million cubic meters per day of gas and will be installed in a water depth of 2,100 meters, in Mero Field, located in the northwestern area of the Libra block, about 180 km off the coast of Rio de Janeiro, in the pre-salt of the Santos basin.  The unit will be operated by Modec, the company responsible for the construction, and chartered for 22 years. Part of the construction will be carried out in Brazil, aligned with Petrobras

May 6, 2022 MODEC, Inc. (“MODEC”) announced today that the FPSO Guanabara MV31 , deployed for operations at the Mero field in the giant “pre-salt” region of the Santos Basin off the coast of Brazil, achieved First Oil production and started charter services on May 1, 2022. It is the largest FPSO built by the company to date. Moored some 180 kilometers off the coast of Rio de Janeiro, at a water depth of approximately 2,100 meters, the FPSO is capable of processing 180,000 barrels of crude oil, 424 million standard cubic feet of gas and 225,000 barrels of water injection per day, and has storage capacity of 1,400,000 barrels of crude oil. The FPSO is leased on a 22-year time charter contract to Petróleo Brasileiro S.A. (“Petrobras”), the Brazilian state oil company. MODEC was responsible for the engineering, procurement, construction and mobilization of the FPSO, including topsides processing equipment as well as hull and marine systems. SOFEC, Inc., a MODEC group company, designed and

September 11, 2019 Recently, Load Out maneuvers of the jacket and deck of the CA-KU-A1 platform for the  Ku-Maloob-Zaap Oil Field were successfully performed in our manufacturing yard in Altamira (Mexico) With approximate weights of 3,500 and 11,500 tons, the jacket and deck of the CA-KU-A1 platform are the main elements of the Integral Gas Compression System that Dragados Offshore Mexico has designed and entirely builds in its new Yard of Altamira. This project is the first to be completed in this Yard and the structures are the first to be loaded onto the dock, constituting a new milestone in the successful career of Dragados Offshore. The CA-KU-A1 Integral Compression System will have capacity to compress, under normal conditions, a flow of 450 MMPCD, for PEMEX, in the KU-A1 process center. Once the loads have been carried out, the Project will continue in its offshore phase with the transport, installation, hook up and commissioning of all the elements of the Integral Compression

September 28, 2020 The Tyra Jackets , delivered to Total E&P Danmark A/S at the sailaway past 2nd of September are now successfully installed in the final location in the Danish sector of the North Sea (approximately 225km west off the coast of Esbjerg, Denmark). Dragados Offshore consolidates once more its position as a leader in the development and execution of offshore projects for the Oil & Gas industry and is proud to be part of TOTAL’s Tyra Future project, having provided a successful and safe supply of the jackets, which form a critical part of the overall development to secure the supply of gas to Denmark.

December 15, 2022 Saipem has been awarded new contracts in Guyana and Egypt for a total amount of approximately 1.2 billion USD. The first contract has been awarded by ExxonMobil Guyana, subject to government approvals, for the UARU oil field development project, located in the Stabroek block offshore Guyana at a water depth of around 2,000 meters. The contract scope includes the design, fabrication and installation of subsea structures, risers, flowlines and umbilicals for a large subsea production facility. Saipem, who was previously awarded other four subsea contracts by ExxonMobil Guyanafor prior developments in the same area, namely Liza Phase 1 and 2, Payara, and Yellowtail, will perform the operations by using its vessels, including FDS2 and Constellation. Subject to the necessary government approvals, project sanction by ExxonMobil Guyana and its Stabroek block coventurers and an authorization to proceed with the final phase, the award will allow Saipem to start some limited

Jan. 27, 2020 ExxonMobil has increased its estimated recoverable resource base in Guyana to more than 8 billion oil-equivalent barrels and made a further oil discovery northeast of the producing Liza field at the Uaru exploration well , the 16th discovery on the Stabroek Block. The new recoverable resource estimate includes 15 discoveries offshore Guyana through year-end 2019. The Uaru discovery is the first of 2020 and will be added to the resource estimate at a later date. “With recent high-quality finds at Tripletail and Mako contributing to our recoverable resources, our investments will continue to provide benefits for the people of Guyana,” said Mike Cousins, senior vice president of exploration and new ventures at ExxonMobil. “The Uaru discovery is another positive step as we begin a new decade with the Co-operative Republic of Guyana and our co-venturers.” Uaru encountered approximately 94 feet (29 meters) of high-quality oil-bearing sandstone reservoir. The well, drilled in 6

Nov. 1, 2022 MODEC, Inc. ("MODEC") is pleased to announce that it has signed a contract to perform Front End Engineering and Design (FEED) for a Floating Production, Storage and Offloading vessel (FPSO) for the “Uaru” development project . The FEED contract award relates to the initial funding by ExxonMobil’s subsidiary, Esso Exploration and Production Guyana Limited (EEPGL), to begin FEED activities related to the FPSO design and to secure the second M350TM hull for FPSO service. Following FEED and subject to government approvals in Guyana of the development plan, project sanction including final investment decision by ExxonMobil, and EEPGL’s release of the second phase (EPCI) of work, MODEC is expected to construct the FPSO and install in Guyana. MODEC is also anticipated to operate the FPSO for an initial duration of 10 years, with potential options for continuation. MODEC will design and construct the FPSO based on its M350 new-build design. Uaru will be the second M350

March 31, 2022 Shell Trinidad and Tobago (through BG International, a subsidiary of Shell plc), today announces that production has started on Block 22 and NCMA-4 in the North Coast Marine Area (NCMA) in Trinidad and Tobago. The start-up of Colibri follows the amendment to the Block 6 Production Sharing Contract for the Manatee field, marking yet another significant milestone in Shell's growth strategy in country. This will allow for the delivery of gas both domestically and internationally through Atlantic LNG. "I am proud of the team in Trinidad and Tobago for their commitment to safely delivering this project on time." said Wael Sawan, Director of Integrated Gas, Renewable and Energy Solutions. "This reinforces the delivery of Shell's Powering Progress strategy in country, as we seek to provide more and cleaner energy solutions, globally. Colibri, along with other development projects, will see natural gas going into both the domestic petrochemical markets and

28 February 2023 Yinson Production (“YP”) is pleased to announce that it has, through wholly owned subsidiaries, entered into a firm contract with Eni Angola S.p.A., a wholly owned subsidiary of Azule Energy (“Azule”), for the provision, operation and maintenance of a floating, production, storage and offloading asset for the Agogo Integrated West Hub Development Project in Angola (“FPSO Agogo”).  Azule is Angola’s largest independent oil and gas producer, and a 50/50 joint venture between BP p.l.c. (“BP”) and Eni S.p.A. (“Eni”).  The contract has an estimated aggregate value of approximately USD5.3 billion and a firm period of fifteen (15) years from the date of the final acceptance, with the option to extend for a further five (5) years. FPSO Agogo is expected to commence operations in the fourth quarter of 2025. The signing of the firm contract follows on from the signing of an agreement for preliminary activities on 2 December 2022 between the parties.   FPSO Agogo will be YP

13 March 2019 Eni announces a major oil discovery in Block 15/06, in the Agogo exploration prospect , in Angola’s deep water. The new discovery is estimated to contain between 450 and 650 million barrels of light oil in place with further upside. The Agogo-1 NFW well, which has led to the discovery, is located approximately 180 kilometers off the coast and about 20 kilometers west from the N’Goma FPSO (West Hub). The well was drilled by the Poseidon drillship in a water depth of 1636 meters and reached a total depth of 4450 meters. Agogo-1 NFW proved a single oil column of about 203 meters with 120 meters of net pay of high quality oil (31° API) contained in a sub salt diapirs setting in Lower Miocene sandstones with excellent petrophysical properties. The data acquired in Agogo-1 NFW indicate a production capacity of more than 20,000 barrels of oil per day. Agogo is the third discovery of commercial nature since the Block 15/06 Consortium decided to launch a new exploration campaign i

1 September 2021  Eni announces a major oil discovery in block CI-101 offshore Ivory Coast. The block is operated by Eni with Petroci Holding, who hold 90% and 10% respectively in the exploration phase. The discovery well has been drilled on the Baleine prospect , with the support of the Government in the difficult context of the pandemic-covid-19. Baleine-1x discovered light oil (40° API) in two different stratigraphic levels. An evaluation program will be carried out to assess the significant upside potential of the overall structure that extends into block CI-802, also operated by Eni with the same Joint-Venture and participating interests in the exploration phase. The well was drilled about 60 kilometers off the coast, in about 1,200 meters of water depth with the Saipem 10,000 drill ship and reached a total depth of 3,445 meters in 30 days. The Baleine-1x well was located on the basis of a comprehensive analysis of a wide range of 3D seismic data and regional studies in the sedim

September 27, 2022  Saipem has been awarded two new contracts in Ivory Coast worth approximately 1 billion euro overall. The contracts have been assigned by the ENI Cote d’Ivoire-Petroci consortium for the Baleine Phase 1 Project , for the development of the relative oil and gas field offshore Ivory Coast located at a 1,200m water depth. The Baleine Prospect represents the largest commercial discovery in the country in the last 20 years and it will contribute to energy production in Ivory Coast, strengthening the country’s role as a regional energy hub. Saipem contributed to the discovery of the field thanks to the drilling activities of the Saipem 10000 and Saipem 12000 vessels. The first contract entails Engineering, Procurement, Construction and Installation (EPCI) activities of Subsea Umbilicals, Risers and Flowlines (SURF) and of an onshore gas pipeline for the connection to the distribution grid. The offshore laying of flexible lines, risers and umbilicals will be executed by Sai

January 14, 2022 Pertamina's dedication in executing the transformation of the refinery and petrochemical business in Balongan continues through the implementation of two strategic projects: the RDMP (Refinery Development Master Plan) and the revitalization of the RCC in Balongan. "RCC" or Residue Catalytic Cracking at Pertamina's refinery unit in Balongan is an important facility in the petroleum processing process because it functions to increase product value with the help of a catalyst. To accelerate the revitalization or rejuvenation of the RCC unit, on January 11, 2022, Pertamina through the Balongan Project Team succeeded in bringing in "Reactor", a core equipment for the RCC unit. As stated by the Corporate Secretary of PT Kilang Pertamina Internasional (PT KPI), Ifki Sukarya, the installation of the reactor unit shows Pertamina's positive performance, which is already on track in overseeing the RCC rejuvenation project. In fact, until early 202

June 10, 2016 Statoil, along with its partners, has finalized a 19-month exploration drilling program offshore Newfoundland. The purpose of the drilling program was to increase the robustness of the Bay du Nord project and to test new areas of the Flemish Pass Basin. Nine wells were drilled safely and efficiently by the Seadrill West Hercules in the Flemish Pass Basin, located approximately 500 kilometres east of St. John’s, Newfoundland and Labrador. The results have improved Statoil’s understanding of the frontier Flemish Pass Basin. The drilling program included four exploration wells in close vicinity of the 2013 Bay du Nord discovery, as well as three appraisal wells on the discovery. In addition, two exploration wells were drilled in areas outside the Bay du Nord discovery. The program was conducted in a harsh offshore environment; however, with strong operational and HSE performance, setting several records on drilling speed during the campaign. The drilling program has resulte