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Shell Discovers More Oil Off Namibia Shell announced its oil discovery off Namibia in January and was “very encouraged by the early results” from the Graff-1 exploration well in the country’s Orange Basin, which “established a working petroleum system and the presence of light oil.” Researchers at Wood Mackenzie believe the find could hold upward of 700 million BOE. Shell is currently drilling a second well at La Rona, an aggressive stepout which is likely to be appraising the discovery prior to confirmation of a potential commercial development. Shell operates the Graff find with a 45% interest. Partners in the discovery are QatarEnergy (45%) and NAMCOR (10%). Less than a month after Graff was announced, TotalEnergies reported that it had made a significant discovery of light oil with associated gas on the Venus prospect, in Block 2913B in the Orange Basin. The Venus 1-X well encountered around 84 m of net oil pay in a Lower Cretaceous reservoir. No resource estimates have been officially released. First Oil Achieved at King’s Quay in the GOM Murphy Oil has achieved first oil from the Khaleesi, Mormont, and Samurai field development project in the deepwater Gulf of Mexico (GOM). The field trio is being developed subsea and tied back to the Murphy-operated King’s Quay floating production system (FPS), designed to process 85,000 B/D of oil and 100 MMcf/D of natural gas. The project comprises the Khaleesi/Mormont fields in Green Canyon Blocks 389 and 478, respectively, and the Samurai field, located in Green Canyon Block 432. Completions operations are ongoing for the remaining five wells in the seven-well project. Murphy operates the King’s Quay FPS and associated export lateral pipelines, which are owned 50% by an affiliate of Third Coast Infrastructure and 50% by entities managed by Ridgewood Energy, including ILX Holdings III LLC. Neptune Energy Ramps Up Gas Production From Duva Field Neptune Energy and its partners will be doubling gas production from the Duva field in the Norwegian sector of the North Sea, supporting increased supplies to the UK and Europe. The partnership has worked closely with the Norwegian authorities to identify measures to help meet gas demand in Europe. Gas production from the field was planned to increase by 6,500 BOE/D from the first half of April. Duva is a subsea installation with three oil producers and one gas producer, tied back to the Neptune Energy-operated Gjøa semisubmersible platform. The gas is transported by pipeline to the UK’s St Fergus gas terminal. Duva’s overall production currently stands at 30,000 BOE/D, of which 6,500 BOE/D is natural gas. Under the newly agreed measures, daily gas production will double to 13,000 BOE/D for an initial 4–8 months. Around 70% of Neptune Energy’s Norwegian production is gas, and the company is investigating opportunities to ramp up gas production from other fields within its portfolio. Duva license partners include operator Neptune Energy (30%), INPEX Idemitsu (30%), PGNiG Upstream Norway (30%), and Sval Energi (10%). New Oil Discovery Near Troll and Fram Area of the North Sea Equinor has once again discovered oil and gas close to the Troll and Fram area—this time with its Kveikje well. The find came on the operator’s 293 B production license. The company estimates the size of the discovery is between 25–50 million bbl of recoverable oil equivalent. Temporarily called Kveikje, this is the sixth discovery in this area since 2019. Up to more than 300 million BOE were proven in the five former discoveries. Equinor is considering the development as a tieback to the Troll B or C platform. There were several drilling targets in the exploration well. After Kveikje was discovered, drilling continued to the next target in the upper part of the Cretaceous stratigraphic sequence. Smaller deposits of petroleum were discovered but are considered noncommercial. The well has been permanently plugged and abandoned. The well was drilled by semisubmersible Deepsea Stavanger. Plans call for Equinor to drill another exploration well in this area this year. The 293 B license owners are Equinor (51%), DNO (29%), Idemitsu (10%), and Longboat Energy (10%). W&T Offshore Completes Bolt-On Acquisition in the GOM W&T Offshore has acquired the remaining working interests in the oil- and gas-producing properties at Ship Shoal 230, South Marsh Island 27/Vermilion 191, and South Marsh Island 73 fields for $17.5 million in cash. The initial interest was purchased earlier this year from an undisclosed private seller. The transaction had an effective date and closing date of 1 April and was paid using cash on hand. The deal adds internally estimated proved reserves of 1.4 million BOE (70% oil) and proved and probable, or 2P, reserves of 2 million BOE (75% oil) as of year-end 2021. The properties carry an estimated net sales rate of about 900 BOE/D (~80% oil). The acquisition also adds an average of 20% working interest in more than 50 gross producing wells currently operated by the company across three shallow-water fields and provides additional opportunities for future drilling. ExxonMobil Comes Up Empty on Cutthroat Prospect in Brazil Prospect partner Murphy Oil said it and operator ExxonMobil came away with disappointing results from their Cutthroat-1 exploration well in Block SEAL-M-428 in the Sergipe-Alagoas Basin offshore Brazil. While the presence of hydrocarbons was not found, the partner group said it will continue to integrate the exploration well data into its regional subsurface interpretation efforts to better understand the exploration potential of its deepwater blocks located in the basin. Cutthroat-1 was located nearly 90 km offshore Brazil and was drilled in 3094 m of water by the Seadrill West Saturn drillship. It is one of multiple prospects that the partner group has mapped in the basin. ExxonMobil is the operator and holds 50% working interest in nine offshore SEAL blocks that span more than 6800 km. Enauta Energia and Murphy Oil each hold a 30% working interest. Eni Upgrades Ndungu Field Resources Off Angola Eni has boosted its reserves base for the Ndungu field in the West Hub of Block 15/06 following the results of an initial well. The Ndungu 2 appraisal well was drilled 5 km away from Ndungu 1 and encountered 40 m of net oil pay in the Lower Oligocene reservoirs with good petrophysical properties confirming the hydraulic communication with the discovery well. The preliminary data collected on Ndungu 2 allows Eni to boost the field resources to between 800 million and 1 billion BOE in place from the initial estimates of 250–300 million BOE following the discovery well. The upgrade makes Ndungu, together with Agogo, the largest accumulation discovered in Block 15/06 since the block award. The early production phase of Ndungu started in February through one producer well, and a second producer well is expected in the fourth quarter of 2022, maximizing the utilization of existing facilities in the West Hub. Ndungu field development will now be upgraded to reflect the increase of the resource base, following a phased approach to uncap the overall potential initially contributing to extend and increase the plateau of the Ngoma—a 100,000 B/D, zero-discharge and zero-process-flaring FPSO. Block 15/06 is operated by Eni Angola with a 36.84% share. Sonangol Pesquisa e Produção holds 36.84% and SSI Fifteen Ltd., 26.32%. ExxonMobil Strikes Gas Off Cyprus The Cyprus energy ministry confirmed a reservoir of high-quality gas was encountered by the ExxonMobil-led Glaucus-2 appraisal well. The drilling of the well was conducted in the area known as Block 10 in the Exclusive Economic Zone (EEZ) that has been challenged by Turkey. The ministry said that operations in the EEZ included production testing. “The consortium will proceed with a detailed analysis and evaluation of the data collected to more accurately determine the qualitative and quantitative characteristics of the reservoir, as well as potential development and commercialization of the discoveries,” the ministry said in a statement. Cyprus previously estimated gas resources in the reservoir of between 5 and 8 Tcf when the discovery from the Glaucus-1 well was announced in 2019. ExxonMobil and Block 10 partner Qatar Petroleum began drilling the Glaucus-2 well using drillship Stena Forth in December 2021. ExxonMobil is the operator and holds a 60% interest in Block 10. Qatar Petroleum International Upstream OPC holds the remaining 40% stake. Eni, Sonatrach Make Oil Hit in Algerian Desert Eni and Sonatrach made a significant oil and gas discovery in the Zemlet el Arbi concession located in the Berkine North Basin in the Algerian desert. The concession is operated by a joint venture between Eni (49%) and Sonatrach (51%). Preliminary estimates of the size of the discovery are around 140 million bbl of oil in place. The exploratory well that led to the discovery has been drilled on the HDLE exploration prospect, about 15 km from the processing facilities of Bir Rebaa North field. HDLE-1 discovered light oil in the Triassic sandstones of the Tagi formation confirming 26 m of net pay. During a production test, the well delivered 7,000 BOPD and 5 MMcf/D of associated gas. The HDLE-1 well is the first well of the new exploration campaign which will include the drilling of five wells in the Berkine North Basin. The discovery will be appraised by the followup HDLE-2 well to confirm the additional potential of the structure extending in the adjacent Sif Fatima 2 concession operated by an Eni-Sonatrach JV (50–50%). In parallel with the appraisal program, Eni and Sonatrach will perform studies and analyses to accelerate the production phase of the new discovery through a fast-tracked development with startup planned for the third quarter of 2022. Eni has been present in Algeria since 1981 where it operates several concessions. The company produces about 95,000 BOE/D from the country. Neptune Energy Confirms Hydrocarbons at Hamlet Neptune Energy struck hydrocarbons at its Hamlet exploration well in the Norwegian sector of the North Sea. The find is located within the Gjøa license (PL153). It has yet to be confirmed if commercial volumes of oil and gas are present. A contingent sidetrack may be drilled to further define the extent of the discovery. Located 58 km west of Florø, Norway, at a water depth of 358 m, Hamlet is within one of Neptune’s core areas and close to existing infrastructure. The Hamlet test was drilled by the Odjfell semisubmersible Deepsea Yantai. Partners in the find include operator Neptune Energy (30%), Petoro (30%), Wintershall Dea (28%), and OKEA (12%).
- North America > United States > Gulf of Mexico > Central GOM (1.00)
- Europe > Norway > North Sea (1.00)
- Asia > Middle East > Qatar (1.00)
- Africa > Middle East > Algeria (1.00)
- Phanerozoic > Mesozoic > Cretaceous (0.75)
- Phanerozoic > Cenozoic > Paleogene > Oligocene (0.55)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Green Canyon > Block 432 > Samuri Field (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 636 > Block 36/7 > Duva Field > Åsgard Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 636 > Block 36/7 > Duva Field > Agat Formation (0.99)
- (33 more...)
The Israeli government awarded 12 offshore licenses to six companies to explore for natural gas off the country's Mediterranean coast after large gas deposits have been discovered in the East Mediterranean over the past decade and a half. Six of the licenses were awarded to Eni, Dana Petroleum, and Israel's Ratio Energies to explore an area west of the Leviathan field. The remaining six were granted to BP, Azerbaijan's national oil company SOCAR, and Israel's NewMed Energy to explore north of the Leviathan. The licenses will last for an initial 3 years, with the option to extend to up to 7 years, depending on progress. The North Sea Transition Authority (NSTA), Britain's oil and gas regulator, awarded 27 new hydrocarbon exploration licenses, the first of its kind since 2019.
- Asia > Middle East > Israel (1.00)
- Europe > United Kingdom > North Sea > Central North Sea (0.48)
- Government > Regional Government > Asia Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- South America > Suriname > North Atlantic Ocean > Guyana-Suriname Basin (0.99)
- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > P1622 > Block 22/29C > Seagull Field (0.99)
- (19 more...)
Eni Starts Area 1 Production off Mexico via MODEC FPSO MODEC said first oil has flowed through FPSO MIAMTE MV34 operating in the Offshore Area 1 block in the Bay of Campeche off Mexico. The contractor was appointed by Eni Mexico for the supply, charter, and operation of the FPSO in the Eni-operated Offshore Area 1 block in 2018. The charter contract will run for an initial 15 years, with options for extension every year thereafter up to 5 additional years. Moored in a water depth of approximately 32 m some 10 km off Mexico’s coast, the FPSO is capable of handling 90,000 B/D of oil, 75 MMcf/D of gas, and 120,000 B/D of water injection with a storage capacity of 700,000 bbl of oil. The FPSO boasts a disconnectable tower yoke mooring system, a first-of-its-kind design in the industry. The system was developed to moor the FPSO in shallow water, while also allowing the unit to disconnect its mooring and depart the area to avoid winter storms and hurricanes in the Gulf of Mexico. The mooring system was developed by MODEC subsidiary SOFEC Inc. The mooring jacket was fabricated in Altamira, Mexico. Eni Starts Production from Ndungu EP Development Italy’s Eni has started production from the Ndungu Early Production (EP) development in Block 15/06 of the Angolan deep offshore, via the Ngoma FPSO. With an expected production rate in the range of 20,000 B/D, the project will sustain the plateau of the Ngoma, a 100,000-B/D, zero-discharge, and zero-process-flaring FPSO, upgraded in 2021 to minimize emissions. A further exploration and delineation campaign will be performed in Q2 2022 to assess the full potential of the overall assets of Ndungu. Ndungu EP is the third startup achieved by Eni Angola in Block 15/06 in the past 7 months, after Cuica Early Production and the Cabaca North Development Project. Block 15/06 is operated by Eni Angola with a 36.84% share. Sonangol Pesquisa e Produção (36.84%) and SSI Fifteen Ltd. (26.32%) comprise the rest of the joint venture. Aramco Discovers Natural Gas in Four Regions Saudi Aramco has discovered natural gas fields in four regions of the kingdom, the Saudi Press Agency (SPA) reported, citing Energy Minister Prince Abdulaziz bin Salman. The fields were found in the Empty Quarter desert located in the central area of the kingdom, near its northern border and in the eastern region, he said, according to SPA. Saudi Arabia wants to increase gas production and boost the share of natural gas in its energy mix to meet growing electricity consumption and to make more crude available for export. The minister said an unspecified number of fields were discovered and he mentioned five by name: Shadoon, in the central region; Shehab and Shurfa, in the Empty Quarter in the southeastern region; Umm Khansar, near the northern border with Iraq; and Samna in the eastern region. Two of the gas fields, Samna and Umm Khansar, were said to be “nonconventional” and possibly shale finds. Lukoil Completes Area 4 Deal in Mexico Russian producer Lukoil has completed a deal to become a lead stakeholder in an Area 4 shallow-water asset adjacent to Tabasco and Campeche in Mexico. Under the deal, Lukoil has acquired a 50% stake in the asset from US independent Fieldwood Energy, which filed for US bankruptcy protection in August 2020, for $685 million. The original deal was priced at $435 million; the additional $250 million is related to expenditures Fieldwood incurred since 1 January 2021. Fieldwood committed to invest $477 million to increase oil production from the Ichalkil and Pokoch fields from the current level of 25,000 B/D to a plateau level of 115,000 B/D. Situated in water depths between 35 and 45 m, the fields’ recoverable hydrocarbon reserves amount to 564 million BOE, more than 80% of which is crude oil. Production started in Q4 2021; current average oil production has exceeded 25,000 B/D. The approved work program includes drilling three development wells (two on Ichalkil and one on Pokoch), upgrading three production platforms, and performing seismic reprocessing and petrophysical studies. The remaining 50% stake in Area 4 is held by operator PetroBal, a subsidiary of Mexico’s GrupoBal. Petrobras Sells Polo Norte Capixaba Field Cluster In line with its strategy to concentrate resources on deepwater and ultradeepwater assets, Brazil’s Petrobras has sold 100% of its interest in Norte Capixaba cluster to Seacrest Exploração e Produção de Petróleo Ltda for $544 million, including a $66-million contingent payment. The cluster comprises four producing fields—Cancã, Fazenda Alegre, Fazenda São Rafael, and Fazenda Santa Luzia—and produced 6,470 BOE/D in 2021. The deal also includes the Norte Capixaba Terminal (TNC) and all production facilities. NewMed Targets Morocco Market Entry Israel-based NewMed Energy, formerly Delek Drilling, has identified Morocco as “a country with enormous geological and commercial potential,” in particular the Moroccan coastal areas in the Mediterranean and North Atlantic. The announcement comes a day after the Moroccan Minister of Industry and Trade, Ryad Mezzour, and his Israeli counterpart, Orna Barbivai, signed an MOU aimed at promoting investments and exchanges between the two countries in the digital design, food, automotive, aviation, textile, water technologies and renewable energies, medical equipment, and the pharmaceutical industries. In September 2021, the Israeli oil and gas exploration company obtained from the Moroccan ministry the exploration and study rights of the Dakhla Atlantic Block, which has an area of about 109000 km. ExxonMobil Sells Nigerian Assets to Seplat ExxonMobil has agreed to sell its shallow-water assets in Nigeria to Seplat Energy for $1.28 billion plus a contingent consideration of $300 million. Seplat said it is acquiring a 40% operating stake in four oil leases to nearly triple its annual net production to 146,000 BOE/D. The deal also includes the Qua Iboe export terminal and a 51% interest in the Bonny River Terminal and natural gas liquids recovery plants at EAP and Oso. It does not include any of ExxonMobil’s deepwater fields in Nigeria. TotalEnergies Discovers Large Oil Field off Namibia TotalEnergies has made a significant discovery of light oil with associated gas on the Venus prospect, located in block 2913B in the Orange Basin, offshore southern Namibia. The Venus 1-X well encountered approximately 84 m of net oil pay in a good-quality Lower Cretaceous reservoir. The find’s potential reserves are estimated at 2 billion bbl of oil. “This discovery offshore Namibia and the very promising initial results prove the potential of this play in the Orange Basin, on which TotalEnergies owns an important position both in Namibia and South Africa,” said Kevin McLachlan, senior vice president exploration at TotalEnergies. “A comprehensive coring and logging program has been completed. This will enable the preparation of appraisal operations designed to assess the commerciality of this discovery.” Block 2913B covers approximately 8215 km in deep offshore Namibia. TotalEnergies is the operator with a 40% working interest, alongside QatarEnergy (30%), Impact Oil and Gas (20%), and NAMCOR (10%). CNPC Scoops Ishpingo Drilling Contract The first drilling contract at the Ishpingo oil field near Ecuador’s Yasuni National Park has been awarded to China National Petroleum Corp. (CNPC), Energy Minister Juan Carlos Bermeo told Reuters. Following the approval of a new hydrocarbon law and legislation, Ecuador plans to move forward with auctions and competitive processes for securing foreign and domestic capital for oil and gas exploration, production, transportation, and refining projects. The first drilling campaign to start after an environmental license was granted for the sensitive area will involve 40 wells over the next 18 months. It will focus on the field’s allowed zone without touching an area protected by a court ruling that has prevented extending drilling. Ishpingo is the latest part of the ITT-43 oil field in Ecuador’s Amazonia region to start drilling after Tambococha and Tiputini. It is expected to produce heavy oil to be added to the nation’s output of flagship Napo crude, Bermeo said. BP Brings Hershel Expansion Project On Line in US GOM BP has successfully started production from the Herschel Expansion project in the Gulf of Mexico—the first of four major projects scheduled to be delivered globally in 2022. Phase 1 comprises development of a new subsea production system and the first of up to three wells tied to the Na Kika platform in the Mississippi Canyon area. At its peak, this first well is expected to increase platform annual gross production by an estimated 10,600 BOE/D. The BP-operated well was drilled to a depth of approximately 19,000 ft and is located southeast of the Na Kika platform, approximately 140 miles off the coast of New Orleans. The project provides infrastructure for future well tie-in opportunities. BP and Shell each hold a 50% working interest in the development. Petrobras Kicks off Gulf of Mexico Asset Sales Petrobras has begun an asset sale program in the Gulf of Mexico, in line with the company’s strategy of debt reduction and pivot toward Brazilian deepwater production. The package for sale includes the company’s 20% stake in MP Gulf of Mexico (MPGoM) which holds ownership stakes in 15 fields in partnership with Murphy Oil. In addition to partnership-operated fields, MPGoM owns nonoperated interests in Occidental’s Lucius, Kosmos’ Kodiak, Shell’s Habanero, and Chevron’s St. Malo fields. During the first half of 2021, Petrobras’ share of production was 11,300 BOE/D. ExxonMobil Liza Phase 2 Underway off Guyana ExxonMobil started production of Liza Phase 2, Guyana’s second offshore oil development on the Stabroek Block; total production capacity is now more than 340,000 B/D in the 7 years since the country’s first discovery. Production at the Liza Unity FPSO is expected to reach its target of 220,000 bbl of oil later this year. The Stabroek Block’s recoverable resource base is estimated at more than 10 billion BOE. The current resource has the potential to support up to 10 projects. ExxonMobil anticipates that four FPSOs with a capacity of more than 800,000 B/D will be in operation on the block by year-end 2025. Payara, the third project in the block, is expected to produce approximately 220,000 BOPD using the Prosperity FPSO vessel, currently under construction. The field development plan and application for environmental authorization for the Yellowtail project, the fourth project in the block, have been submitted for government and regulatory approvals. The Liza Unity arrived in Guyana in October 2021. It is moored in water depth of about 1650 m and will store around 2 million bbl of crude. ExxonMobil affiliate Esso Exploration and Production Guyana Ltd. is the operator and holds 45% interest. Hess Guyana Exploration Ltd. holds 30% interest and CNOOC Petroleum Guyana Ltd. holds 25%. Dragon Finds Oil in Gulf of Suez UAE’s Dragon Oil has discovered oil in the Gulf of Suez, according to a statement from the Egyptian Minister of Petroleum and Mineral Resources. The field contains potential reserves of around 100 million bbl inside the northeastern region of Ramadan. That estimate makes it one of the largest oil finds in the region over the past 2 decades. Development plans were not reported but reserve numbers could expand, the ministry said. The oil field is the first discovery by Dragon Oil since it acquired 100% of BP’s Gulf of Suez Petroleum assets in 2019. Dragon Oil, wholly owned by Emirates National Oil Co., holds 100% interest in East Zeit Bay off the southern Gulf of Suez region. The 93-km block lies in shallow waters of 10 to 40 m.
- South America (1.00)
- North America > Mexico (1.00)
- Asia > Middle East > Saudi Arabia (1.00)
- (4 more...)
- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin > Stabroek Block (0.99)
- South America > Ecuador > Orellana > Oriente Basin > ITT (Ishpingo-Tambococha-Tiputini) Block > ITT Field > Ishpingo Field (0.99)
- South America > Ecuador > Orellana > Oriente Basin > Block 43 > ITT Field > Ishpingo Field (0.99)
- (7 more...)
Tullow Swings and Misses off Guyana Tullow Oil has come away empty with its Beebei-Potaro exploration well, drilled in the Kanuku license, offshore Guyana. According to the company, the well encountered good quality reservoir in the primary and secondary targets but both targets were water-bearing. Noble jackup Regina Allen drilled the well to a total depth of 4325 m in 71 m of water. The well has been plugged and abandoned. Tullow will integrate the well results into its regional subsurface models and work with its joint venture partners before deciding on next steps. Repsol is the operator of the Kanuku license with a 37.5% working interest. Tullow holds 37.5% with TOQAP—a joint venture between TotalEnergies and Qatar Petroleum—holding 25%. Tullow previously said it would limit capital exposure in Guyana. The company holds a 60% interest in the Orinduik block, its other licensed area in Guyana, with partners including TotalEnergies and Eco Atlantic Oil & Gas. Oxy Brings Horn Mountain West Online in GOM Occidental has successfully turned the taps on its Horn Mountain West subsea field in the Mississippi Canyon area of the Gulf of Mexico (GOM). The field is in about 5,400 ft of water. The $250-million project comprises a pair of wells tied back to the existing Horn Mountain spar in Block 126 via a 3½-mile dual flowline. According to Oxy, the project came in on budget and 3 months ahead of schedule. It is expected to eventually add approximately 30,000 BOPD. Horn Mountain initially came on stream in late 2002. Hess Strikes Miocene-Aged Oil at Huron in GOM Hess made an oil discovery with a well at its Huron prospect in the Green Canyon area of the deepwater GOM. The well, drilled in Block 69 to a target depth of 28,900 ft by Transocean drillship Deepwater Asgard, struck high-quality, oil-bearing Miocene-aged reservoirs and established the existence of a working petroleum system. An up-dip sidetrack to the initial probe is planned. Gregory Hill, Hess’ chief operating officer, told investors in July that … “as a result of what we’re seeing at Huron we see additional prospectivity in that northern Green Canyon area, and we have a very competitive leasehold position there.” The company had stated previously that its position in the northern Green Canyon area has a high potential for multiple, high-return hub-class Miocene opportunities. Hess operates Huron with a 40% interest. Partners Chevron and Shell each hold 30% stakes. Hess struck a deal with both Chevron and Shell to farm into the prospect in February 2022. The Huron well marks Hess’ return to exploration drilling in the deepwater GOM for the first time in around 2 years. Wintershall Dea Turns the Taps at Nova Wintershall Dea started production from the Nova oil field in the Norwegian North Sea. The field comprises two subsea templates, one with three oil producers and one with three water injectors, tied back to the Gjøa platform. The expected recoverable gross reserves from the field are estimated at 90 million BOE, of which the majority will be oil. The operator said the completion of Nova emphasizes its strength as one of the largest subsea operators on the Norwegian Continental Shelf. “With the startup of the major project Nova, Wintershall Dea is now operating three subsea production fields in Norway,” said Hugo Dijkgraaf, member of the executive board and chief technology officer. The Dvalin field and the partner-operated Njord Future project, in which Wintershall Dea holds a 50% share, are planned to come on stream later this year. The company also operates recent discoveries like Dvalin North, planned for PDO hand-in (Plan for Development and Operations) by the end of 2022, and several other discoveries which could be developed in the future. Wintershall Dea is a partner in the Aker BP-operated Storjo discovery in the Norwegian Sea. Wintershall Dea operates the Nova field with a 45% stake, of which it plans to transfer 6% to OKEA in Q4 this year; Sval Energi holds 45%, Pandion Energy Norge, 10%. Eni Touts Potential 3.5-Tcf Gas Find With First Offshore Abu Dhabi Well Eni believes it has discovered an additional 1.0 to 1.5 Tcf of raw gas in place, in a deeper zone, in its first exploration well drilled in Offshore Block 2 Abu Dhabi. The discovery follows an initial finding in a shallower zone of the same well, aggregating to a total gas in place of up to 3.5 Tcf. The Italian operator said gas-bearing reservoirs were tested with excellent flow rates and fast-track development options are currently under evaluation. Eni, operator, holds a 70% stake in Block 2; PTTEP holds the remaining 30%. Eni has been present in Abu Dhabi since 2018. It operates three exploration concessions and participates with ADNOC in three offshore development and production concessions: Lower Zakum (5%), Umm Shaif and Nasr (10%), and Ghasha (25%). Petrobras Makes Gas Discovery in Colombia Petrobras confirmed the discovery of natural gas accumulation in the Uchuva-1 exploratory well drilled in the deep waters 32 km off the coast of Colombia. The discovery is about 76 km from the city of Santa Marta in a water depth of approximately 830 m. The well was drilled in the Tayrona block, with operator Petrobras (44.44%) in partnership with Ecopetrol, who holds the remaining stake. The consortium will continue its activities in the block to assess the dimensions of the new gas accumulation. CNOOC Successfully Tests Offshore Shale Well China’s CNOOC Ltd. tested commercial flows of oil and gas from an offshore shale exploration well in the South China Sea, marking the first successfully drilled shale oil well offshore China, state media reported in early August. Exploration well Weiye-1, drilled at the southwestern trough of Beibuwan basin, tested daily production of 126 bbl of oil and 1589 m3 of natural gas. CNOOC estimated that the shale oil resources in the entire basin are about 8.8 billion bbl, suggesting good exploration prospects. With the Chinese government stressing added volumes for its domestic energy supply security, national oil companies are making greater efforts to tap shale deposits despite being tougher to drill and more expensive. As of late 2021, China produced only 35,000 B/D of shale oil, mostly in the onshore northern Ordos basin and northwestern Jungar basin. Eni Strikes Oil With Baleine East Well in Côte d’Ivoire Eni has encountered oil with its Baleine East 1X well, the first exploration well in block CI-802 and second discovery on the Baleine structure offshore Côte d’Ivoire. The results have prompted a 25% increase in the oil and gas volumes in place, which are now estimated at 2.5 billion bbl of oil and 3.3 Tcf of associated gas. The well was drilled in the block operated by Eni (90%), together with its partner Petroci Holding (10%), using the drillship Saipem 12000. The final depth reached was 3165 m measured depth, in a water depth of about 1150 m. Baleine East 1X is located about 5 km east of the Baleine 1X discovery well in the adjacent block CI-101 and represents the first commercial discovery in the CI-802 block, confirming the extension of the Baleine field. The well confirmed the presence of a continuous oil column of about 48 m in reservoir rocks with good properties. From the vertical borehole, a horizontal drain of 850 m in length was subsequently drilled into the reservoir to perform a production test that confirmed potential production of at least 12,000 BOPD from the Baleine East 1X well. A third well will be drilled to ensure the accelerated startup of production and confirmation of first oil in the first half of 2023. In addition to blocks CI-101 and CI-802, Eni owns interests in five other blocks in the Ivorian deep water: CI-205, CI-501, CI-504, CI-401, and CI-801, all with the same partner, Petroci Holding. Neptune Energy Kicks Off Ofelia Exploration Well Neptune Energy began drilling operations on the Ofelia exploration well in the Norwegian sector of the North Sea. The well, 35/6-3 S, is being drilled by the Odfjell Drilling-operated semisubmersible Deepsea Yantai. The prospect is located 13 km north of the Gjøa field within the Neptune-operated PL929 License. If commercial, Ofelia could be tied back to the Neptune-operated Gjøa platform and produce at less than half the average carbon intensity of Norwegian Continental Shelf fields, according to the company. Neptune said it could potentially be developed in parallel with Hamlet (PL153). Ofelia is positioned in one of Neptune’s core areas and close to existing infrastructure. The reservoir target is the Lower Cretaceous Agat Formation and is expected to be reached at a depth of approximately 2570 m. The drilling program comprises a main bore (35/6-3 S) with an optional sidetrack (35/6-3 A) based on the outcome of the exploration well. Neptune Energy operates Ofelia with a 40% working interest. Partners are Wintershall Dea (20%), Aker BP (10%), Pandion Energy (20%), and DNO (10%). Partners Continue Successful Drilling in Algerian Desert Eni and partner Sonatrach revealed a further discovery in the Zemlet el Arbi concession, located in the Berkine North Basin in the Algerian desert. The Rhourde Oulad Djemaa Ouest-1 (RODW-1) exploration well, in the Sif Fatima II research perimeter, is the third well in the exploration drilling campaign. It led to a discovery of oil and associated gas in the Triassic sandstones of the Tagi reservoir. During its production test, the well produced 1,300 BOPD and about 2 MMcf/D of associated gas. The RODW-1 discovery comes after the significant discovery of HDLE-1, announced in March 2022, and the successful second appraisal well HDLS-1 in the adjacent Sif Fatima II. Because of their proximity to existing BRN/ROD facilities, the development of these discoveries will be fast-tracked. The Zemlet el Arbi concession is operated by a joint venture between Eni (49%) and Sonatrach (51%). The discovery is part of the new exploration campaign which will include the drilling of five wells in the Berkine North Basin.
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Guyana Prepares for Offshore Licensing Round The Guyanese government is preparing to launch its first bidding round for offshore exploration and production of hydrocarbon blocks. New fiscal terms and conditions are being finalized which the country hopes will allow it to gain the maximum economic benefits. The 2022 bidding round, which according to the nation’s Department of Public Information, is expected to be officially launched soon and will be opened for several months to give interested companies sufficient time to prepare their competitive packages and bid to win the available acreages offshore. With the upcoming bidding round the government expects Guyana’s offshore areas to emerge as a potential super basin with over 11 billion BOE discovered to date. The process seeks to ensure the country gets a fairer share of revenues from oil and gas resources through improved fiscal arrangements, as well as safeguard the safety of people and the environment by following international best practices in offshore development. The new round also aims to be competitive with other global energy projects and assure investors of stability, predictability, and security of any investment. The government seeks to balance its developmental agenda with its climate change goals. Ault Drills Successful Smackover Well in Mississippi Ault Energy completed drilling the Harry O’Neal 20-9 No. 1 in Holmes County, Mississippi, and logged productive oil results across multiple pay zones in the Smackover formation. Completion work has begun on the well, and it is expected to be on stream soon. Ault was formed by parent BitNile this past summer to make strategic oil and gas acquisitions. The company obtained participation rights with for the O’Neal No. 1 well and future oil wells when it invested $12 million in Ecoark Holdings in June. Ault Energy exercised its participation right and acquired a 40% working interest in the well, which is the first project in an expected long-term partnership between Ecoark and Ault parent companies White River and BitNile, respectively, with the intention to drill approximately 100 oil wells over 5 years. White River’s next drilling project is expected to be a 14,000-ft-deep vertical oil well in the Wilcox, Austin Chalk, and Tuscaloosa Marine Shale formations in the Coochie oil field in Concordia Parish, Louisiana. White River also plans to drill three consecutive deep vertical drilling projects at approximately 13,000 ft in the Rodessa and Hosston sand formations on the Pisgah Field Lease in Rankin County, Mississippi. Hess Brings Another Llano Well On Stream Hess brought its Llano-6 well in the Gulf of Mexico (GOM) on stream. The new well, like the other Llano wells, is tied back to Shell’s Auger facility. Hess is planning increased activity in the Llano area based on the success of Llano-6, quality of the reservoir, and adjacent high-value prospects. Hess holds a 50% interest in the long-producing Llano field, located about 150 miles off the Louisiana coast in the Garden Banks area in an estimated 2,600 ft of water. Shell, the operator, holds a 27.5% interest, and ExxonMobil has the remaining 22.5%. The field was discovered in 1997 and achieved first oil in 2004. Recent seismic reprocessing and analysis confirmed additional development opportunities in the field. Hess expects more high-value opportunities at Llano with wells planned for 2023 and 2024 and is finalizing plans for a year-long drilling campaign starting in early 2023 that will focus on tieback and hub-class opportunities in the GOM. Mubadala Discovers Gas Field Off Malaysia Mubadala Energy and its partners have announced a new gas discovery offshore Malaysia via the Cengkih-1 exploration well in Block SK 320. The exploration well was drilled to a total depth of 1680 m and encountered a 110-m gas column in the Miocene Cycle IV/V pinnacle carbonate reservoirs. The Cengkih-1 well is located nearly 220 km off the Bintulu coast in Sarawak. The discovery is near the Pegaga gas field, also located within Block SK 320. Mubadala Energy and its partners began production from the Pegaga field in March 2022. The Pegaga field has been developed with an integrated central processing platform built to handle throughput of 550 MMcf/D of gas plus condensate. A new pipeline transports gas from the platform into an existing offshore gas network and subsequently to the onshore Petronas LNG Complex. Mubadala Energy is the operator of Block SK 320 with a 55% stake. Partners Petronas and Sarawak Shell hold 25% and 20%, respectively. Petrobras Progresses Sale of Potiguar Basin Assets Petrobras entered the binding phase of the sale of 40% of its stake in the BM-POT-17 exploratory concessions, in which the Pitu well discovery assessment plan is being developed (Blocks POT-M-853 and POT-M-855), and the POT-M-762_R15 concession (Block POT-M-762), located in deep waters in the Potiguar Basin—Equatorial Margin–off the coast of Rio Grande do Norte. Petrobras currently holds a 100% stake in these concessions and will continue as operator of the partnership after the sale. Petrobras said the search for partnership in these assets is aligned with its portfolio management strategy and the improvement of the company’s capital allocation, aiming to maximize value. POT-M-853 and POT-M-855 are exploratory blocks acquired in the 7th Bidding Round of the National Petroleum Agency (ANP) in 2006. Petrobras is conducting the discovery assessment plan for the Pitu well, with a firm commitment to drill an exploratory well (Pitu Oeste) scheduled for 2023. POT-M-762 is an exploratory block acquired in the 15th ANP Bidding Round in 2018. Petrobras plans to drill the Anhangá well between 2023 and 2024. TotalEnergies Sews Up PSA on Oman’s Block 11 TotalEnergies, along with its partners, has signed an Exploration and Production Sharing Agreement (EPSA) with the Ministry of Energy and Minerals (MEM) of the Sultanate of Oman for onshore Block 11. The first stage of the EPSA activities will see seismic acquisition in late 2022, with a first exploration well planned to be drilled in 2023. TotalEnergies will hold a 22.5% interest in the block, OQ 10% and Shell with 67.5% will be the operator. Block 11 contains undeveloped discoveries and exploration potential. “Our recent activities in Oman are a demonstration of TotalEnergies’ strategy of transformation into a multi-energy company,” said Laurent Vivier, senior vice president Middle East and North Africa, exploration and production, at TotalEnergies. “Today’s entry into the Block 11 gives us the opportunity to unlock additional potential to meet domestic and export gas demand. It strengthens our strategic relationship with the Sultanate of Oman, as illustrated last December by our entry into the neighboring Block 10 gas concession and the start of construction last July of 17-MW peak solar photovoltaic systems providing power to a desalination plant.” In 2021, TotalEnergies’ production in Oman was 39,000 BOE/D. The operator produces oil in Block 6 (4%), as well as LNG through its participation in the Oman LNG (5.54%)/Qalhat LNG (2.04% via Oman LNG) liquefaction complex with an overall capacity of 10.5 mtpa. In 2021 TotalEnergies signed a concession agreement to develop natural gas resources on the onshore Block 10 (26,55%), with first gas expected in 2023. TotalEnergies also operates exploration Block 12 (80%). India Lets New Contracts Related to Small Discovered Fields, CBM The Indian government has signed contracts for 31 discovered small fields under the third round of bidding, and for four coalbed methane (CBM) blocks under the fifth round of bidding with 14 domestic companies. These blocks have been awarded. Among these blocks, the Oil and Natural Gas Corporation (ONGC) has signed six contracts for discovered small fields, with three each for fields in the Arabian Sea and Bay of Bengal. These include four contract areas as sole bidder and two contract areas in partnership with Indian Oil Corporation Ltd. The ONGC has also signed two contracts for CBM fields situated in Jharkhand and Madhya Pradesh. Cairn Oil & Gas has signed pacts for eight fields. The third round for discovered small fields was launched by the government in June 2021 where 75 fields were offered under 31 contract areas. The CBM bidding round was launched in September 2021, which concluded at the end of May 2022 with 15 blocks under offer.
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