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Angola Opens Congo, Kwanza Blocks in Ongoing Bid Round Angolaโs National Oil, Gas, and Biofuelโs Agency has opened blocks for licensing in the Onshore Lower Congo Basin and the Onshore Kwanza Basin as part of its 2020 oil and gas licensing round. This latest call to tender is part of the agencyโs ongoing 2019โ2025 hydrocarbons licensing strategy. The Onshore Lower Congo Basin Blocks include CON1, CON5, and CON6; while the Onshore Kwanza Basin Blocks comprise KON5, KON6, KON8, KON9, KON17, and KON20. The round aims to expand research and evaluation activities across sedimentary basins, increase geological knowledge of Angolaโs hydrocarbon potential, and invite a new wave of explorers to yield new discoveries. Raven Field Startup for BP in Egypt Natural gas has begun flowing from the BP-operated Raven field, the third stage of the companyโs major West Nile Delta (WND) development off the Mediterranean coast in Egypt. The $9-billion WND development includes five gas fields across the North Alexandria and West Mediterranean Deepwater offshore concession blocks in the Mediterranean Sea. Raven is currently producing approximately 600 MMcf/D with a peak potential of 900 MMcf/D and 30,000 B/D of condensate. Raven follows the Taurus/Libra and Giza/Fayoum projects, which started production in 2017 and 2019, respectively. It produces gas to a new onshore processing facility, alongside the existing WND onshore processing plant. In total, the WND development includes 25 wells producing gas to the onshore processing plant via three long-distance subsea tiebacks. The onshore facilitiesโincluding the new Raven facilityโnow have a total gas processing capacity of around 1.4 Bcf/D of gas. All gas produced is fed into Egyptโs national grid. BP is the operator and has an 82.75% stake in the WND development, with Wintershall Dea holding the remaining 17.25% interest. CGX Secures Rig for Kawa-1 Well off Guyana CGX Energy and Frontera Energy, joint venture partners in the Petroleum Prospecting License for the Corentyne block offshore Guyana, have secured semisubmersible Maersk Discoverer to drill the Kawa-1 well. An early third quarter spud for the exploration well is targeting a Santonian age, stratigraphic trap, interpreted to be analogous to the discoveries immediately to the east on Block 58 in Suriname. The well is anticipated to be drilled to a total depth of approximately 6500 m in a water depth of approximately 370 m. The contract has an estimated duration of 75โ85 days and has a one-well option attached. If exercised, that probe would spud in the nearby Demerara Block and take an estimated 40 days to reach its target. Talosโ Bulleit Reservoir in US Gulf Smaller Than Expected A technical assessment of the main producing sand performance at Talos Energyโs Green Canyon Block 21 Bulleit field in the US Gulf has indicated a smaller reservoir than originally anticipated. Project partner Otto Energy said the assessment included detailed bottomhole pressure and reservoir performance data collected after hookup and first production. The Block 21 field is flowing via a single subsea well tied back to a platform in nearby Green Canyon Block 18. While additional technical work is ongoing, the currently favored path forward is to move away from the current sand and execute a recompletion of the well in the shallower DTR-10 sand. A DTR-10 recompletion will require the procurement of long-lead items from manufacturers, which are expected to cost $3.5 million with payment expected in mid-2021. The recompletion is expected to begin in mid-2022, with production from the DTR-10 immediately following in mid-to late 2022. Captain Field EOR Stage 2 Project a Go Ithaca Energy, operator of the Captain field, has sanctioned the Captain Enhanced Oil Recovery (EOR) Stage 2 project in the UK Central North Sea after receiving Field Development Plan Addendum consent from the Oil and Gas Authority. EOR Stage 2 is designed to significantly increase hydrocarbon recovery by injecting polymerized water into the reservoir through additional subsea wells, subsea infrastructure, and new topsides facilities. Stage 1 of the project demonstrated that polymer EOR technology can work, with the production response in line with or better than expected across all injection patterns, helping maximize economic recovery. The Captain field was discovered in 1977, in Block 13/22a located on the edge of the outer Moray Firth. The billion-barrel field achieved first production in March 1997โover 24 years ago. Ithaca Energy holds 85% working interest, while partner Dana Petroleum holds the remaining 15%. Equinor Touts new Tyrihans Field Discovery Equinor and partners Total E&P Norge AS and Vรฅr Energi AS have struck oil and gas in a new segment belonging to the Tyrihans field in the Norwegian Sea. Exploration well 6407/1-A-3 BH in production license 073 was drilled from sub-sea template A at Tyrihans North. The well was drilled to a measured depth of 5332 m by semisubmersible drilling rig Transocean Norge and struck a gas column of about 43 m and an oil column of about 15 m in the Ile formation, including about 76 m of moderate to good reservoir quality sandstone. In the Tilje formation, moderate to good quality water-bearing reservoir was struck. The Tyrihans field is in the middle of the Norwegian Sea, some 25 km southeast of the ร sgard field and 220 km northwest of Trondheim. The licensees consider the discovery commercial and intend to start production immediately. Recoverable resources are so far estimated at between 19 and 26 million BOE. Maersk Awarded Intervention Work off Brazil Maersk Drilling has been awarded a contract with Karoon Energy Ltd. for the semisubmersible rig Maersk Developer to perform well intervention on four wells at the Baรบna field offshore Brazil. The contract is expected to begin in the first half of 2022, with a firm duration of 110 days. The value of the contract is $34 million, including rig modifications and a mobilization fee. The contract contains options to add up to 150 days of drilling work at the Patola and Neon fields. Carnarvon Completes Farmout of Buffalo Project Carnarvon Petroleum has completed the farmout of 50% of the Buffalo project to Advance Energy PLC. On 17 December 2020, Carnarvon announced that Advance Energy would acquire 50% of the Buffalo project off the west coast of Australia by funding the drilling of the Buffalo-10 well up to $20 million on a free carry basis. Advance met this funding requirement and now has a 50% interest in the project. The well is on track to be drilled in late 2021, subject to securing a drilling rig, where the tendering process is already underway. Following the well, the joint venture will acquire development funding from third-party lenders and any additional funding will be provided by Advance as an interest-free loan. The current plan is to suspend a successful well as a future producer and begin early development studies during 2021. Shell Hires Seadrill Rig for Brazilian Campaign Shell has contracted Seadrillโs drillship West Tellus for a new drilling campaign offshore Brazil this year. The program is expected to start in BC-10 of the Campos Basin, where Shell operates the Parque das Conchas made up of the Abalone, Argonauta, and Ostra fields. BC-10 has produced more than 100 million bbl since oil first started flowing from the block in 2009. The drillship will be used on the third phase of BC-10 activity, which includes five additional production wells and two water-injection wells at the Massa and Argonauta O-Sul fields, with the wells connected to the Espirito Santo FPSO. Shell owns a 50% operating stake in BC-10. Indiaโs ONGC retains a 27% minority share and Qatar Petroleum the remaining 23%. Following the BC-10 work, the operator is expected to drill the first wells in the Campos Basinโs C-M-791 block, which was acquired during the 15th bid round held in 2017. Shell owns a 40% operating stake in the block, with Chevron retaining a 40% interest and Portugalโs Galp Energia the remaining 20%. Panoro Energy Kicks Off 2021 Drilling Campaign Offshore Gabon Panoro Energy has initiated its 2021 Gabon drilling campaign with the spudding of the Hibiscus Extension well on the Dussafu Marin Permit. That well will be followed by drilling at Tortue and Hibiscus North. Hibiscus and Tortue are two out of a total of six discovered fields within the Dussafu Permit offshore Gabon. Panoro currently holds a 7.5% interest in the license and has entered into an agreement to acquire an additional 10% working interest in the Dussafu Permit, bringing its total ownership to 17.5% following completion of the transaction. The Extension well is being drilled with the jackup Borr Norve and is the first well in a three-well campaign planned on Dussafu during 2021. The well is planned as a vertical well to test structure, oil, and reservoir presence in what is believed to be a possible northerly extension of the Gamba reservoir in the Hibiscus field. The well is positioned about 3 km northwest of the Hibiscus discovery well drilled by the joint venture in 2019. The initial well and its appraisal sidetrack established a 2P gross recoverable reserves of just over 46 million bbl at the Hibiscus field. The Extension well is expected to take around 30 days to drill and log to a total depth of 3500 m. Success at the probe could prompt one or two appraisal side-tracks to further delineate the field. Following the Hibiscus Extension, the rig will move to drill a horizontal production well, DTM-7H, at the Tortue field. This will complete the Phase 2 development of Tortue and, along with DTM-6H, will bring the total number of production wells at Tortue up to six. An exploration well at the Hibiscus North prospect, located approximately 6 km north-northeast of the initial Hibiscus well is also scheduled. Hibiscus North is a separate 10โ40 million bbl prospect that could be tied into the Hibiscus/Ruche development project. Puma West Strike for BP in the US Gulf An exploration well at the Puma West prospect in the deepwater US Gulf has yielded a significant oil discovery for operator BP. The well, on Green Canyon Block 821, was drilled using Seadrill drillship West Auriga to a total depth of 23,530 ft and encountered oil pay in a high-quality Miocene reservoir with fluid properties like productive Miocene reservoirs in the area. Preliminary data supports the potential for a commercial volume of hydrocarbons. The Puma West partners will begin planning an appraisal program to better define the discovered resource. The discovery well has been suspended as a keeper well to preserve future utility. Puma West is located west of the BP-operated Mad Dog field and is approximately 131 miles off the coast of Louisiana in 4,108 ft of water. The Puma West is operated by BP with a 50% working interest. Partners include Chevron with 25% and Talos Energy with the remaining 25%. Petrobras Pushes First Oil at Mero Into 2022 Petrobras has postponed first oil from its Mero 1 field via the FPSO Guanabara in the Santos Basin offshore Brazil due to delays with the production system. Startup at Mero 1 was originally expected in the fourth quarter of this year and is now expected to begin flowing during the first quarter of 2022 due to COVID-19 pandemic-related delays with the buildout of the production system in China. The FPSO will be installed in the Mero field, which belongs to the Libra Block, in the Santos Basin pre-salt area, with a processing capacity of 180,000 OPD. The field is operated by Petrobras (40%) in partnership with Shell Brasil Petrรณleo (20%), Total E&P (20%), CNODC Brasil Petrรณleo e Gรกs (10%), CNOOC Petroleum Brasil (10%), and Prรฉ-Sal Petrรณleo, which is the contract manager.
- South America > Guyana > North Atlantic Ocean (1.00)
- Europe > Norway > Norwegian Sea (1.00)
- Africa > Gabon > South Atlantic Ocean (1.00)
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- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin > Demerara Block (0.99)
- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin > Corentyne Block > Kawa-1 Well (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Libra Block > Mero Field (0.99)
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KrisEnergy Pumps Cambodiaโs First Crude in 17 Years A Cambodian concession has commenced production after years of delays in a venture between Singaporeโs KrisEnergy and the government. The crude comes from oil fields in Block A, comprising 3083 km of the Khmer basin in the oil-rich Gulf of Thailand, off the southwestern coast of Sihanoukville. The concession will progress in phases once new wells are commissioned and completed. Kelvin Tang, chief executive of KrisEnergyโs Cambodian operations, called the 29 December event โan important strategic milestoneโ for the company, while Prime Minister Hun Sen hailed the first extraction as โa new achievement for Cambodiaโs economyโ and โa huge gift for our nation.โ Ironbark Australian Exploration Well Declared Dry; Co-Owner Stocks Plummet BP has come up dry at its Ironbark-1 exploration well, the anticipated multi-trillion-scf prospect off the west Australian Pilbara coast. The disappointing prospect was once seen as a potential gas supplier to the emptying North West Shelf (NWS) LNG plant, where BP is a co-owner, within 5 to 10 years. After 2 months of drilling to a total depth of 5618 m, โno significant hydrocarbon shows were encountered in any of the target sands,โ according to co-owner New Zealand Oil and Gas (NZOG). Petrorecรดncavo Buys Petrobrasโ Onshore Bahian Stake for $30 Million Brazilian operator Petrobras on 23 December signed a contract with independent producer Petrorecรดncavo to sell its entire stake in 12 onshore E&P fields, the Remanso Cluster, in the state of Bahia. The sale value for the fields was $30 million; $4 million was paid on signing, $21 million at the closing of the transaction, and $5 million will be paid 1 year after that. The Remanso Cluster comprises the onshore fields of Brejinho, Canabrava, Cassarongongo, Fazenda Belรฉm, Gomo, Mata de Sรฃo Joรฃo, Norte Fazenda Caruaรงu, Remanso, Rio dos Ovos, Rio Subaรบma, Sรฃo Pedro, and Sesmaria. Zion Spuds the Israeli Megiddo-Jezreel #2 Well On 6 January, Zion Oil and Gas officially spudded the MegiddoยญJezreel #2 on its 99,000ยญacre MegiddoยญJezreel license area in Israel. โWith unique operating conditions in the COVIDยญ19 environment, our crews have performed an amazing task,โ Zion CEO Robert Dunn said. โMobilizing a rig into a new counยญtry during a pandemic and rigging up is the most challenging part of the drilling operation,โ Zionโs vice president of operations, Monty Kness, added. Exxon Declares a Dud at Second Guyana Well Exxon Mobil said on 15 January that its exploration well in the prolific Stabroek Block off Guyanaโs coast did not find oil in its target area. Exxon, which operates the Stabroek Block in a consortium with Hess and Chinaโs CNOOC, has made 18 discoveries in the area in 5 years, totaling more than 8 billion BOE, for a combined potential for producing up to 750,000 B/D of crude. The Hassaยญ1 exploration well was the giantโs second setback to its drilling campaign in recent months. Heirs Holdings Buys 45% of Shell Nigeriaโs OML 17 Field Shell Nigeria announced on 15 January it had completed a $533 million sale of its stakes in an onshore OML 17 oil field in Nigeria to African strategic investor Heirs Holdings, Nigeriaโs largest publicly listed conglomerate. The deal is one of the largest oil and gas financings in Africa in more than a decade, with a financing component of $1.1 billion provided by a consortium of global and regional banks and investors. Heirs Holdings, in partnership with Transcorp, one of the largest power producers in Nigeria with 2000 MW of installed capacity, purchased 45% stake in the field. It acquired the stakes of Shell, Total, and Eni to further its expansion into the oil and gas industry. Apex Discovers Oil in Egyptโs Western Desert Privately held independent E&P firm Apex International Energy, backed in part by UK energy investment firm Blue Water Energy, on 18 January announced a discovery in the Southeast Meleiha Concession (SEM) in the western desert of Egypt. The discovery was made at the SEMZ-11X well located 10 km west of Zarif field, the nearest producing field. The well was drilled to a total depth of 5,700 ft and encountered 65 ft of oil pay in the Cretaceous sandstones of the Bahariya and Abu Roash G formations. Testing of the Bahariya resulted in a peak rate of 2,100 B/D with no water. Additional uphole pay exists in the Bahariya and Abu Roash G formations that can be added to the production stream in the future. Kosmos Announces Oil at Winterfell Well Dallas-based E&P independent Kosmos Energy announced on 19 January an oil discovery in deepwater US Gulf of Mexico. The Winterfell discovery well, the product of infrastructure-led exploration (ILX), was drilled to a total depth of approximately 23,000 ft and is located in approximately 5,300 ft of water. This subsalt Upper Miocene prospect in off-shore Louisiana encountered approximately 85 ft of net oil pay in two intervals. ILX exploration, which has featured prominently in upstream operatorsโ portfolios in recent years of relatively low oil prices, is exploration around producing hubs that can be hooked up to those facilities easily and cheaply. The development sidesteps the need for costly and time-consuming individual hub construction. Equinor Gets Permit To Drill North Sea Wildcat Well The Norwegian Petroleum Directorate has granted Equinor a drilling permit for wildcat well 31/11-1 S in the North Sea offshore Norway, 62 km south of the Troll field. The drilling program is the first exploration well to be drilled in production license 785 S, awarded on 6 February 2015 (APA 2014). Operator Equinor and Total E&P Norge are 50/50 partners in the license, which consists of parts of Blocks 26/2 and 31/11. Petrobras, ExxonMobil Hit Hydrocarbons at Urissanรช Well, Offshore Brazil Brazilian state-owned Petrobras announced on 29 January it had discovered hydrocarbons in a well located in the Campos Basin presalt off Brazilโs coast of Campos dos Gotyacaze in the State of Rio de Janeiro. Well 1-BRSA-1377-RJS (informally called Urissanรช) is located in Block C-M-411, at a depth of 2950 m approximately 200 km offshore. Petrobras, which operates the block in a 50/50 partnership with Exxon Mobil, said it would analyze the well data to better target exploratory activities and assess the potential of the discovery. BP Offloads 20% Share of Omanโs Block 61 To PTTEP Marking another significant step in its divestment program, BP will sell a 20% participating interest in Omanโs 3950 km Block 61 in central Oman to Thailandโs national PTT Exploration and Production (PTTEP) for $2.59 billion. BP will remain operator of the block, holding a 40% interest.โ The sale comprises $2.45 billion payable on completion and $140 million payable contingent on preagreed conditions.โ After the sale, BP will hold 40% interest in Block 61, while OQ holds 30%, PTTEP โ20%, and โPetronas 10%.โ Block 61 contains the largest tight gas development in the Middle East.
- South America > Guyana > North Atlantic Ocean (1.00)
- Asia > Thailand (1.00)
- Asia > Middle East > Oman (1.00)
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- Government > Regional Government > South America Government > Brazil Government (1.00)
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- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin > Stabroek Block > Payara Field (0.99)
- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin > Stabroek Block > Liza Field > Liza-1 Well (0.99)
- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin > Kaieteur Block > Maastrichtian Formation > Tanager-1 Well (0.99)
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Shell Explores Plans for North Slope Development Dutch oil major Shell is looking to further develop its North Slope oil position in Alaska. The companyโs offshore unit applied to form the West Harrison Bay Unit offshore from the National Petroleum ReserveโAlaska with plans for drilling and exploration. The proposed West Harrison Bay Unit comprises 18 leases in West Harrison Bay approximately 34 miles northwest of the Colville River Unit. Shell holds 100% working interest in those 18 leases, covering more than 78,000 acres in the proposed unit. The company is identifying partners to share in the risk and costs, with plans to drill exploration wells in the West Harrison unit with at least one sidetrack each in 2023 and 2024. Because economic uncertainty from the pandemic and oil-price crash made negotiations difficult with potential partners, Shell requested the initial West Harrison Bay exploration plan to be for 5 years to allow enough time to find a partner and improve its plan. The wells would target the Nanushuk oil formation first identified by the Repsol-Armstrong Energy partnership in the Pikka Unit. The shallow, conventional formation also forms the basis of ConocoPhillipsโ large Willow oil prospect to the south of Harrison Bay and is believed by many in the industry to be prolific across much of the western North Slope. Shell has been operating in Alaska since the 1950s when it began exploration in the Cook Inlet Basin. It acquired the West Harrison Bay leases in 2012, and redirected focus to the leases in 2017, generating five standalone prospects in the Nanushuk and multiple leads in the Torok formation and Jurassic Alpine-like plays.
- Asia > Middle East (0.73)
- Oceania > Australia > Western Australia (0.72)
- North America > United States > Alaska > Kenai Peninsula Borough > Cook Inlet (0.25)
- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin > Stabroek Block (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Buzios Field > Guaratiba Formation (0.99)
- South America > Brazil > Brazil > South Atlantic Ocean > Santos Basin (0.99)
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E&P Notes Nine Months After Discovery, Eni Starts Offshore Angolan Oil Field Eni achieved first oil at the Agogo oil field located in the 15/06 Block offshore Angola. The startup comes just 9 months after the field was discovered thanks to the use of a floating, production, storage, and offloading (FPSO) unit, the NโGoma production hub that is less than 10 miles away. The Italian oil and gas company said it drilled the production well in a water depth of around 5,500 ft and achieved an initial production rate of close to 10,000ย B/D. Peak output is expected to reach 20,000 B/D in the coming weeks. Eni estimates the field holds more than 650 bbl of crude and says the potential may increase after more delineation wells are drilled. ย ExxonMobil: Another Guyana Discovery, Ups Reserves Uaru is the name of ExxonMobilโs 16th discovery in the waters offshore Guyana. The Uaru well is found within the Stabroek Block and is located about 10 miles to the northeast of the Liza field, which achieved first production in December. ExxonMobil reports that it found 94 ft of oil-bearing sandstone reservoir while drilling the well in a water depth of 6,342ย ft. The international major also announced that the 15 discoveries it made prior hold an estimated 8 billion BOEโan increase of 2 billion BOE from its previous estimate. ExxonMobil did not break down the figure into estimated quantities of crude or natural gas. ย EIA: US Crude and Renewables Will Coexist for Decades The makeup of the US energy sector is on the fast track to diversificationโplacing natural gas and renewable sources in a head-to-head race over the next decade for the nationโs most dominant source of electric power. Meanwhile, the future remains bright for US oil and gas production as well as the countryโs newly established export profile. A critical byproduct of the energy transition will be lower to only modestly growing CO2 emissions. This is all according to the US Energy Information Administrationโs (EIA) Annual Energy Outlook 2020 that is used by government officials to steer energy policy and the business world to guide future investments. ย Lundin Petroleum Joins Decarbonization Movement Lundin Petroleum aims to become carbon neutral by 2030, joining a growing cadre of European-based oil and gas companies making similar commitments. The Swedish oil and gas company will also change its name to Lundin Energyโdisposing of โPetroleumโโlater this year if shareholders approve the move. The company said it will drastically reduce its carbon footprint to address the oil and gas industryโs dual challenge of mitigating climate change while still providing enough energy resources to meet global demand. ย Schlumberger, Halliburton Downsize Fracturing Services The worldโs two largest oilfield service firms are moving quickly to reduce their exposure to the slowing North American unconventional sector by laying down substantial portions of their fracturing fleets. Schlumberger and Halliburton told investors on earnings calls not to expect a market turnaround in either the US or Canada any time soon, while playing up the importance of markets elsewhere. The companies began last year as the number one and two providers of pressure pumping services in North America; Halliburton providing 4.6 million horsepower and Schlumberger 2.6 million horsepower. ย Oilfield Giant McDermott Files for Bankruptcy Houston-based McDermott announced that it is entering into a pre-packaged restructuring program that will be carried out under the scope of the US Chapter 11 process. The move will effectively eliminate the oilfield engineering and construction companyโs debt load of $4.6 billion. McDermott said in a statement that the arrangement has the support of two-thirds of its creditors and that all ongoing projects will continue without disruption. The company said late last year that it holds a project backlog valued at $20 billion. ย Eni, ADNOC Sign Carbon Capture Agreement Eni and Abu Dhabi National Oil Company (ADNOC) have signed a memorandum of understanding for the joint development of research initiatives aimed at creating advanced technology solutions for the reduction, capture, usage, or confinement (CCUS) of CO2 emissions. The agreement will cover the five offshore projects in Abu Dhabi in which Eni is an equity participant. The agreement also will explore processes and technologies to promote the โcircular economyโโthe regenerative economic approach that is aimed at eliminating waste and continually using and reusing resourcesโover the traditional linear approach. The CO2 will be used to improve the hydrocarbon recovery factor and will be permanently stored. ย Israel Starts Exporting Natural Gas to Egypt Israel has begun exporting natural gas to Egypt under what has been called one of the most important deals to have been signed by the neighboring countries since their historic 1979 peace treaty. The terms of the deal call for Dolphinus Holdings, a private firm in Egypt, to purchase 85 Bcm of gas, worth an estimated $19.5 billion, from Israelโs Leviathan and Tamar offshore fields over 15ย years via a subsea pipeline connecting Israel and Egyptโs Sinai Peninsula. Gas from Leviathan will be supplied to Dolphinus at a rate of 2.1 Bcm per year, rising to 4.7 Bcm per year by the second half of 2022, according to Delek Drilling, one of the partners in Leviathan and Tamar. Israel will initially export 200 MMcf/D, according to Egyptian industry sources. ย Federal Investigators Probe Central Texas Blowout The US Chemical Safety Board will send a team to central Texas to investigate a blowout that killed three service company employees working on a Chesapeake Energy well. The board looks into major accidents in the energy sector, such as the blowout in Oklahoma that killed five workers in 2018, searching for the cause and changes that could reduce the risk of it happening again. The victims were using a service rig last week to install hardware in the well, according to a news report quoting a Chesapeake spokesperson, Gordon Pennoyer. One man died at the scene, while two others who were rushed to hospitals died in the days that followed. ย Report: BP Pulling Out of Iraq Field BP is pulling out of Iraqโs giant Kirkuk oil field after its current exploration contract expired and a new deal was not reached for the fieldโs expansion, according to the Reuters news agency. The supermajor told Iraqi authorities in January that its staff would be leaving the oil field, which is located in the north of the country. BPโs 2013 $100-million service contract expired at the end of 2019, sources told Reuters. BP apparently told Iraq that the development did not meet its expectations. ย Talos Shares Zama Reserves Audit of Mexico Field Talos Energy has released the results of a new independent evaluation of its Zama discovery offshore Mexico, which estimates the asset holds about 670 millionย BOE in recoverable resources. The estimates are in line with Talosโ pre-appraisal estimates of 400โ800ย millionย BOE. The Zama field is the first discovery made by a foreign company in the Mexican side of the Gulf of Mexico (GOM) following the historic opening of the countryโs oil and gas sector in 2015. Details of the reserves audit were shared amid ongoing negotiations between Houston-based Talos, Mexicoโs state-owned oil company Pemex, and Mexican regulators over revenue sharing through unitization.
- South America > Guyana > North Atlantic Ocean (1.00)
- North America > United States (1.00)
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- Press Release (0.69)
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- Government > Regional Government > Asia Government > Middle East Government > UAE Government (0.89)
- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin > Stabroek Block > Uaru Well (0.99)
- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin > Stabroek Block > Payara Field (0.99)
- South America > Guyana > North Atlantic Ocean > Guyana-Suriname Basin > Stabroek Block > Liza Field (0.99)
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New Merger to Create Third-Largest US Pressure Pumper In an all-stock deal, US service companies Keane Energy and C&J Energy Services announced that they are merging. Upon regulatory approval, the development will result in the third-largest service company based on hydraulic fracturing horsepower (HHP). The deal will further consolidate a market segment that has been under pressure to reduce operating costs since the onset of the oil price downturn almost 5โขyears ago. Ownership is to be split evenly between Keane and C&J shareholders, each holding 50% of the new stock. With unanimous approval from the board of directors of both companies, the merger is expected to be completed by the end of the year. The combined entity will be worth $1.8 billion, with an annual revenue of $4.2 billion, 66% of which will come from the pressure pumping service line. โข Hurricane Hits First Oil From Basement Reservoir in North Sea Hurricane Energy reported 18 June that the first cargo of oil extracted from a naturally fractured basement reservoir in the UK North Sea had been successfully loaded onto a tanker. First oil from two horizontal subsea wells was achieved from the Lancaster field, located to the west of the Shetland Islands, at the start of this month after a successful well test that had a combined production rate of 20,000 B/D. With an expected uptime of 85%, the long-term target for UK-based Hurricane is to produce 17,000 B/D. The announcement marks an historic moment for the offshore oil and gas industry in the UK since the Lancaster field is the countryโs first to produce commercial quantities from a naturally fractured basement reservoir. โข ExxonMobil Proceeds with Long-Term Vaca Muerta Shale Oil Development ExxonMobil will move forward with a long-term oil development in Argentinaโs Bajo del Choique-La Invernada block, part of the Vaca Muerta Shale, that is expected to produce up to 55,000โขBOE/D within 5 years. The project will consist of 90 wells, a central production facility, and export infrastructure connected to the Oldeval pipeline and refineries. If the expansion is successful and business and market conditions allow, ExxonMobil may invest in a second phase that would produce up to 75,000 BOE/D, the companyโขsaid. โWe are encouraged by the excellent results of our Neuquรฉn pilot project and look forward to increased production through this significant expansion,โ said Staale Gjervik, ExxonMobil senior vice president of unconventional. โThe reforms implemented by the federal and provincial governments have been critically important to enabling the development of the Vaca Muerta basin as one of the countryโs main energy resources.โ โข Thirty Firms Awarded Blocks in UKโs 31st Offshore Licensing Round The UK Oil and Gas Authority (OGA) has awarded 37 licenses covering 141 blocks or partial blocks to 30 companies in the 31st Offshore Licensing Round. The round offered frontier areas on the UK Continental Shelf (UKCS) in theโขFaroe-Shetland Basin, Moray Firth, East Irish Sea, East Shetland Platform, Mid North Sea High, and English Channel. It marked a continuation of a recent trend on the UKCS in which lesser-known firms and newcomers have gained stature, though some of the larger, more-familiar operators still showed a desire in the round to maintain a presence in the basin. Privately held Corallian Energy and Equinor were each awarded five licenses, more than any other company. Corallian, based in Stroud, UK, and founded in 2015, is operator of all five of its licenses, while Equinor will operate four and serve as partner on one. โข Global Energy Demand in 2018 Grew at the Fastest Pace This Decade Despite weakening growth in GDP and strengthening energy prices in 2018, global energy demand last year rose at its fastest pace since 2010, according to BPโs 2019 Statistical Review of World Energy. China, India, and the US were responsible for two-thirds of the 2.9% increase in consumption, BP Group Chief Economist Spencer Dale said in releasing the report. The widely followed annual statistical review said that demand growth pervaded all fuels, most of which grew more strongly than their historical averages. Natural Gas Leads the Way Both consumption and production of natural gas grew more than 5%โone of its strongest growth rates in more than 30 yearsโmaking up almost 45% of the entire growth in global energy consumption. โข Dorado Discovery Off Australia Is Bigger Than Expected The Santos Energy-operated Dorado-2 appraisal well has uncovered more hydrocarbons, primarily gas, from the already-large Dorado discovery offshore Western Australia reported last year. The appraisal well, drilled down-dip 2โขkm from the Dorado-1 discovery in the Bedout Basin, encountered 85 m of net reservoir in the primary Caley formation. As expected, an oil/water contact was intersected at 4003โขm measured depth, with 40 m of net oil pay encountered, the Adelaide-based operator said. Another 11 m of pay was encountered inโขthe Upper Caley sands, with preliminary wellsite analysis indicating this upper zone is oil-bearing. But it is subject to additional analysis to confirm the hydrocarbon phase. โข Murphy Oil to Buy Deepwater US Gulf Assets for up to $1.625 Billion Murphy Oil has agreed to acquire deepwater US Gulf of Mexico assets from LLOG Exploration for up to $1.625 billion. The deal will result in the El Dorado, Arkansas-based Murphy adding 32,000โ35,000 BOE/D net to its 2019 US gulf production, of which 60% will be oil, bringing its total US gulf output to 85,000โขBOE/D net. The gulf will represent 66% of the companyโs total dailyโขproduction.โข โWith this transaction, Murphy becomes the eighth-highest producer in the Gulf of Mexico. Only a year ago, they were No. 20,โ said Imran Khan, senior research manager, US Gulf of Mexico upstream oil and gas, at consultancy Wood Mackenzie, in comments on theโขdeal.
- Europe > United Kingdom > North Sea (0.95)
- South America > Argentina > Neuquรฉn Province > Neuquรฉn (0.89)
- Oceania > Australia > Western Australia (0.87)
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- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.69)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.45)
- South America > Argentina > Patagonia > Neuquรฉn > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- Oceania > New Zealand > West Basin (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Roebuck Basin > Bedout Basin > WA-437-P Permit > Block WA-437-P > Dorado Field > Milne Sandstone Formation > Dorado-1 Well (0.99)
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Techbits An SPE Applied Technology Workshop (ATW) on subsea processing recently took place in Stresa, Italy. The workshop was divided into sessions covering concept development, subsea boosting, subsea compression, subsea power, subsea separation, and operational experience. Each session included topic presentations, question-and-answer sessions, and mini-workshops allowing participants to interact, learn, and share from one another. Subsea processing is allowing increased recovery, lower capital and operating expenses, and health, safety, and environmental (HSE) benefits. Subsea processing success stories are increasing in number and during the workshop participants heard that: Petrobras has extensive experience from subsea electric submersible pumps (ESPs) and has recently applied subsea mudline multiphase pumping (MMP) pumps at the Barracuda field, subsea raw water injection pumps at the Albacora field, horizontal mudline ESP skid at the Espardarte field, and a subsea gas/liquid separation system and an oil/water separation system at the Marlim field. At the Vincent field, Woodside has applied a subsea MPP system, including two off multiphase pumps. The processing system has given accelerated production and increased the availability of topside facilities and will extend the production life of wells. Pazflorโs subsea separation units (SSUs) have been in operation and operator Total considers the project a success for subsea processing. SSUs make topsides facilities easier to operate. Statoil and Shell are confident that the technology can be deployed at Ormen Lange. Rigorous qualification testing, access to good test facilities, and a stepwise development of technologies are important factors to succeed with the implementation of new subsea processing technologies and to mitigate risk. Communication of success stories and a correct allocation of risk for subsea processing technologies are critical to the selection of subsea processing solutions by decision makers. Concrete new subsea separation projects and business cases are relatively few and there seems to be less confidence and some confusion about the maturity of separation technologies. Several suggestions for improvement were discussed during the workshop. Generally, oil companies have confidence in subsea processing solutions, but costs are becoming a serious issue. If costs continue to increase, deployment of new technologies could be hampered.
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.54)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Marlim Field > Macae Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Marlim Field > Lago Feia Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Albacora Field (0.99)
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Techbits The SPE Applied Technology Workshop (ATW) titled "Capture and Geological Storage of CO2" was held in Perth, Australia, from 7โ10 October. Attending the ATW were 107 participants, representing 50 different organizations from 15 countries. The workshop's chief objective was to provide an overview of current CO2 capture and storage (CCS) technology and projects, as well as a look ahead into how technical, economic, and policy developments might facilitate large-scale, widespread application of CCS to mitigate greenhouse-gas (GHG) levels. Cochairpersons Scott Imbus and John Kaldi opened the ATW's initial session with an overview of the goals and expectations for the week, which was followed by the first keynote address, "Carbon Dioxide Capture and Geologic Storage: Research, Development, and Application in Australia," given by Peter J. Cook, chief executive, Cooperative Research Centre for Greenhouse Gas Technologies, which is known as CO2CRC. Cook focused on the role of CO2CRC's Otway basin pilot project in setting a precedent for safe, effective geological storage of CO2 in Australia. The second keynote speaker, John Bradshaw, chief scientist, Geoscience Australia, spoke on "Technical and Regulatory Impacts of Implementing a Geological Storage Regime." Bradshaw reviewed results of the national storage-capacity assessment and the need for a regulatory regime knowledgeable on the trapping and migration properties of CO2 at the large scale. The need for technical rigor to earn public assurance was stressed. The perspectives of energy providers, including oil and gas companies, coal producers, and utilities, formed Session 2. While recognizing that capture technology is commercially available, speakers focused on the large costs that will be borne by the public and industry. Development and demonstration of more-cost-effective capture technology are needed, but funding for demonstration projects is lacking, they agreed. Subsurface aspects of CCS are familiar to the oil and gas industry but not to the public, they pointed out. The risks of CO2 storage can be managed during capture-and-storage operations. However, long-term liability afterward should be dealt with at the public-policy level rather than through the avenue of litigation against the project participants, the speakers noted. Session 3 overviewed technologies and approaches to site assessment. A recurrent theme was balancing information available with that needed to provide suitable models and simulations, as well as the implications of uncertainty. The importance of natural analogs, flexible workflows, and improved, coupled simulations was stressed. Storage assurance was the topic of Session 4. Monitoring programs should be fit-for-purpose, performance-based, and designed to detect and mitigate leakage in the deep subsurface, speakers said. Understanding fault stability through geomechanical studies will help determine whether faults will be vulnerable to CO2 leakage. Well-integrity studies, including assessment protocols, new well-construction design, and materials and intervention options, will be essential to the long-term security of storage sites, speakers said, adding that risk assessment incorporates all technical assurance issues but at present is not "quantitative." By framing CO2 injection, migration, and trapping scenarios, however, the assessment process serves to align stakeholder perception and risk tolerance, speakers noted.
- Oceania > Australia > Tasmania > Bass Strait (0.36)
- Oceania > Australia > Western Australia > Perth (0.24)
- Summary/Review (1.00)
- Instructional Material > Course Syllabus & Notes (0.41)
- Europe > Norway > North Sea > Central North Sea > South Viking Graben > PL 046 > Block 15/9 > Sleipner Field > Draupne Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > South Viking Graben > PL 046 > Block 15/8 > Sleipner Field > Draupne Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > South Viking Graben > PL 046 > Block 15/6 > Sleipner Field > Draupne Formation (0.99)
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- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
- Facilities Design, Construction and Operation > Unconventional Production Facilities > CO2 capture and management (1.00)
A simple surface facility consisting of a "gunbarrel tank separator" and storage tanks for processed oil. Separated produced water flows to a fiberglass tank to await off-site disposal. Surface water ran Seepages of asphaltic bitumen in brine. It was only after the into the sumps, dirt and other debris Mesopotamia around 3000 B.C. were the Drake well was drilled in 1859 that commercial caused problems and they were messy," raw material for a "petroleum" industry oil and natural gas exploration Campbell adds. It primarily began in earnest. In time, surface likely drilling sites for exploration and on minimum from a flowing well by providing facilities for this production involved a completing oil wells on those locations," a flow tank connected to the casing head... crude type of distillation.
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- Health, Safety, Environment & Sustainability > Environment > Water use, produced water discharge and disposal (1.00)
- Facilities Design, Construction and Operation > Processing Systems and Design > Separation and treating (1.00)
This article is a synopsis of paper SPE 50081, "High-Rate-Gas-Well Design: Issues and Solutions - Goodwyn Gas Condensate, NWS, Australia," by D. Teng, SPE, G. Nettleship, SPE, S. Hicking, and K. Hindmarsh, Woodside Energy Ltd., originally presented at the 1998 SPE Asia Pacific Oil and Gas Conference and Exhibition, Perth, Australia, 12-14 October.
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Dampier Basin > Rankin Platform > North West Shelf > North Rankin Field (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Dampier Basin > Dixon Basin > Rankin Platform > North West Shelf > WA-5-L > Goodwyn Field (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Dampier Basin > Carnarvon Basin > Rankin Platform > North West Shelf > WA-5-L > Goodwyn Field (0.99)
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