Academic literature on the topic 'MADA s.p.a.m. (Firm)'

Energean Secures Rig for Multiwell Program off Israel Energean has signed a contract with Stena Drilling for an up to five-well drilling program offshore Israel, which is expected to target the derisking of unrisked prospective recoverable resources of more than 1 billion BOE. The contract is for the drilling of three firm wells and two optional wells using drillship Stena Icemax. The first firm well is expected to spud in early 2022. The firm wells are all expected to be drilled during 2022. “Our five-well growth program off-shore Israel, commencing in the first quarter of 2022, has the potential to double Energean reserve base with resource volumes that can be quickly, economically, and safely monetized,” said Mathios Rigas, chief executive of Energean. “Combined with first gas from our flagship Karish gas development project in mid-2022, the next 12 months are set to be truly transformational for Energean.” One of the firm wells is the Karish North development well. The scope includes re-entry, sidetracking, and completion of the previously drilled Karish North well and completion as a producer. The Karish North development will commercialize 1.2 Tcf of natural gas plus 31 million bbl of liquids and is expected to deliver first gas during the first half of 2023. The program also includes the Karish Main-04 appraisal well and the Athena exploration well, located in Block 12, directly between the Karish and Tanin leases. Athena is estimated to contain unrisked recoverable prospective resource volumes of 0.7 Tcf of gas plus 4 million bbl of liquids. Exxon Hits, Misses off Guyana ExxonMobil made another new discovery in the Stabroek Block offshore Guyana but came away empty with a well on the Canje block. The Longtail-3 well on the Stabroek block struck 230 ft of net pay, including newly identified reservoirs below those intervals found in the Longtail-1 probe. “Longtail-3, combined with our recent discovery at Uaru-2, has the potential to increase our resource estimate within the Stabroek block, demonstrating further growth of this world-class resource and our high-potential development opportunities offshore Guyana,” said Mike Cousins, senior vice president of exploration and new ventures at ExxonMobil. Exxon operates the 6.6-million-acre Stabroek Block as part of a consortium that includes Hess and China’s CNOOC. The new well was drilled 2 miles south of Longtail-1, which was drilled in 2018 and encountered 256 ft of oil-bearing sandstone. The Uaru-2 well in the Stabroek Block was announced in April. That well struck 120 ft of pay. While Stabroek drilling success continues, the operator suffered a set-back on the nearby Canje block and its Jabillo-1 well. The Stena Carron drillship reached a planned target depth of 6475 m; however the well failed to encounter commercial hydrocarbons. According to partner Eco Oil and Gas, the well was drilled to test Upper Cretaceous reservoirs in a stratigraphic trap. Drillship Stena Drillmax will next mobilize to drill the Sapote-1 prospect located in the south-eastern section of Canje, in a separate and distinct target from Jabillo. Sapote-1 lies approximately 100 km southeast of Jabillo and approximately 50 km north of the Haimara discovery in the Stabroek Block, which encountered 207 ft of gas-condensate-bearing sandstone reservoir. Erdogan Touts Turkish Black Sea Natural Gas Discoveries Turkey President Recep Tayyip Erdogan announced the discovery of new natural gas deposits in the Black Sea, where the country plans to start production in 2023. State energy company Tpao found 135 Bcm of gas at the Amasra-1 off-shore well, bringing the total amount of deposits discovered over the past year to 540 Bcm, according to Erdogan. Turkey has ramped up offshore exploration for hydrocarbons over the past few years. Last year, explorers found 405 Bcm of gas at the Tuna-1 well in Sakarya field. Turkey currently imports nearly all the 50 Bcm of gas it consumes annually. Equinor Hits Oil Near Visund Equinor struck oil in Production License 554 with a pair of wells at its Garantiana West prospect. Exploration wells 34/6-5 S and 34/6-5 ST2 were drilled some 10 km north-east of the Visund field, with the former encountering a total oil column of 86 m in the Cook formation. The latter well encountered sandstones in the Nansen formation, but did not encounter commercial hydro-carbons. Recoverable resources are esti-mated at between 8 and 23 million BOE. “This is the first Equinor-operated well in the production license, and the fifth discovery on the Norwegian continental shelf this year,” said Rune Nedregaard, senior vice president, exploration and production south. “The discovery is in line with our roadmap of exploring near existing infrastructure in order to increase the commerciality.” Well 34/6-5 S was drilled using Seadrill semisubmersible rig West Hercules. Equinor operates the discovery; partners include Var Energi and Aker BP. ExxonMobil Eyes Flemish Pass Well ExxonMobil is looking to secure a semi-submersible to complete the drilling of a deepwater wildcat in the Flemish Pass offshore eastern Canada. The operator began drilling the Hampden K-41 probe in the spring of last year using Seadrill semisubmersible rig West Aquarius, but the unit was pulled off the well soon thereafter for reasons unknown. ExxonMobil is currently prequalifying companies to supply a mobile offshore drilling unit to continue the well at Hampden in Exploration License (EL) 1165A. The operator is targeting a mid-year 2022 start to the probe to be drilled in around 1175 m of water, some 454 km from St. John’s, Newfoundland. Meanwhile, China’s CNOCC has wrapped up drilling on its Pelles prospect, its first exploration well offshore Newfoundland. The prospect, in about 1163 m of water, is located within license EL 1144. The wildcat was originally set to spud in early 2020 but was delayed due to impacts of the COVID-19 pandemic. The company confirmed that drilling operations onboard drillship Stena Forth were complete and the rig plugged and abandoned the well. The results of the well were not released. Equinor To Drop Mexican Offshore Leases Equinor will exit two Mexican deepwater blocks as part its upstream investment strategy to focus on assets offering rapid and strong returns. The two blocks located in the Salina Sureste basin were acquired in Mexico’s 1.4 bid round in an equal equity split with BP and TotalEnergies. Block 3, where Equinor holds a 33% operating interest, has water depths ranging from 900 to 2500 m. Block 1, where BP is the operator, has water depths ranging from 200 to 3100 m. Exploration commitments include a single well on each block, not yet drilled. The announcement to exit Mexico was made by Executive Vice President for E&P International Al Cook during the company’s Capital Markets Day event held in June. The company also unveiled plans to leave Nicaragua and Australia, as part of its upstream investment plans. Cook added that Equinor will only operate offshore assets moving forward and will no longer operate onshore, unconventional projects. The company will instead opt to partner with others on those projects. Equinor will also look to offload its exploration assets in the Austin Chalk play in the US and Terra Nova in Canada, he said. Var Energi Strikes North Sea Oil Var Energi has confirmed a discovery at its King and Prince exploration wells in the Balder area in the Southern North Sea. Success at the combined King and Prince exploration wells lifts preliminary estimates of recoverable oil equivalents between 60 and 135 million bbl. King/Prince was drilled in PL 027 by semisubmersible rig Scarabeo 8. The Prince well encountered an oil column of about 35 m in the Triassic Skagerrak formation within good to moderate reservoir sandstones, while the King well discovered a gas column of about 30 m and a light oil column of about 55 m with some thick Paleogene sandstone. An additional King appraisal side-track further confirmed a 40-m gas column and an oil column of about 55 m of which about 35 m are formed by thick and massive oil-bearing sandstone with excellent reservoir quality. The licensees consider the discoveries to be commercial and will assess tie-in to the existing infrastructure in the Balder area. The wells are located about 6 km north of the Balder field and 3 km west of the Ringhorne platform. Var Energi operates and holds a 90% stake of the license. Mime Petroleum holds the remaining 10%.

KrisEnergy Pumps Cambodia’s First Crude in 17 Years A Cambodian concession has commenced production after years of delays in a venture between Singapore’s KrisEnergy and the government. The crude comes from oil fields in Block A, comprising 3083 km2 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 KrisEnergy’s Cambodian operations, called the 29 December event “an important strategic milestone” for the company, while Prime Minister Hun Sen hailed the first extraction as “a new achievement for Cambodia’s economy” and “a huge gift for our nation.” 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, “no significant hydrocarbon shows were encountered in any of the target sands,” according to co-owner New Zealand Oil and Gas (NZOG). Petrorecôncavo Buys Petrobras’ Onshore Bahian Stake for $30 Million Brazilian operator Petrobras on 23 December signed a contract with independent producer Petrorecôncavo 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 Belém, Gomo, Mata de São João, Norte Fazenda Caruaçu, Remanso, Rio dos Ovos, Rio Subaúma, São Pedro, and Sesmaria. Zion Spuds the Israeli Megiddo-Jezreel #2 Well On 6 January, Zion Oil and Gas officially spudded the Megiddo­Jezreel #2 on its 99,000­acre Megiddo­Jezreel license area in Israel. “With unique operating conditions in the COVID­19 environment, our crews have performed an amazing task,” Zion CEO Robert Dunn said. “Mobilizing a rig into a new coun­try during a pandemic and rigging up is the most challenging part of the drilling operation,” Zion’s 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 Guyana’s coast did not find oil in its target area. Exxon, which operates the Stabroek Block in a consortium with Hess and China’s 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 Hassa­1 exploration well was the giant’s second setback to its drilling campaign in recent months. Heirs Holdings Buys 45% of Shell Nigeria’s 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, Nigeria’s 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 Egypt’s 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 operators’ 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 Urissanê 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 Brazil’s coast of Campos dos Gotyacaze in the State of Rio de Janeiro. Well 1-BRSA-1377-RJS (informally called Urissanê) 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 Oman’s Block 61 To PTTEP Marking another significant step in its divestment program, BP will sell a 20% participating interest in Oman’s 3950 km2 Block 61 in central Oman to Thailand’s national PTT Exploration and Production (PTTEP) for $2.59 billion. BP will remain operator of the block, holding a 40% interest.‎ The sale comprises $2.45 billion payable on completion and $140 million payable contingent on preagreed conditions.‎ After the sale, BP will hold 40% interest in Block 61, while OQ holds 30%, PTTEP ‎20%, and ‎Petronas 10%.‎ Block 61 contains the largest tight gas development in the Middle East.

CNOOC Turns Taps on Bohai Bay Fields Volumes are flowing from two new CNOOC-operated field developments in the Bohai Sea, offshore China. Production began at the Luda 5-2 oil field north phase 1 project in Liaodong Bay. The field is in an average water depth of around 32 m. CNOOC installed one thermal recovery wellhead platform and one production platform, and connected processing facilities serving the Suizhong 36-1 oil field. The company plans to drill a total of 26 production and two water-source wells, with peak crude oil production of 8,200 B/D targeted for 2024. Oil also is flowing at the Kenli 6-1 oil field 4-1 block development in the southern Bohai Sea. A new wellhead platform in about 17 km of water is connected to processing facilities at the Bozhong 34-9 oil field. CNOOC plans a total of seven producer and five water-injector wells at Kenli 6-1, with peak oil production later this year of around 4,000 B/D. CNOOC holds a 100% stake in both projects. Sailaway for GTA FPSO Expected by Year-End A BP executive told conference goers in Senegal recently that the FPSO destined for that country’s Greater Tortue Ahmeyim (GTA) gas project is expected to leave China prior to year-end. BP Executive Vice President for Production and Operations Gordon Birrell added that the first phase of the GTA project is 80% complete. The main function of the FPSO will be to remove water and condensate and reduce impurities in the gas stream before exporting processed gas to a nearby FLNG facility and domestic gas offtake. BP and Kosmos Energy are leading the development of GTA and Yakaar-Teranga, Senegal’s first natural gas projects. GTA straddles the border between Senegal and Mauritania. Phase 1 of the planned development is expected to start delivering gas by the end of 2023. Birrell added that BP is in discussions with Senegal and Mauritania about GTA’s second phase and other projects in both countries, but did not get into specifics, according to Reuters. Phase two should double expected production from 2.5 to 5.0 mtpa. ReconAfrica, NAMCOR Reach Target Depth on Namibia Well Reconnaissance Energy Africa and its joint venture partner NAMCOR, the state oil company of Namibia, confirmed the third stratigraphic test well in the Kavango basin of northeast Namibia, 1819/8-2, reached target depth. The well was drilled to a total depth of 2056 m reaching all geological targets. However, the duo did not reveal what was found in the well. Instead, the pair said current operations were focused on well data capture and initiating analysis of the data. Company-owned rig Jarvie-1 will remain on site until logging and coring operations are completed. A vertical seismic profile tool will also be run to total depth to tie into the 2D seismic program. Processing of the second phase of 761 km of 2D seismic is near completion, where early results are being used to refine drilling locations for the upcoming stratigraphic wells. The next well of this planned continuous drilling program was scheduled to have the rig on location by the end of last month. Pantheon Resources Alaska Discovery Deemed “World Class” Pantheon Resources has uncovered a “world-class” oil discovery on its Theta West acreage in Alaska, according to independent consultants brought in to assess the area’s potential. Baker Hughes Advanced Hydrocarbon Stratigraphy (AHS) was charged with compiling a report based on data collated after a successful appraisal well drilled early this year. The firm believes there is a continuous column of oil-bearing cuttings of at least 1,360 ft that is host to a light crude in the order of 37–39 °API. The AHS report concluded there are “abundant good-quality reservoirs” with an “ultimate, nonpermeable seal” at 7,070 ft. Pantheon said the results are supportive of analyses of cuttings from previous work on the acreage on Alaska’s prolific North Slope. The company estimated the project, which is close to infrastructure, is host to 17 billion bbl of which 10%, or 1.7 billion bbl, is deemed recoverable. Invictus Well in Zimbabwe a “Game Changer” The Mukuyu-1 exploration well being drilled in Zimbabwe by Australian firm Invictus Energy in partnership with the government is being called “a game changer” for the country by President Emmerson Mnangagwa. The well is in license SG 4571, which covers 250,000 acres located in the most prospective portion of the Cabora Bassa Basin in northern Zimbabwe. The license is currently in the second exploration period which runs to June 2024. Invictus entered into an agreement with the Zimbabwe government in March 2022 to increase the license area sevenfold to 1.77 million acres. Previously explored by Mobil Oil, the project contains the largest undrilled structure in onshore Africa. The Muzarabani anticline feature has more than 200 km2 under closure and up to 1500 m vertical relief at favorable depths for conventional oil and gas. Invictus completed the acquisition of 840 km of high-resolution infill 2D seismic data ahead of spudding the well using Exalo Rig 202 in August. Drilling Results a Mixed Bag for APA Offshore Suriname APA Corporation has made an oil discovery offshore Suriname with its Baja-1 well in Block 53 but came away empty with a probe in Block 58. Baja-1 was drilled to a depth of 5290 m and encountered 34 m of net oil pay in a single interval within the Campanian. Preliminary fluid and log analysis indicates light oil with a gas/oil ratio (GOR) of 1,600 to 2,200 scf/bbl, in good-quality reservoir. The discovery at Baja-1 is a down-dip lobe of the same depositional system as the Krabdagu discovery, 11.5 km to the west in Block 58. Evaluation of openhole well logs, cores, and reservoir fluids is ongoing. The success at Baja marks the sixth oil discovery in which APA has participated in offshore Suriname and the first on Block 53. The company said the result confirms its geologic model for the Campanian in the area and helps to de-risk other prospects in the southern portion of both Blocks 53 and 58. APA recently received regulatory approval regarding an amendment to the Block 53 production-sharing contract, which provides options to extend the exploration period by up to 4 years. The company is currently proceeding with formalizing the first one-year extension, for which all work commitments are complete. APA is operator and holds a 45% working interest in Block 53; partners Petronas and CEPSA hold 30% and 25% stakes, respectively. Baja-1 was drilled using drillship Noble Gerry de Souza in water depths of approximately 1140 m. The rig will mobilize to Block 58 following the completion of current operations, where it will drill the Awari exploration prospect, approximately 27 km north of the Maka Central discovery. APA was not as fortunate with its Dikkop exploration well in Block 58. The well encountered water-bearing sandstones in the targeted interval and has been plugged and abandoned. Operator TotalEnergies holds a 50% working interest, while APA holds the remaining 50% stake. The drillship Maersk Valiant will be moving to the Sapakara field to drill a second appraisal well at Sapakara South, where the joint venture conducted a successful flow test late last year. Helix Energy Solutions Secures Production, P&A Work With Thunder Hawk Buy Helix Energy Solutions Group subsidiary Deepwater Abandonment Alternatives (DAA) acquired all of MP GOM’s 62.5% interest in Mississippi Canyon Block 734, comprising three wells and related subsea infrastructure, collectively known as the Thunder Hawk field. MP GOM is a subsidiary of Murphy Oil. Financial terms of the deal were not disclosed. “This acquisition furthers Helix’s energy transition business model by taking on decommissioning obligations in exchange for production revenues,” said Owen Kratz, president and chief executive of Helix. “We have long communicated our unique position as a qualified offshore field operator that can also assume and efficiently discharge decommissioning obligations. We continue to pursue opportunities that enable us to enhance and extend the life of existing reserves and safely perform the related decommissioning of the infrastructure in transactions that allow producers to remove noncore assets from their balance sheets.” Under the terms of the transaction, Helix receives the benefit of ownership of MP GOM’s interest, with a 1 November 2021 effective date purchase price adjustment resulting in nominal cash paid by MP GOM at closing, in exchange for the assumption of MP GOM’s abandonment obligations at the Thunder Hawk Field. In addition to anticipated future production revenue, DAA will operate the Thunder Hawk field with Helix eventually expected to perform the required plug and abandonment operations. Kolibri Continues Tishamingo Program in Oklahoma Kolibri Global Energy has completed the location work for the Glenn 16-3H and Brock 9-3H wells, which are the third and fourth wells in its 2022 drilling program. A fifth location is also being prepped. All three wells in the Tishamingo area of the SCOOP play are planned to be drilled back-to-back, and the completion operations for the Glenn 16-3H and Brock 9-3H wells have been tentatively scheduled for the first week of October. Neptune Energy Confirms New Discovery in the Gjøa Area Neptune Energy and its partners announced a new commercial discovery at the Ofelia exploration well (PL 929), close to the Gjøa field in the Norwegian sector of the North Sea. Neptune has completed drilling of the Ofelia well, 35/6-3 S, and encountered oil in the Agat formation. The preliminary estimate of recoverable volume is in the range of 16 to 39 million BOE. In addition to the Agat volumes, north of the well there is an upside of around 10 million BOE recoverable gas in the shallower Kyrre formation, which brings the total recoverable volume to approximately 26 to 49 million BOE. Located 15 km north of the operated Gjøa platform, at a water depth of 344 m, Ofelia will be considered for development as a tieback to Gjøa, in parallel with the company’s recent oil and gas discovery at Hamlet. The Ofelia well, drilled by Odfjell-operated semisubmersible Deepsea Yantai, confirmed an oil/water contact at 2639 m total vertical depth. It is the third discovery by Neptune Energy in the Agat formation, a reservoir which until recently was not part of established exploration models on the Norwegian Shelf. The first was at the Duva field, which is now onstream and being operated by Neptune. The second was the company’s discovery at Hamlet, with estimated recoverable volumes between 8 and 24 million BOE.

O objetivo principal desta pesquisa foi avaliar a capacidade de absorção do conhecimento organizacional, tendo como uma das suas dimensões a comunicação com o ambiente externo. Foi desenvolvida uma pesquisa de caráter quantitativo com cem empresas pertencentes aos setores de comércio e de serviços, localizadas na cidade de Palmas, TO. O questionário aplicado envolveu a utilização de uma escala da capacidade de absorção do conhecimento, desenvolvida por Matusik e Heeley (2005). Os autores avaliam que a capacidade de absorção é composta de múltiplas dimensões: 1) relação da empresa com seu ambiente externo, 2) a estrutura, as rotinas de conhecimentos, e o grupo principal de criação de valor e, 3) absorção de habilidades individuais. Os resultados demonstraram que as empresas pesquisadas possuíam alto grau de predominância de relacionamento com o ambiente.Palavras-chave: Capacidade de Absorção do Conhecimento; Conhecimento; Comunicação com o ambiente externo. ABSTRACTThe main objective of this research was to evaluate the absorption capacity of organizational knowledge, having as one of its dimensions communication with the external environment. One quantitative study with a hundred companies belonging to the trade and service sectors has been developed, located in the city of Palmas, TO. The questionnaire involved the use of a range of absorption capacity of the knowledge developed by Matusik and Heeley (2005). The authors estimate that the absorption capacity is made up of multiple dimensions: 1) the company's relationship with its external environment, 2) the structure, routines of knowledge, and the main group of value creation and, 3) absorption of individual skills . The results showed that the surveyed enterprises had a high degree of dominance relationship with the environment.Keywords: Absorption Capacity of Knowledge; Knowledge; Communication with the external environment. RESUMENEl principal objetivo de esta investigación fue evaluar la capacidad de absorción de conocimiento organizacional, teniendo como una de sus dimensiones de comunicación con el ambiente externo. Un estudio cuantitativo con un centenar de empresas pertenecientes a los sectores de comercio y servicios se ha desarrollado, que se encuentra en la ciudad de Palmas, TO. El cuestionario implicó el uso de una gama de capacidad de absorción del conocimiento desarrollado por Matusik y Heeley (2005). Los autores estiman que la capacidad de absorción se compone de múltiples dimensiones: 1) la relación de la empresa con su entorno externo, 2) la estructura, las rutinas de conocimiento, y el grupo principal de la creación de valor y, 3) la absorción de las capacidades individuales . Los resultados mostraron que las empresas encuestadas tenían un alto grado de relación de dominación con el medio ambiente.Palabras clave: Capacidad de absorción de conocimiento; el conocimiento; la comunicación con el ambiente externo. REFERÊNCIASCOHEN,W. M., LEVINTHAL, D. A. Absorptive capacity: A new perspective on learning and innovation. Administrative Science Quarterly, v. 35: 128-152, 1990.CRADWELL, D. The Norton history of technology. London: Norton.1995.FELDMAN, M. S.; PENTLAND, B., T. Reconceptualizing organizational routines as a source of flexibility and change. Administrative Science quarterly, v. 48, n. 1, 94-118, 2003.FLATTEN, T.; BRETTEL, M.; ENGELEN, A.; GREVE G. A measure of absorptive capacity: Development and validation. Academy of Management Proceedings Volume: 2009, Publisher: Academy of Management, Pages: 1-7, 2009.GOES, J. B.; PARK, S. H. Interorganizational links and innovation: The case of hospital services. 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Penelitian ini menjelaskan pada pemerolehan bahasa anak usia 2 tahun – 2 tahun 3 bulan dari segi fonologi. Di pembahasan fonologi yang terdiri dari pemerolehan vokal dan pemerolehan konsonan. Penelitian ini dilakukan pada bulan Oktober-Desember 2019. Penelitian ini menggunakan metode kualitatif memakai pendekatan studi kasus. Sumber data penelitian ini adalah seorang anak laki-laki yang berinisial MADA saat berusia 2 – 2 tahun 3 bulan. Data yang didapat disimpan melalui rekaman. Selain melalui proses rekaman, data juga dicatat. Dalam artikel ini dapat ditemukan bahwa pemerolehan fonem [a], [i], [u], [e], [ә], dan [o] MADA sudah dikuasai. Fonem yang pertama MADA kuasai ialah [a], dan [u], sedangkan untuk diftong asli belum dapat dilafalkan. Selain itu, konsonan [p], [m], [b], [y], [s], [n], [k], [d], [c], [t], [ɲ], [w], [j], [g], [ŋ], dan [h] sudah mulai dikuasai meskipun masih mengalami kesulitan dalam pengucapan. Fonem yang belum sempurna dikuasai MADA adalah [r].

ABSTRAK Penelitian ini bertujuan untuk mengetahui pengaruh kinerja manajemen, efisiensi, kinerja underwriting dan likuiditas terhadap profitabilitas perusahaan asuransi syariah di Indonesia periode 2015-2019 secara parsial dan simultan. Penelitian ini menggunakan metode kuantitatif dengan teknik analisis regresi data panel dan mengambil 24 sampel perusahaan asuransi jiwa maupun umum syariah di Indonesia, sumber data diambil dari laporan keuangan masing-masing perusahaan asuransi syariah dan laporan statistik keuangan OJK. secara parsial kinerja manajemen dan kinerja underwriting berpengaruh positif signifikan terhadap profitabilitas, efisiensi dan likuiditas berpengaruh negatif signifikan terhadap profitabilitas. secara simultan variabel kinerja manajemen, efisiensi, kinerja underwriting dan likuiditas yang diukur melalui rasio perubahan surplus, rasio underwriting, rasio biaya manajemen dan rasio likuiditas berpengaruh signifikan terhadap profitabilitas yang diukur dengan ROE pada perusahaan asuransi syariah di Indonesia periode 2015-2019. Perusahaan asuransi syariah diharapkan dapat mengoptimalkan struktur modal perusahaannya, lalu menjaga kondisi keuangan perusahaan dengan baik terutama dari sisi kewajiban dan biaya operasional perusahaan asuransi syariah. Perusahaan juga diharapkan mampu mengelola dana pesertanya dengan baik agar tidak mengalami defisit underwriting. Kata kunci: Kinerja Manajemen, Efisiensi, Kinerja Underwriting, Likuiditas, Profitabilitas. ABSTRACT This study aims to determine the effect of management performance, efficiency, underwriting performance and liquidity on the profitability of Islamic insurance companies in Indonesia for the 2015-2019 period partially and simultaneously. This study uses a quantitative method with panel data regression analysis techniques and takes 24 samples of sharia life and general insurance companies in Indonesia, the data sources are taken from the financial statements of each sharia insurance company and OJK financial statistics reports. partially management performance and underwriting performance have a significant positive effect on profitability, efficiency and liquidity have a significant negative effect on profitability. Simultaneously, the variables of management performance, efficiency, underwriting performance and liquidity as measured by the ratio of changes in surplus, underwriting ratio, management expense ratio and liquidity ratio have a significant effect on profitability as measured by ROE in Islamic insurance companies in Indonesia for the 2015-2019 period. Islamic insurance companies are expected to optimize the company's capital structure, then maintain the company's financial condition well, especially in terms of obligations and operational costs of sharia insurance companies. The company is also expected to be able to manage the funds of its participants well so as not to experience an underwriting deficit. Keywords: Management Performance, Efficiency, Underwriting Performance, Liquidity, Profitability. DAFTAR PUSTAKA Akotey G., J. O., & Manso, S. L. (2013). The financial performance of life insurance companies in Ghana. Journal of Risk Finance, 14(3), 286-302. https://doi.org/10.1108/JRF-11-2012-0081 Anshori, M., & Iswati, S. (2009). Metodologi penelitian kuantitatif. Surabaya: Universitas Airlangga. Azhari, R. A. (2021). Studi analisis meta pada determinan profitabilitas perusahaan asuransi syariah di Indonesia. Skripsi tidak dipublikasikan. Surabaya: Universitas Airlangga. Bakri, W. (2015). Prinsip-prinsip dasar asuransi syariah. 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Jurnal Akuntansi dan Keuangan Indonesia, 9(1), 43-55. http://dx.doi.org/10.21002/jaki.2012.03 Ramadhan, Y. (2019). Pengaruh ujrah diterima, beban klaim dan total investasi terhadap laba asuransi jiwa syariah di Indonesia periode 2008-2017. Skripsi tidak dipublikasikan. Surabaya: Universitas Airlangga. Safitri, K. E., & Suprayogi, N. (2017). Analisis kesehatan keuangan dana tabarru yang mempengaruhi profitabilitas pada asuransi syariah di Indonesia. Jurnal Ekonomi Syariah Teori dan Terapan, 4(1), 73-88. https://doi.org/10.20473/vol4iss20171pp73-88 Salsabila, F. H. (2020). Pengaruh rasio-rasio early warning system terhadap profitabilitas perusahaan asuransi jiwa syariah periode 2014-2018. Skripsi tidak dipublikasikan. Surabaya: Universitas Airlangga. Satria, S. (1994). Pengukuran kinerja keuangan perusahaan asuransi kerugian di Indonesia dengan analisis rasio keuangan early warning system. Jakarta : Lembaga penerbit FE-UI. Silalahi, D., Sitepu, R., & Tarigan, G. (2014). 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Skripsi tidak dipublikasikan. Lampung: Universitas Islam Negeri Raden Intan Lampung.

This paper studies how the nature and shape of the relationship between inter- national diversification (ID) and performance (P) may vary according to a firm’s geographical focus of internationalization. Using a sample of Spanish multinational firms for the 2004—2012 period we find an M-shaped relationship. However, significant differences are found when the different geographical foci of internationalization are considered. Strong support is found when firms adopt a regional focus (an inverted S-curve when the ID measure refers to the number of foreign countries and an M-curve when it refers to the size of the network of foreign sub- sidiaries), a biregional focus (an S-curve) and a semiglobal focus (an inverted S-curve but also an M-curve with foreign subsidiaries). These findings and their pattern suggest the critical impor- tance of the country of origin and the geographical focus of internationalization in explaining the relationship between ID—P. JEL CLASSIFICATION C33; F23; G15; L25

- Dennis Tedlock, Dennis Tedlock, The Spoken Word - Reaction to R. de Ridder’s review of The Spoken Word and Popul Vuh (BKI 142-I, 1986, pp. 179-182). - J.G. de Casparis, Kenneth R. Hall, Maritime trade and state development in early Southeast Asia, Honolulu: University of Hawaii Press, 1985, 368 pp. - M. Hekker, J.E. Ellemers, Indische Nederlanders en gerepatrieerden, Muiderberg: Coutinho, 1985. 159 pp., foto’s., R.E.F. Vaillant (eds.) - Tineke Hellwig, Els Postel-Coster, Het omheinde kweekbed; Machtsverhoudingen in de Minangkabause familieroman, Delft: Eburon, 233 pp., 1985. - H.A.J. Klooster, Sartono Kartodirdjo, Modern Indonesia, tradition and transformation. A socio-historical perspective, Yogyakarta: Gadjah Mada University Press, 1984, xii + 299 pp. - Gert J. Oostindie, W.S.M. Hoogbergen, De Boni-oorlogen 1757-1860. Marronage en guerilla [sic] in Oost-Suriname. Utrecht: Rijksuniversiteit 1985. [Bronnen voor de studie van Afro-amerikaanse samenlevingen in de Guyana’s, 528 pp. - P. Pink, V. M. Clara van Groenendael, The Dalang behind the Wayang. The role of the Surakarta and the Yogyakarta dalang in Indonesian-Javanese society, Verhandelingen van het Koninklijk Instituut voor Taal-, Land- en Volkenkunde 114, Dordrecht-Holland/Cinnaminson-U.S.A.: Foris publications, 1985, VIII + 242 pp., 3 maps. - P. Pink, J. Kats, De Wajang Poerwa, een vorm van Javaans Toneel, ingeleid door J.J. Ras en H.A. Poeze, Koninklijk Instituut voor Taal-, Land- en Volkenkunde, Indonesische Herdrukken, Dordrecht-Holland/Cinnaminson-U.S.A.: Foris publications, 1984, XL VIII + VIII + 446 pp. - S. Pompe, Hisako Nakamura, Divorce in Java, Gadjah Mada University Press, Yogyakarta 1983, xxiii + 145 pp. - J.M.C. Pragt, Wim Bakker, Bali verbeeld, Volkenkundig Museum Nusantara, Delft, 1985, 96 p., 120 afb.

The authors study the Fama and French three-factor (FF-3F) model in relation to a developing market. To this end, they consider Chinese stock markets over the period 1995–2008, which is to say, over a period when these markets are recognized as “developing” markets influenced by speculative activity. The authors find that the model appears to be working as a form of “principal component analysis for the determinants of stock price formation with book-to-market (B/M) as the “variable of choice” on account of that it captures the earnings-to-price (E/P), cash-flow-to-price (C/P) and sales-to-price (S/P) variables while remaining largely uncorrelated with firm size (whereas E/P, C/P and S/P are themselves positively correlated with firm size). The variables, however, are unrelated to risk as represented by market exposure, volatility, or leverage.

Abstract
 In the process of maximizing the value of the company, a conflict of interest between the manager and the shareholders often arises, which is often called an agency problem. This happens because managers prioritize the opposite interests, ownership does not like the personal interests of managers because what managers do will add costs to the company so that it will cause a decrease in corporate profits. Therefore, companies need a corporate monitoring function through external auditors that are used by company managers to reduce agency problems that arise in the company and reduce fraud in the presentation of the company's financial statements. Therefore, this study discusses the factors that can influence the decisions of public accounting firms such as institutional share ownership, managerial stock ownership, largest shareholding, company size, independent commissioners and leverage. The sample in this study consisted of 135 manufacturing companies. Sampling was done by purposive sampling method. The analytical method used is logistic regression analysis using SPSS 20. The conclusion from the results of the analysis in this study is that the largest shareholding has a positive interest in the selection of a public accounting firm. 
 Keywords: Selection of Public Accounting Firm, Independent Commissioner, Institutional Ownership, Managerial Ownership, Largest Share Ownership, Company Size, Leverage.
 
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