Smoothie King teams up with Heinz for new ketchup smoothie. Where to get a cup
The Heinz tomato ketchup smoothie arrived Wednesday, Aug. 6, at select Smoothie King locations nationwide, the Texas-based smoothie brand said in a news release.
It teamed up with Kraft Heinz for the 'first-ever ketchup-based smoothie,' made with real Heinz Simply Tomato ketchup. For $5.70, the 20-ounce drink combines Acai sorbet, apple juice, strawberries and raspberries with the 'bright, tangy' finish of Heinz ketchup.
Customers can grab a cup at Smoothie King locations across Atlanta, Chicago, Denver, Miami-Ft. Lauderdale and New York, while supplies last.
Together, the brands sought to settle the age-old debate, 'Is tomato a fruit or a vegetable?' Though often used in savory dishes from salads to stews, tomatoes are classified as a fruit, according to NatureSweet.com.
More specifically, the vibrant red orbs are berries because 'they are fleshy fruits without pits that develop from a single flower with only one ovary,' according to the produce company's website.
Now, Smoothie King is turning to ketchup for a spin on its traditional fruit smoothies.
'The idea of a ketchup smoothie is provocative, and our top priority was landing a delicious tasting fruit smoothie with distinct yet well-balanced ketchup notes,' Angie Madigan, vice president of elevation marketing at Kraft Heinz, said in the release.
'The experts at Smoothie King helped make this dream a reality, and we're absolutely thrilled with the final smoothie we created together.'
Find your nearest participating Smoothie King here.
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Yahoo
22 minutes ago
- Yahoo
PetroTal Announces Q2 2025 Financial and Operating Results
Calgary, Alberta and Houston, Texas--(Newsfile Corp. - August 7, 2025) - PetroTal Corp. (TSX: TAL) (AIM: PTAL) (OTCQX: PTALF) ("PetroTal" or the "Company") is pleased to report its operating and financial results for the three months ended June 30, 2025. All amounts herein are in United States dollars unless stated otherwise. Selected financial and operational information outlined above should be read in conjunction with the Company's unaudited consolidated financial statements and management's discussion and analysis ("MD&A") for the three months ended June 30, 2025, which are available on SEDAR+ at and on the Company's website at Key Highlights Average Q2 2025 sales and production of 20,578 and 21,039 barrels of oil per day ("bopd"), respectively; Generated Adjusted EBITDA(1) and Free Funds Flow(1) of $44.3 million ($23.66/bbl) and $27.2 million ($14.55/bbl), respectively; Q2 2025 capital expenditures of $17.1 million, bringing H1 2025 capital expenditures to $40.7 million; Net Income of $17.5 million ($9.35/bbl) in Q2 2025, and $48.4 million ($11.46/bbl) in H1 2025; Total cash of $142.1 million, including $99.3 million of unrestricted cash; Declaring a quarterly dividend of $0.015/sh, payable to shareholders on September 12, 2025, and; Revision of 2025 production guidance to a range of 20,000 to 21,000 bopd, on capital spending of $80 million. (1) Non-GAAP (defined below) measure that does not have any standardized meaning prescribed by GAAP and therefore may not be comparable with the calculation of similar measures presented by other entities. See "Selected Financial Measures" section. Manuel Pablo Zuniga-Pflucker, President and Chief Executive Officer, commented: "PetroTal has once again delivered strong results in the second quarter of 2025, reflecting our ongoing commitment to profitable long-term growth. Even under lower oil prices this quarter, PetroTal is reporting free cash flow of more than $27 million, while holding our available cash reserves broadly flat near $100 million. The Bretana field is also performing as expected, with recent production topping 20,000 bopd. As discussed in our July 14 operations update, we have encountered delays in the resumption of our development drilling program. As a result, we are revising our 2025 production guidance to a range of 20,000 to 21,000 bopd, from 21,000-23,000 bopd previously. At the Bretana field, we are taking advantage of the gap in our drilling campaign to fully optimize our long-term plans for the asset, an exercise which takes on heightened importance given recent weakness in oil pricing. As indicated in the 2024 year-end reserves report, the field still has sixteen proved and probable locations remaining, and that is before we have even begun development of the VS1 sand in the Upper Vivian Formation. PetroTal is committed to developing the field in a responsible manner for all our stakeholders, at a variety of oil price assumptions. We have plenty of work ahead of us in the second half of 2025 and look forward to updating the market on our progress." Selected Financial HighlightsThree Months EndedQ2-2025 Q1-2025 Q2-2024$/bbl $(000's) $/bbl $(000's) $/bbl $(000's) Average Production (bopd)21,03923,28118,290 Average Sales (bopd)20,57823,28618,050 Total Sales (bbls)1,872,6022,095,7141,642,578 Average Brent Price $65.55$73.96$83.87Contracted Sales Price, Gross $65.53$73.89$83.92Tariffs, Fees and Differentials -$22.75-$21.43-$21.15Realized Sales Price, Net $42.78$52.46$62.76Oil Revenue $42.78 $80,110 $52.46 $109,951 $62.76 $103,086 Royalties $4.95 $9,276 $5.84 $12,241 $6.08 $9,991 Operating Expenses $9.34 $17,488 $6.31 $13,227 $6.10 $10,023 Direct Transportation Diluent $0.00 $0 $0.00 $0 $1.16 $1,898 Barging $0.79 $1,482 $0.79 $1,664 $0.69 $1,137 Diesel $0.00 $0 $0.00 $0 $0.00 $0 Storage $0.30 $570 $0.30 $636 $0.01 $12 Total Transportation $1.09 $2,052 $1.09 $2,300 $1.86 $3,047 Net Operating Income $27.40 $51,294 $39.22 $82,183 $48.72 $80,025 Erosion Control $0.38 $705 $0.87 $1,816 $0.00 $0 G&A $4.15 $7,775 $4.57 $9,579 $6.41 $10,528 EBITDA $22.86 $42,815 $18.78 $39,355 $43.55 $71,539 Adjusted EBITDA $23.66 $44,310 $34.29 $71,860 $45.78 $75,201 Net Income $9.35 $17,513 $14.72 $30,852 $21.56 $35,407 Basic Shares Outstanding ('000)913,808915,930914,196 Market Capitalization$456,904$435,754$504,152 Net Income/Share ($/sh)$0.02$0.03$0.04 Capex$17,064$23,624$38,867 Free Funds Flow $14.55 $27,246 $23.02 $48,042 $22.12 $36,334 Total Cash$142,102$113,565$95,859 Available Cash$99,313$102,783$84,116 Approximately 90% of Q2 2025 sales were through the Brazilian route vs 88% in Q1 2025. Royalties include the impact of the 2.5% community social trust. Non-GAAP (defined below) measure that does not have any standardized meaning prescribed by GAAP and therefore may not be comparable with the calculation of similar measures presented by other entities. See "Selected Financial Measures" section. Net operating income represents revenues less royalties, operating expenses, and direct transportation. Adjusted EBITDA is net operating income less general and administrative ("G&A") and plus/minus realized derivative impacts. Market capitalization for Q2 2025, Q1 2025 and Q2 2024 assume share prices of $0.50, $0.475, and $0.53 respectively on the last trading day of the quarter. Free funds flow is defined as adjusted EBITDA less capital expenditures. See "Selected Financial Measures" section. Includes restricted cash balances. Additional financial and operational updates during and subsequent to the quarter ending June 30, 2025: Block 95 Update PetroTal produced an average of 20,512 bopd from the Bretana field in Q2 2025. Bretana production declined by approximately 2,150 bopd relative to the prior quarter, due to a combination of natural declines and previously disclosed pump failures in four producing wells in Q4 2024 and Q1 2025. PetroTal successfully replaced all four pumps ahead of schedule by the end of July 2025, restoring approximately 4,400 bopd of production capacity. As a result, field production averaged approximately 20,000 bopd in the month of July, compared to 18,899 bopd in June. Barge exports have continued near 100% capacity throughout the month of July; in the event that river levels remain above normal through the coming dry season, PetroTal would not expect to encounter any material reduction in export capacity. During the second quarter, PetroTal completed the installation of the CPF-4 processing facility, increasing nominal oil treatment capacity at Bretana to 26,000 bopd, which has been established as a more optimum design for the Company's current output than the previously mentioned 32,000 bopd. Oil production remains constrained by water treatment capacity, which currently stands at just over 170,000 barrels of water per day("bwpd"). The remaining 2025 Bretana capital program is largely allocated to field infrastructure, including completion of the L2 platform, which will be required to accommodate additional development wells beginning in 2026. Due to a combination of factors, including sustained lower oil prices, regulatory considerations, and delays commissioning its drilling rig, PetroTal has taken the decision to pause investment on several projects at Bretana in order to rigorously evaluate and optimize its long-term development plan for the asset. The Company intends to provide a revised field development plan, incorporating holistic forecasts for fluid handling capacity, integrated development of the VS1 and VS2 sands, and export transportation, in time for its year-end 2025 reserve report, which is typically published in February each year. Block 131 Update Los Angeles field production averaged 526 bopd in Q2 2025, down approximately 90 bopd compared to the prior quarter. PetroTal performed a cased-hole well logging program at the Los Angeles field in the second quarter, which necessitated the shut-in of targeted wells for brief periods. The Company is currently mobilizing the service rig which recently completed the pump replacements at Bretana to the Los Angeles field, where it will carry out a planned workover program on at least three wells. The workover program, which is scheduled to run into September 2025, is expected to increase field production by a total of approximately 500-1,500 bopd (on a peak monthly average basis). PetroTal is evaluating options to secure a drilling rig to initiate the Block 131 development program, pending technical review of the workover program. Bretana Erosion Control Project PetroTal expensed $0.7 million of erosion control costs in Q2 2025, down from $1.8 million in the prior quarter. As disclosed previously, the Ucayali River at the inland port of Pucallpa was unseasonably high throughout the local wet season. The staging yard at Pucallpa, where PetroTal's contractor has been preparing equipment for the erosion control project, was flooded for approximately six weeks in March - April 2025. River levels have since declined, allowing the construction consortium to resume activity, and a number of project milestones were completed by the end of July. The main piling barge, along with the first batch of fabricated steel components, recently arrived at Bretana and is expected to commence the test piles for the first breakwater within the next two weeks. In-line with previous disclosures, PetroTal estimates the project is approximately one month behind schedule, with a targeted completion date of Q3 2026. There are no material changes to cost estimates for the project at this time. Cash and Liquidity Update PetroTal ended Q2 2025 with a total cash position of $142 million, of which $99 million was unrestricted. The increase in total cash primarily reflects the first tranche of the previously announced COFIDE loan, which was drawn on May 20, 2025. Of the $42.8 million that PetroTal carried as Restricted Cash on June 30, approximately $31.9 million was related to the escrow account of the COFIDE loan. Available cash as of June 30, 2025 amounted to $99.3 million, compared to $84.1 million at the same time last year. As previously announced, PetroTal has entered into hedge agreements for the sale of its crude oil, during periods when Brent oil pricing topped $80.00/bbl. These hedges consist of costless collars with a Brent floor price of $65.00/bbl and a ceiling of $82.50/bbl, with a cap of $102.50/bbl. As of the end of Q2 2025, the hedges covered approximately 44% of PetroTal's remaining estimated sales volumes through the end of 2025. PetroTal recorded a $5.6 million gain on these hedges as of June 30. 2025 Guidance Update Accounting for several factors discussed above, most notably lower than forecast oil prices and delays in the resumption of its development drilling program, PetroTal is updating market guidance for key 2025 financial and operational metrics. The Company now expects group production to average 20,000-21,000 bopd in 2025, down from the range of 21,000-23,000 bopd that was originally communicated on January 16, 2025. Annual adjusted EBITDA guidance, which was previously based on the assumption that Brent oil prices would average $75.00/bbl in 2025, is being reduced to a range of $170 - 185 million, from $240 - 250 million previously. Updated adjusted EBITDA guidance is based on H1 2025 actual adjusted EBITDA of $116 million, plus estimated H2 2025 adjusted EBITDA at Brent oil prices of $65.00 - 70.00/bbl. PetroTal attributes the majority of the reduction (approximately $50-55 million) in forecast adjusted EBITDA to lower oil price realizations, with the balance due to lower forecast sales volumes, partially offset by cost savings. Note that adjusted EBITDA guidance is net of approximately $30 million in expenses associated with the erosion control project, which are expected to be non-recurring. PetroTal is also reducing guidance for 2025 capital expenditures to $80 million, from $140 million previously. The reduction is primarily due to delays in resuming the development drilling program at Block 131, and to a lesser extent the deferral or cancellation of several non-essential projects due to recent weakness in oil pricing. Original guidance provided in January assumed approximately $35-40 million of capital spending at Block 131; however, the updated budget largely reflects a maintenance capital program at Blocks 95 and 131. Pending technical interpretation of the results of the workover program, and should a drilling rig arrive at the Los Angeles field before year end 2025, the Company may deploy additional capital at Block 131. Importantly, PetroTal would like to re-emphasize its commitment to a robust capital returns policy. To the extent that oil prices and its funding obligations allow, the Company will continue to prioritize a stable dividend for its shareholders. Q2 2025 Dividend Declaration PetroTal's Board of Directors has declared a quarterly cash dividend of USD$0.015 per common share, payable according to the following timeframe: Record date: 29 August 2025 Ex-Dividend date: 29 August 2025 Payment date: 12 September 2025 This dividend is with respect to Q2 2025 results and includes the recurring USD$0.015 per common share amount but no liquidity sweep this quarter due to anticipated heavier cash requirements over the next two quarters. The dividend is an eligible dividend for the purposes of the Income Tax Act (Canada) and investors should note that the excess liquidity sweep portion of all future dividends may be subject to fluctuations up or down in accordance with the Company's return of capital policy. Shareholders outside of Canada should contact their respective brokers or registrar agents for the appropriate tax election forms regarding this dividend. Corporate Presentation Update The Company has updated its Corporate Presentation, which is available for download or viewing at Q2 2025 Webcast Link for August 7, 2025 PetroTal's management team will host a webcast to discuss Q2 2025 results on August 7, 2025 at 9am CT (Houston) and 3pm BST (London). Please see the link below to register. ABOUT PETROTAL PetroTal is a publicly traded, tri‐quoted (TSX: TAL) (AIM: PTAL) and (OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in the Bretaña Norte oil field in Peru's Block 95, where oil production was initiated in June 2018. In early 2022, PetroTal became the largest crude oil producer in Peru. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretaña oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders. For further information, please see the Company's website at the Company's filed documents at or below: Camilo McAllisterExecutive Vice President and Chief Financial OfficerCmcallister@ (713) 253-4997 Manolo ZunigaPresident and Chief Executive OfficerMzuniga@ (713) 609-9101 PetroTal Investor RelationsInvestorRelations@ Celicourt CommunicationsMark Antelme / Jimmy Leapetrotal@ T : +44 (0) 20 7770 6424 Strand Hanson Limited (Nominated & Financial Adviser)Ritchie Balmer / James Spinney / Robert CollinsT: +44 (0) 207 409 3494 Stifel Nicolaus Europe Limited (Joint Broker)Callum Stewart / Simon Mensley / Ashton ClanfieldT: +44 (0) 20 7710 7600 Peel Hunt LLP (Joint Broker) Richard Crichton / David McKeown / Georgia Langoulant T: +44 (0) 20 7418 8900 READER ADVISORIES FORWARD-LOOKING STATEMENTS: This press release contains certain statements that may be deemed to be forward-looking statements. Such statements relate to possible future events, including, but not limited to: oil production levels and production capacity; PetroTal's 2025 development program for drilling, completions and other activities, including Block 131 and CPF-4 at Bretana; plans and expectations with respect to the erosion control project; and PetroTal's expectations with respect to dividends and share buybacks. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "estimate", "potential", "will", "should", "continue", "may", "objective", "intend" and similar expressions. The forward-looking statements provided in this press release are based on management's current belief, based on currently available information, as to the outcome and timing of future events. The forward-looking statements are based on certain key expectations and assumptions made by the Company, including, but not limited to, expectations and assumptions concerning the ability of existing infrastructure to deliver production and the anticipated capital expenditures associated therewith, the ability to obtain and maintain necessary permits and licenses, the ability of government groups to effectively achieve objectives in respect of reducing social conflict and collaborating towards continued investment in the energy sector, reservoir characteristics, recovery factor, exploration upside, prevailing commodity prices and the actual prices received for PetroTal's products, including pursuant to hedging arrangements, the availability and performance of drilling rigs, facilities, pipelines, other oilfield services and skilled labour, royalty regimes and exchange rates, the impact of inflation on costs, the application of regulatory and licensing requirements, the accuracy of PetroTal's geological interpretation of its drilling and land opportunities, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of new wells, future river water levels, the Company's growth strategy, general economic conditions and availability of required equipment and services. PetroTal cautions that forward-looking statements relating to PetroTal are subject to all of the risks, uncertainties and other factors, which may cause the actual results, performance, capital expenditures or achievements of the Company to differ materially from anticipated future results, performance, capital expenditures or achievement expressed or implied by such forward-looking statements. Factors that could cause actual results to differ materially from those set forth in the forward-looking statements include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; and health, safety and environmental risks), business performance, legal and legislative developments including changes in tax laws and legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures, credit ratings and risks, fluctuations in interest rates and currency values, changes in the financial landscape both domestically and abroad, including volatility in the stock market and financial system, wars (including Russia's war in Ukraine and the Israeli-Hamas conflict), regulatory developments, commodity price volatility, price differentials and the actual prices received for products, exchange rate fluctuations, legal, political and economic instability in Peru, access to transportation routes and markets for the Company's production, changes in legislation affecting the oil and gas industry, changes in the financial landscape both domestically and abroad (including volatility in the stock market and financial system) and the occurrence of weather-related and other natural catastrophes. Readers are cautioned that the foregoing list of factors is not exhaustive. Please refer to the annual information form for the year ended December 31, 2023 and the management's discussion and analysis for the three months ended March 31, 2024 for additional risk factors relating to PetroTal, which can be accessed either on PetroTal's website at or under the Company's profile on The forward-looking statements contained in this press release are made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws. OIL REFERENCES: All references to "oil" or "crude oil" production, revenue or sales in this press release mean "heavy crude oil" as defined in National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). SHORT TERM RESULTS: References in this press release to peak rates, initial production rates, current production rates, 30-day production rates and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long-term performance or of ultimate recovery. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of PetroTal. The Company cautions that such results should be considered to be preliminary. FOFI DISCLOSURE: This press release contains future-oriented financial information and financial outlook information (collectively, "FOFI") about PetroTal's prospective results of operations and production results, 2024 drilling program and budget, well investment payback, cash position, liquidity and components thereof, all of which are subject to the same assumptions, risk factors, limitations and qualifications as set forth in the above paragraphs. FOFI contained in this press release was approved by management as of the date of this press release and was included for the purpose of providing further information about PetroTal's anticipated future business operations. PetroTal and its management believe that FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments, and represent, to the best of management's knowledge and opinion, the Company's expected course of action. However, because this information is highly subjective, it should not be relied on as necessarily indicative of future results. PetroTal disclaims any intention or obligation to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Readers are cautioned that the FOFI contained in this press release should not be used for purposes other than for which it is disclosed herein. All FOFI contained in this press release complies with the requirements of Canadian securities legislation, including NI 51-101. Changes in forecast commodity prices, differences in the timing of capital expenditures, and variances in average production estimates can have a significant impact on the key performance measures included in PetroTal's guidance. The Company's actual results may differ materially from these estimates. To view the source version of this press release, please visit Error in retrieving data Sign in to access your portfolio Error in retrieving data Error in retrieving data Error in retrieving data Error in retrieving data
Business Insider
24 minutes ago
- Business Insider
Behind the biometric curtain: When border tech outpaces accountability
In an era where artificial intelligence and biometric surveillance are becoming the new frontiers of national security, a quiet struggle is unfolding—one not just of innovation, but of ethics, transparency, and trust. At the center of this unfolding narrative are companies like Travizory, a Swiss-based border tech startup, whose recent moves have sparked scrutiny from both industry peers and government watchdogs. Across the globe, from South America to the Indian Ocean, the implications of fast-tracked technology contracts are coming under the microscope. This is not just a story about software and security, it's a cautionary tale for every government, especially in Africa, navigating the allure of digital border solutions without adequate oversight. The Stakes in Kenya This question has come to the forefront in Kenya, where controversy surrounds the management of the country's eCitizen platform—a critical national digital portal that connects citizens and tourists to government services ranging from visa issuance to tax payments. At the center of the debate is Travizory that secured a contract to help digitize and manage parts of Kenya's travel authorization and border management ecosystem. The Travizory contract has created multiple risks: revenue leakage through foreign exchange spreads, personal data subject to Swiss rather than Kenyan privacy laws during the pilot period; and an opaque exit clause allowing Travizory to claim intellectual property indemnity fees if Kenya builds its own system. The issue, however, is not simply about foreign involvement, it is about the legal jurisdiction under which this data is being handled. Travizory's contract in Kenya has been in contention not only because it collected and allegedly withheld the gross revenues owed to the government of Kenya, but it has personal data subject to Swiss rather than Kenyan privacy laws during the pilot period. This revelation has sparked serious concern among digital rights advocates, policymakers, and civil society organizations, who argue that such arrangements undermine Kenya's data sovereignty— the principle that the data of a country's citizens should be governed by that country's laws, not those of a foreign state. Echoes in the Seychelles This isn't the first time Travizory has been linked to questions of transparency and conflict of interest. In Seychelles, an archipelago praised for topping Africa's Corruption Perception Index, the company is the central player in a growing controversy involving the nation's Minister of Transport, Antony Derjacques. The minister, whose law chamber reportedly advised Travizory, failed to disclose this connection while overseeing the company's 10-year government contract with Travizory for managing the country's digital travel authorization platform—a tool that became central during the COVID-19 pandemic. Seychelles opposition leader Sebastien Pillay has called for Derjacques' resignation, alleging a clear conflict of interest. The National Assembly is now grappling with how to circulate the confidential contract without breaching its non-disclosure clauses, raising even more concerns about transparency in public-private partnerships. Why It Matters for Africa For African nations investing heavily in digital identity, e-visas, and border modernization, the Travizory case offers valuable lessons. Technology may be global, but accountability must be local. Governments entering agreements with fast-scaling tech vendors—particularly in high-trust areas like biometric surveillance, passenger data, and border security—must implement stronger vetting processes, conflict of interest safeguards, and ongoing performance audits. This is especially important as African states look to digitize border control, often under tight deadlines and with support from international donors or multilateral partners. The risk? Falling for shiny demos without digging into a company's history, real-world deployments, or local partnerships. The Bigger Picture In a market where companies compete not just with technology but also perception, moments like these become inflection points. Travizory's allegations of corruption in Seychelles, Kenya and others that we have yet to uncover, should not be dismissed as isolated events—they're reflective of a deeper industry tension between growth, and governance. And for African governments watching from the sidelines, now is the time to ask the right questions—not just can this be done, but by whom and at what cost?
Android Authority
an hour ago
- Android Authority
Samsung will soon make chips for iPhones in the US
Ryan Haines / Android Authority TL;DR Apple has said that Samsung's US factory will make chips for a number of its products, including iPhones. It's unclear if Apple is referring to its A series chips that are the heart and soul of iPhones. Samsung has historically produced A series chips for Apple, but it's been a while since anyone but TSMC manufactured iPhone chips. Apple says Samsung's facility will supply chips that 'optimize power and performance of Apple products.' Apple has announced that none other than Samsung will soon make chips for its products, including iPhones. Before you start thinking iPhones will soon be powered by Exynos processors, let's examine what Apple is saying exactly and the history between the two companies as far as manufacturing iPhone components is concerned. As part of its announcement of investing an additional $100 billion in the US over the next four years, Apple said that it will procure chips from Samsung's Austin factory for a number of its products, including its phones. 'This facility will supply chips that optimize power and performance of Apple products, including iPhone devices,' Apple said in a statement. While it's unclear just how big a role these Samsung chips will play in shaping Apple's A series processors, it's certainly interesting to see the two tech giants joining hands for crucial iPhone components. While Samsung currently doesn't have any role in manufacturing any part of the iPhone's A series processors — that's a job for TSMC — the South Korean company has been a long-time supplier of displays, RAM, and memory chips for iPhones. Samsung also historically manufactured Apple's A series chips for iPhone, specifically from the A4 chip used on the iPhone 4 through to the A9 chip used in the iPhone 6s. After the A9 chip, however, Apple moved its chip production to TSMC. It would be a big deal if Samsung once again started making the A series chips for Apple out of the US, but that's unlikely to happen. Apple is already expected to utilize TSMC's 3nm process for its A19 and A19 Pro chips, which will power the iPhone 17 lineup. Follow
