Flight Plan to Net-Zero Sustainable Aviation Fuels

Image Credit: RaymondClarkeImages (Flickr)

The Future of Flight in a Net-Zero Carbon World: 9 Scenarios, Abundant Sustainable Biofuel

Several major airlines have pledged to reach net-zero carbon emissions by midcentury to fight climate change. It’s an ambitious goal that will require an enormous ramp-up in sustainable aviation fuels, but that alone won’t be enough, latest research shows.

The idea of jetliners running solely on fuel made from used cooking oil from restaurants or corn stalks might seem futuristic, but it’s not that far away.

Airlines are already experimenting with sustainable aviation fuels. These include biofuels made from agriculture residues, trees, corn and used cooking oil. Other fuels are synthetic, made by combining captured carbon from the air and green hydrogen, made with renewable energy. Often, they can go straight into existing aircraft fuel tanks that normally hold fossil jet fuel.

United Airlines, which has been using a blend of used oil or waste fat and fossil fuels on some flights from Los Angeles and Amsterdam, announced in February 2023 that it had formed a partnership with biofuel companies to power 50,000 flights a year between its Chicago and Denver hubs using ethanol-based sustainable aviation fuels by 2028.

This article was republished with permission from The Conversation, a news site dedicated to sharing ideas from academic experts. It represents the research-based findings and thoughts of, Candelaria Bergero, Ph.D. Student in Earth System Science, University of California, Irvine, Steve Davis Professor of Earth System Science, University of California, Irvine.

In a new study, we examined different options for aviation to reach net-zero emissions and assessed how air travel could continue without contributing to climate change.

The bottom line: Each pathway has important trade-offs and hurdles. Replacing fossil jet fuel with sustainable aviation fuels will be crucial, but the industry will still need to invest in direct-air carbon capture and storage to offset emissions that can’t be cut.

Scenarios for the Future

Before the pandemic, in 2019, aviation accounted for about 3.1% of total global CO₂ emissions from fossil fuel combustion, and the number of passenger miles traveled each year was rising. If aviation emissions were a country, that would make it the sixth-largest emitter, closely following Japan.

In addition to releasing carbon emissions, burning jet fuel produces soot and water vapor, known as contrails, that contribute to warming, and these are not avoided by switching to sustainable aviation fuels

Aviation is also one of the hardest-to-decarbonize sectors of the economy. Small electric and hydrogen-powered planes are being developed, but long-haul flights with lots of passengers are likely decades away.

We developed and analyzed nine scenarios spanning a range of projected passenger and freight demand, energy intensity and carbon intensity of aviation to explore how the industry might get to net-zero emissions by 2050.

Nine scenarios illustrate how much carbon offsets would be required to reach net-zero emissions, depending on choices made about demand and energy and carbon intensity. Each starts with 2021’s emissions (1.2 gigatons of carbon dioxide equivalent). With rising demand and no improvement in carbon intensity, a large amount of carbon capture will be necessary. Less fossil fuel use and slower demand growth reduce offset needs. Candelaria Bergero

We found that as much as 19.8 exajoules of sustainable aviation fuels could be needed for the entire sector to reach net-zero CO₂ emissions. With other efficiency improvements, that could be reduced to as little as 3 exajoules. To put that into context, 3 exajoules is almost equivalent to all biofuels produced in 2019 and far surpasses the 0.005 exajoules of bio-based jet fuel produced in 2019. An exajoule is a measure of energy.

Flying less and improving airplanes’ energy efficiency, such as using more efficient “glide” landings that allow airlines to approach the airport with engines at near idle, can help reduce the amount of fuel needed. But even in our rosiest scenarios – where demand grows at 1% per year, compared to the historical average of 4% per year, and energy efficiency improves by 4% per year rather than 1% – aviation would still need about 3 exajoules of sustainable aviation fuels.

Why Offsets are Still Necessary

A rapid expansion in biofuel sustainable aviation fuels is easier said than done. It could require as much as 1.2 million square miles (300 million hectares) of dedicated land to grow crops to turn into fuel – roughly 19% of global cropland today.

Another challenge is cost. The global average price of fossil jet fuel is about about US$3 per gallon ($0.80 per liter), while the cost to produce bio-based jet fuels is often twice as much. The cheapest, HEFA, which uses fats, oils and greases, ranges in cost from $2.95 to $8.67 per gallon ($0.78 to $2.29 per liter), but it depends on the availability of waste oil.

Fischer-Tropsch biofuels, produced by a chemical reaction that converts carbon monoxide and hydrogen into liquid hydrocarbons, range from $3.79 to $8.71 per gallon ($1 to $2.30 per liter). And synthetic fuels are from $4.92 to $17.79 per gallon ($1.30 to $4.70 per liter).

Realistically, reaching net-zero emissions will likely also rely on carbon dioxide removal.

In a future with similar airline use as today, as much as 3.4 gigatons of carbon dioxide would have to be captured from the air and locked away – pumped underground, for example – for aviation to reach net-zero. That could cost trillions of dollars.

For these offsets to be effective, the carbon removal would also have to follow a robust eligibility criteria and be effectively permanent. This is not happening today in airline offsetting programs, where airlines are mostly buying cheap, nonpermanent offsets, such as those involving forest conservation and management projects.

Some caveats apply to our findings, which could increase the need for offsets even more.

Our assessment assumes sustainable aviation fuels to be net-zero carbon emissions. However, the feedstocks for these fuels currently have life-cycle emissions, including from fertilizer, farming and transportation. The American Society for Testing Materials also currently has a maximum blend limit: up to 50% sustainable fuels can be blended into conventional jet fuel for aviation in the U.S., though airlines have been testing 100% blends in Europe.

How to Overcome the Final Hurdles

To meet the climate goals the world has set, emissions in all sectors must decrease – including aviation.

While reductions in demand would help reduce reliance on sustainable aviation fuels, it’s more likely that more and more people will fly in the future, as more people become wealthier. Efficiency improvements will help decrease the amount of energy needed to power aviation, but it won’t eliminate it.

Scaling up sustainable aviation fuel production could decrease its costs. Quotas, such as those introduced in the European Union’s “Fit for 55” plan, subsidies and tax credits, like those in the U.S. Inflation Reduction Act signed in 2022, and a carbon tax or other price on carbon, can all help achieve this.

Additionally, given the role that capturing carbon from the atmosphere will play in achieving net-zero emissions, a more robust accounting system is needed internationally to ensure that the offsets are compensating for aviation’s non-CO₂ impacts. If these hurdles are overcome, the aviation sector could achieve net-zero emissions by 2050.

Alvopetro Energy (ALVOF) – Company update mostly good news


Wednesday, February 08, 2023

Alvopetro Energy Ltd.’s vision is to become a leading independent upstream and midstream operator in Brazil. Our strategy is to unlock the on-shore natural gas potential in the state of Bahia in Brazil, building off the development of our Caburé natural gas field and our strategic midstream infrastructure.

Michael Heim, CFA, Senior Research Analyst, Noble Capital Markets, Inc.

Refer to the full report for the price target, fundamental analysis, and rating.

Production running ahead of our modeling. January sales volumes averaged 2,754 boepd ahead of our 2023-1Q quarterly estimate of 2,710 boepd. This represents a 1% increase over 2022-4Q volumes and a 10% increase over 2022-1Q volumes. The year-over-year increase reflects an increase in processing volumes last summer to 3,000 boepd. Alvopetro will be bringing two new wells to production in the next few months which could further increase sales.

Prices rise again under semi-annual price redetermination. Realized natural gas prices will increase to an expected level of $12.40/mcf (includes price redetermination and various adjustments). Redeterminations are based on a variety of factors including oil prices, gas prices, and exchange rates subject to price adjustment floors and ceilings that rise each period. New prices reflect a 3.6% increase from the previous determination. As we have discussed in the past, current redeterminations would be as high as $15/mcf absent a ceiling and will most likely continue to rise each period even if energy prices decline.


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*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision. 

Largo Inc. (LGO) – Coverage Initiated With a $11 Price Target


Tuesday, February 07, 2023

Michael Heim, CFA, Senior Research Analyst, Noble Capital Markets, Inc.

Refer to the full report for the price target, fundamental analysis, and rating.

Largo is a play on growing vanadium demand. We believe Largo, Inc. offers investors an attractive way to play an expected growth in the demand for vanadium due to its use in large-scale energy storage. Largo is the largest producer of vanadium outside of China and Russia. The high vanadium concentration of is Maracas Menchen Mine in Brazil makes Largo one of the lowest-cost producers of vanadium in the world.

Largo is involved with vanadium batteries. In addition to mining vanadium, Largo has formed a division to manufacture and install Vanadium Redox Flow Batteries (VRFB). VRFBs have key advantages over other battery types in terms of scalability, cost, and safety making them ideal for grid operations. VRFB can store energy for months and have operating duration periods of 6-10 hours. Vanadium used in VRFBs has little degradation and can be recovered and reused upon recycling.


Get the Full Report

Equity Research is available at no cost to Registered users of Channelchek. Not a Member? Click ‘Join’ to join the Channelchek Community. There is no cost to register, and we never collect credit card information.

This Company Sponsored Research is provided by Noble Capital Markets, Inc., a FINRA and S.E.C. registered broker-dealer (B/D).

*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision. 

Release – Alvopetro Announces January 2023 Sales Volumes, our Semi-Annual Natural Gas Price Redetermination, 2023 Capital Plans and an Operational Update

Research News and Market Data on ALVOF

Feb 06, 2023

CALGARY, AB, Feb. 6, 2023 /CNW/ – Alvopetro Energy Ltd. (TSXV: ALV) (OTCQX: ALVOF) announces January 2023 sales volumes, our February 1, 2023 natural gas price redetermination, our 2023 capital plan and an operational update.

President and CEO, Corey Ruttan commented:

“Building on our record year in 2022 we are looking forward to our 2023 capital plan.  Our focus this year is on adding production and reserves from our lower risk development opportunities. We have made the key infrastructure investments necessary to realize the full potential from our Murucututu natural gas project. This project has significant reserves and resources and our goal is to unlock this potential with a multi-year development plan starting this year.”

January 2023 sales volumes

January sales volumes averaged 2,754 boepd, including natural gas sales of 15.6 MMcfpd, associated natural gas liquids sales (condensate) of 141 bopd, and 5 bopd of oil sales, based on field estimates, a 1% increase from our Q4 average daily volumes.   

Operational Update and 2023 Capital Plans

Murucututu (100% Alvopetro)

On our Murucututu project, we expect to commence the stimulation on our 197(1) well later this quarter. We have already completed the work to tie-in this well to our 183(1) facility and expect to commence production in the second quarter. We also plan to drill two “fit-for-purpose” Gomo development wells in 2023. One of these locations has additional uphole exploration potential in the Caruaçu and Marfim Formations.  Total capital expenditures of $16 million are budgeted for Murucututu in 2023.

Caburé (49.1% Alvopetro)

Our 2023 capital budget includes an expansion of the unit facilities and drilling two additional development wells. Total expenditures of $3 million are budgeted for Alvopetro’s share of 2023 capital expenditures on our Caburé project.

Bom Lugar (100% Alvopetro)

In 2023, we plan to drill up to two development wells on our Bom Lugar oil field, targeting the Caruaçu Formation with additional potential in the deeper Gomo and Agua Grande Formations. Capital expenditures of up to $11 million are budgeted in 2023 for Bom Lugar, including the development wells and facility upgrades.

Mãe-da-lua (100% Alvopetro)

2023 capital expenditures include $0.5 million at our Mãe-da-lua field where we plan to complete a stimulation of our existing well to improve oil recovery rates.

Exploration (100% Alvopetro)

In 2022, Alvopetro drilled two exploration prospects, 182-C, and 183-B. We encountered thick, hydrocarbon saturated zones in the Sergi Formation which have demonstrated low permeability during testing operations. Alvopetro continues to evaluate alternatives to enhance permeability in the Sergi Formation in both wells and in the Agua Grande Formation of the 183-B1 well. We are evaluating alternatives to remediate possible permeability impacts from near wellbore damage.  This work is expected to start with the 182-C2 well later this quarter. Capital costs of $0.4 million are currently budgeted on these projects in 2023, including final testing costs on 182-C2 incurred in January. Future capital expenditures will depend on these initial results.

Semi-Annual Natural Gas Price Redetermination

Effective February 1, 2023, our natural gas price under our long-term gas sales agreement with Bahiagás has been adjusted to BRL2.00/m3 or $11.88/Mcf (based on our average heat content to date and the January 31, 2023 BRL/USD foreign exchange rate of 5.10). This price represents an increase of 3.6% from our prior contracted price and will be effective for natural gas sales from February 1 to July 31, 2023. Including recently approved and enhanced sales tax credits, our realized gas price, net of sales taxes, is expected to be $12.40/Mcf (based on our average heat content to date and the January 31, 2023 BRL/USD foreign exchange rate of 5.10).   

Corporate Presentation

Alvopetro’s updated corporate presentation is available on our website at:http://www.alvopetro.com/corporate-presentation

Social Media

Follow Alvopetro on our social media channels at the following links: Twitter – https://twitter.com/AlvopetroEnergyInstagram – https://www.instagram.com/alvopetro/LinkedIn – https://www.linkedin.com/company/alvopetro-energy-ltdYouTube –https://www.youtube.com/channel/UCgDn_igrQgdlj-maR6fWB0w

Alvopetro Energy Ltd.’s vision is to become a leading independent upstream and midstream operator in Brazil. Our strategy is to unlock the on-shore natural gas potential in the state of Bahia in Brazil, building off the development of our Caburé natural gas field and our strategic midstream infrastructure.

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this news release.

All amounts contained in this new release are in United States dollars, unless otherwise stated and all tabular amounts are in thousands of United States dollars, except as otherwise noted.

Abbreviations:

bbls=barrels
boepd=barrels of oil equivalent (“boe”) per day
bopd =barrels of oil and/or natural gas liquids (condensate) per day
BRL =Brazilian real
m3 =cubic metre
Mcf =thousand cubic feet
MMcf =million cubic feet
MMcfpd =million cubic feet per day

BOE Disclosure. The term barrels of oil equivalent (“boe”) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet per barrel (6Mcf/bbl) of natural gas to barrels of oil equivalence is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. All boe conversions in this news release are derived from converting gas to oil in the ratio mix of six thousand cubic feet of gas to one barrel of oil.

Forward-Looking Statements and Cautionary Language. This news release contains “forward-looking information” within the meaning of applicable securities laws. The use of any of the words “will”, “expect”, “intend” and other similar words or expressions are intended to identify forward-looking information. Forward–looking statements involve significant risks and uncertainties, should not be read as guarantees of future performance or results, and will not necessarily be accurate indications of whether or not such results will be achieved. A number of factors could cause actual results to vary significantly from the expectations discussed in the forward-looking statements. These forward-looking statements reflect current assumptions and expectations regarding future events. Accordingly, when relying on forward-looking statements to make decisions, Alvopetro cautions readers not to place undue reliance on these statements, as forward-looking statements involve significant risks and uncertainties. More particularly and without limitation, this news release contains forward-looking information concerning plans relating to the Company’s operational activities, proposed exploration and development activities and the timing for such activities, capital spending levels and future capital costs, and the expected natural gas price, gas sales and gas deliveries under the Company’s long-term gas sales agreement. The forward–looking statements are based on certain key expectations and assumptions made by Alvopetro, including but not limited to expectations and assumptions concerning the timing of regulatory licenses and approvals, equipment availability, the success of future drilling, completion, testing, recompletion and development activities, the performance of producing wells and reservoirs, well development and operating performance, expectations regarding Alvopetro’s working interest and the outcome of any redeterminations, environmental regulation, including regulation relating to hydraulic fracturing and stimulation, the ability to monetize hydrocarbons discovered, the outlook for commodity markets and ability to access capital markets, foreign exchange rates, general economic and business conditions, the impact of the COVID-19 pandemic, weather and access to drilling locations, the availability and cost of labour and services, the regulatory and legal environment and other risks associated with oil and gas operations. The reader is cautioned that assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be incorrect. Actual results achieved during the forecast period will vary from the information provided herein as a result of numerous known and unknown risks and uncertainties and other factors. Although Alvopetro believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Alvopetro can give no assurance that it will prove to be correct. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on factors that could affect the operations or financial results of Alvopetro are included in our annual information form which may be accessed on Alvopetro’s SEDAR profile at www.sedar.com. The forward-looking information contained in this news release is made as of the date hereof and Alvopetro undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.

SOURCE Alvopetro Energy Ltd.

Release – InPlay Oil Corp. Confirms Monthly Dividend for February 2023

Research News and Market Data on IPOOF

CALGARY AB, Feb. 1, 2023 /CNW/ – InPlay Oil Corp. (TSX: IPO) (OTCQX: IPOOF) (“InPlay” or the “Company”) is pleased to confirm that its Board of Directors has declared a monthly cash dividend of $0.015 per common share payable on February 28, 2023, to shareholders of record at the close of business on February 15, 2023.  The monthly cash dividend is expected to be designated as an “eligible dividend” for Canadian federal and provincial income tax purposes.

About InPlay Oil Corp.

InPlay is a junior oil and gas exploration and production company with operations in Alberta focused on light oil production. The company operates long-lived, low-decline properties with drilling development and enhanced oil recovery potential as well as undeveloped lands with exploration possibilities. The common shares of InPlay trade on the Toronto Stock Exchange under the symbol IPO and the OTCQX Exchange under the symbol IPOOF.

SOURCE InPlay Oil Corp.

For further information: Doug Bartole, President and Chief Executive Officer, InPlay Oil Corp., Telephone: (587) 955-0632; Darren Dittmer, Chief Financial Officer, InPlay Oil Corp., Telephone: (587) 955-0634

The Bullish ESG Investment Fund Trend Reversed Recently

Image Credit: Marco Verch (Flickr)

Will ESG Investing be Able to Recycle Itself in 2023?

Investment trends run in cycles. As a new trend is recognized, it attracts new money, which drives up prices, until there isn’t as much additional money left to keep the trend going strong. At some point, investors may feel there is a more profitable use for their capital, and the old trend then falls out of favor. Over the decades, sustainable and social investing have had several up cycles, followed by a hiatus and then a new incarnation. Where is ESG investing in its cycle in 2023?

Background

Environmental, social, and governance (ESG) holds as an underlying promise that companies and those that invest in them can do well by doing good. Just a couple of years back, investors trillions of dollars into ESG strategies. This had the effect of causing many businesses to alter their business model in ways that would conform to an unofficial ESG designation(s).

Investment companies aimed to fill the demand by creating new ESG funds, at the same time the business of creating ESG profile rankings also grew. Professionally managed assets with ESG mandates surged to an astronomical $46 trillion globally in 2021. According to Deloitte’s Center for Financial Services, assets, ESG funds represented nearly 40% of all assets under management.

The first couple of years this decade were riddled with black swan events, investment assets swelled on many fronts. Investors in ESG have recently stepped back and moved the most money out of U.S. sustainable funds in more than five years (4Q). The fund industry experienced nearly $6.2 billion pulled from professionally managed funds catering to environmental, social, and governance strategies. As compared to the trillions in the funds, this is not overly significant. What is significant is the reversal of what had been a strong trend of inflows.

Sustainable funds overall netted more than $3 billion in positive flows for all of 2022 – traditional U.S. funds experienced more than $370 billion in withdrawals during the year. A lower percentage but still significant as it was the first calendar year of net outflows since Morningstar began tracking data in 1983.

According to a new report from Morningstar, flows of money into U.S. sustainable mutual funds and ETFs has declined since its record high in the first quarter of 2021. The withdrawal of money comes as many companies are improving their ESG scores. The decline in 4Q 2022 came as a myriad of factors soured investors on many market sectors.

Political Winds Changing

But stock market sentiment may only be part of the story. There are louder and louder voices that are questioning the purity of this newer incarnation of social investing. They ask if it provide for what is good and best overall? There is even some confusion by investors that remember the older versions of social and environmental investing that specifically excluded things like nuclear power. Today many ESG scores view carbonless nuclear generation as clean.

Where there is money, there is also politics. This is part of what originally helped the trend pick up steam. Now opposing political voices are causing some second looks at the overall benefits. The most recent examples include the person who moved the electric vehicle (EV) movement out so far into the spotlight that the car company he founded is the most valuable in the world (market cap). Elon Musk made one of his negative ESG comments as a tweet responding to self-described “Hero of the Environment” and author, Michael Shellenberger.

Image: Twitter (@elonmusk)

Less political, but perhaps more important, Federal Reserve Chair Jerome Powell made his official position clear during a conference titled Central Bank Independence and the Mandate—Evolving Views. Standing before an international audience in Stockholm, Sweden, Powell said, “we resist the temptation to broaden our scope to address other important social issues of the day. Taking on new goals, however worthy, without a clear statutory mandate would undermine the case for our independence.”

The New York Times ran the following headline:

Image: NYT Headline January 10, 2023

Performance

Sustainable funds lagged behind the broader market in performance. Remember, there was an increasing supply of names that were attaining ESG status. Also their lack of exposure to the top-performing oil and gas sector and its 66% gain during the year hurt performance.

The drag in the last quarter of 2022 was even more pronounced as it was the first period in more than three years that U.S. sustainable funds had a lower organic growth rate than the total U.S. fund market. During the fourth quarter, sustainable funds shrank by 2.2% compared with an 0.8% shrinkage in the overall U.S. landscape.

Morningstar’s sustainable fund universe encompasses mutual funds and ETFs “that, by prospectus or other regulatory filings, claim to focus on sustainability; impact; or environmental, social, and governance factors.”

Take Away

Last year while the overall markets were gloomier, ESG investors slowed and then reversed their piling into ESG funds. These funds had attracted 40% of fund assets, so it is no surprise they paused. However last quarter was the first decline since 1983. Part of the issue is the normal cyclicality of investment trends. Make no mistake; sustainable investing is not dying, but it suffers from a lack of clarity as to how companies are scored, and who is doing the scoring.

Investors that wish to keep the entire universe of opportunities open to their portfolios can still invest in stocks that suit their appetite for many factors, including environmental, social, or corporate governance. A little digging through analyst research reports ought to provide enough information to steer one clear of companies individuals would rather not be part of, and those they feel especially good about owning.

Paul Hoffman

Managing Editor, Channelchek

Sources

https://www.morningstar.com/products/esg-investing

https://www.yahoo.com/now/musk-rips-satanic-esg-world-233742968.html

https://www.barrons.com/articles/esg-investing-big-test-reckoning-51650041442

https://www.barrons.com/articles/us-esg-sustainable-funds-outflows-51674767507?mod=hp_LEAD_5

https://www2.deloitte.com/us/en/insights/environmental-social-governance.html?icid=top_environmental-social-governance

Permex Petroleum (OILCD) – Permex held a call updating investors


Tuesday, January 24, 2023

Michael Heim, CFA, Senior Research Analyst, Noble Capital Markets, Inc.

Refer to the full report for the price target, fundamental analysis, and rating.

Production from first drilled well is coming. The Eoff PPC #3 well in the Breedlove Field was completed in October and is going through a Flowback Recovery Period (removal of liquids). It was shut down due to freezing temperatures. Management expects full production by the end of February and will disclose flow rates then. The company hinted that it will probably go forward with converting the well to a horizontal well at an additional $1.1 million cost.

Cash is tight. Permex’s cash position is down to $2.5 million, not enough to drill another well. The company is opposed to taking on debt (which we agree with) because debt is the Achilles heel of start-up energy companies should energy prices decline. The company discussed selling acreage but indicated that it neither has a large contiguous field to sell (outside of its Breedlove Field position) nor does it have small, producing property that might be of interest to energy companies. Management would like to issue stock but not at the current stock price of 4% of net asset value.


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Equity Research is available at no cost to Registered users of Channelchek. Not a Member? Click ‘Join’ to join the Channelchek Community. There is no cost to register, and we never collect credit card information.

This Company Sponsored Research is provided by Noble Capital Markets, Inc., a FINRA and S.E.C. registered broker-dealer (B/D).

*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision. 

InPlay Oil (IPOOF) – Production slows, expenditures rise, and gas prices drop


Thursday, January 19, 2023

InPlay Oil is a junior oil and gas exploration and production company with operations in Alberta focused on light oil production. The company operates long-lived, low-decline properties with drilling development and enhanced oil recovery potential as well as undeveloped lands with exploration possibilities. The common shares of InPlay trade on the Toronto Stock Exchange under the symbol IPO and the OTCQX Exchange under the symbol IPOOF.

Michael Heim, CFA, Senior Research Analyst, Noble Capital Markets, Inc.

Refer to the full report for the price target, fundamental analysis, and rating.

Production slows. Management projects 2022 production of 9,100-9,200 BOE/d versus 11/9/22 guidance of 9,150-9,400. Downtime at a third party gas facility led to a 435 BOE/d decrease in production. Cold weather also delayed getting wells on line. We have reduced our estimate to 9,162 BOE/d from 9,280. The company projects 2023 production of 9,500-10,000 BOE/d down from 9,900-10,400. We have lowered our forecast to 10,000 BOE/d from 10,400 to be within management’s guidance. We are comfortable being at the upper end of guidance given InPlay’s history of surpassing guidance (until the most recent quarter).

Expenditures rise. The company projects 2022 capital expenditures of C$76-78 million up from C$70-72 million due the acceleration of a drilling program. 2023 capital expenditure guidance increased to C$75-80 million (versus C$69-71 million) despite the drilling of 0.5 net wells less than previously assumed. Management attributes the higher capital expenditures mainly to two gas facility upgrades but also notes that it plans to drill longer wells in 2023 than in 2022.


Get the Full Report

Equity Research is available at no cost to Registered users of Channelchek. Not a Member? Click ‘Join’ to join the Channelchek Community. There is no cost to register, and we never collect credit card information.

This Company Sponsored Research is provided by Noble Capital Markets, Inc., a FINRA and S.E.C. registered broker-dealer (B/D).

*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision. 

Release – InPlay Oil Corp. Named to 2023 OTCQX Best 50

Research News and Market Data on IPOOF

NEWS PROVIDED BY

InPlay Oil Corp. 

Jan 19, 2023, 08:00 ET

CALGARY, AB, Jan. 18, 2023 /CNW/ – InPlay Oil Corp. (TSX: IPO) (OTCQX: IPOOF) (“InPlay” or the “Company”) is pleased to announce it has been named to the 2023 OTCQX® Best 50, a ranking of top performing companies traded on the OTCQX Best Market last year.

The OTCQX Best 50 is an annual ranking of the top 50 U.S. and international companies traded on the OTCQX market.  The ranking is calculated based on an equal weighting of one-year total return and average daily dollar volume growth in the previous calendar year.  Companies in the 2023 OTCQX Best 50 were ranked based on their performance in 2022. 

Doug Bartole, President and Chief Executive Officer of InPlay, commented: “We are very pleased with InPlay’s inclusion in the OTCQX Best 50 list. InPlay was the fifth best performer on the OTCQX Best Market based on 2022 total return and average daily dollar volume growth and this is the second consecutive year placing in the top five on this list. This ranking is a stong acknowledgement of the value we have created for shareholders through measured per share growth, free adjusted funds flow generation and delivering sustainable returns to shareholders. It is also evidence of the commitment of our employees and management team, strong leadership from our board of directors and the support of our lenders and shareholders. As outlined in our recently announced 2023 capital budget and guidance, InPlay finds itself in an extremely enviable financial and operational position allowing the Company to continue to forecast strong results in the upcoming year.” 

For the complete 2023 OTCQX Best 50 ranking, visit
https://www.otcmarkets.com/files/2023_OTCQX_Best_50.pdf

The OTCQX Best Market offers transparent and efficient trading of established, investor-focused U.S. and global companies. To qualify for the OTCQX market, companies must meet high financial standards, follow best practice corporate governance, and demonstrate compliance with applicable securities laws.

About InPlay Oil Corp.

InPlay is a junior oil and gas exploration and production company with operations in Alberta focused on light oil production. The company operates long-lived, low-decline properties with drilling development and enhanced oil recovery potential as well as undeveloped lands with exploration possibilities. The common shares of InPlay trade on the Toronto Stock Exchange under the symbol IPO and the OTCQX Exchange under the symbol IPOOF.  Additional information about the Company and our latest corporate presentation can be found on InPlay’s website at www.inplayoil.com.

SOURCE InPlay Oil Corp.

For further information: Doug Bartole, President and Chief Executive Officer, InPlay Oil Corp., Telephone: (587) 955-0632; Darren Dittmer, Chief Financial Officer, InPlay Oil Corp., Telephone: (587) 955-0634

Who Gets to Decide the Future of Seafloor Mining?

Deep sea sponges and other creatures live on and among valuable manganese nodules like this one that could be mined from the seafloor. (GEOMAR)

Deep Seabed Mining Plans Pit Renewable Energy Demand Against Ocean Life in a Largely Unexplored Frontier

As companies race to expand renewable energy and the batteries to store it, finding sufficient amounts of rare earth metals to build the technology is no easy feat. That’s leading mining companies to take a closer look at a largely unexplored frontier – the deep ocean seabed.

A wealth of these metals can be found in manganese nodules that look like cobblestones scattered across wide areas of deep ocean seabed. But the fragile ecosystems deep in the oceans are little understood, and the mining codes to sustainably mine these areas are in their infancy.

A fierce debate is now playing out as a Canadian company makes plans to launch the first commercial deep sea mining operation in the Pacific Ocean.

The Metals Company completed an exploratory project in the Pacific Ocean in fall 2022. Under a treaty governing the deep sea floor, the international agency overseeing these areas could be forced to approve provisional mining there as soon as spring 2023, but several countries and companies are urging a delay until more research can be done. France and New Zealand have called for a ban on deep sea mining.

As scholars who have long focused on the economic, political and legal challenges posed by deep seabed mining, we have each studied and written on this economic frontier with concern for the regulatory and ecological challenges it poses.

Manganese nodules on the seafloor in the Clarion-Clipperton Zone, between Hawaii and Mexico, . (GEOMAR)

What’s Down There, and Why Should We Care?

A curious journey began in the summer of 1974. Sailing from Long Beach, California, a revolutionary ship funded by eccentric billionaire Howard Hughes set course for the Pacific to open a new frontier — deep seabed mining.

Widespread media coverage of the expedition helped to focus the attention of businesses and policymakers on the promise of deep seabed mining, which is notable given that the expedition was actually an elaborate cover for a CIA operation.

The real target was a Soviet ballistic missile submarine that had sunk in 1968 with all hands and what was believed to be a treasure trove of Soviet state secrets and tech onboard.

The expedition, called Project Azorian by the CIA, recovered at least part of the submarine – and it also brought up several manganese nodules from the seafloor.

Manganese nodules are roughly the size of potatoes and can be found across vast areas of seafloor in parts of the Pacific and Indian oceans and deep abyssal plains in the Atlantic. They are valuable because they are exceptionally rich in 37 metals, including nickel, cobalt and copper, which are essential for most large batteries and several renewable energy technologies.

Manganese nodules form as metals accumulate around a shell or part of another nodule. (GEOMAR)

These nodules form over millennia as metals nucleate around shells or broken nodules. The Clarion-Clipperton Zone, between Mexico and Hawaii in the Pacific Ocean, where the mining test took place, has been estimated to have over 21 billion metric tons of nodules that could provide twice as much nickel and three times more cobalt than all the reserves on land.

Mining in the Clarion-Clipperton Zone could be some 10 times richer than comparable mineral deposits on land. All told, estimates place the value of this new industry at some US$30 billion annually by 2030. It could be instrumental in feeding the surging global demand for cobalt that lies at the heart of lithium-ion batteries.

Yet, as several scientists have noted, we still know more about the surface of the moon than what lies at the bottom of the deep seabed.

Deep Seabed Ecology

Less than 10% of the deep seabed has been mapped thoroughly enough to understand even the basic features of the structure and contents of the ocean floor, let alone the life and ecosystems therein.

Even the most thoroughly studied region, the Clarion-Clipperton Zone, is still best characterized by the persistent novelty of what is found there.

Brightly colored sea cucumbers and many other unusual deep sea creatures live among the nodules in the Clarion-Clipperton Zone (GEOMAR)

Brightly colored sea cucumbers and many other unusual deep sea creatures live among the nodules in the Clarion-Clipperton Zone. (GEOMAR)

Between 70% and 90% of living things collected in the Clarion-Clipperton Zone have never been seen before, leaving scientists to speculate about what percentage of all living species in the region has never been seen or collected. Exploratory expeditions regularly return with images or samples of creatures that would richly animate science fiction stories, like a 6-foot-long bioluminescent shark.

Also unknown is the impact that deep sea mining would have on these creatures.

An experiment in 2021 in water about 3 miles (5 kilometers) deep off Mexico found that seabed mining equipment created sediment plumes of up to about 6.5 feet (2 meters) high. But the project authors stressed that they didn’t study the ecological impact. A similar earlier experiment was conducted off Peru in 1989. When scientists returned to that site in 2015, they found some species still hadn’t fully recovered.

Environmentalists have questioned whether seafloor creatures could be smothered by sediment plumes and whether the sediment in the water column could effect island communities that rely on healthy oceanic ecosystems. The Metals Company has argued that its impact is less than terrestrial mining.

Given humanity’s lack of knowledge of the ocean, it is not currently possible to set environmental baselines for oceanic health that could be used to weigh the economic benefits against the environmental harms of seabed mining.

Scarcity and the Economic Case for Mining

The economic case for deep seabed mining reflects both possibility and uncertainty.

On the positive side, it could displace some highly destructive terrestrial mining and augment the global supply of minerals used in clean energy sources such as wind turbines, photovoltaic cells and electric vehicles.

Terrestrial mining imposes significant environmental damage and costs to human health of both the miners themselves and the surrounding communities. Additionally, mines are sometimes located in politically unstable regions. The Democratic Republic of Congo produces 60% of the global supply of cobalt, for example, and China owns or finances 80% of industrial mines in that country. China also accounts for 60% of the global supply of rare earth element production and much of its processing. Having one nation able to exert such control over a critical resource has raised concerns.

Deep seabed mining comes with significant uncertainties, however, particularly given the technology’s relatively early state.

First are the risks associated with commercializing a new technology. Until deep sea mining technology is demonstrated, discoveries cannot be listed as “reserves” in firms’ asset valuations. Without that value defined, it can be difficult to line up the significant financing needed to build mining infrastructure, which lessens the first-mover advantage and incentivizes firms to wait for someone else to take the lead.

Commodity prices are also difficult to predict. Technology innovation can reduce or even eliminate the projected demand for a mineral. New mineral deposits on land can also boost supply: Sweden announced in January 2023 that it had just discovered the largest deposit of rare earth oxides in Europe.

In all, embarking on deep seabed mining involves sinking significant costs into new technology for uncertain returns, while posing risks to a natural environment that is likely to rise in value.

Who Gets to Decide the Future of Seafloor Mining?

The United Nations Convention on the Law of the Sea, which came into force in the early 1990s, provides the basic rules for ocean resources.

It allows countries to control economic activities, including any mining, within 200 miles of their coastlines, accounting for approximately 35% of the ocean. Beyond national waters, countries around the world established the International Seabed Authority, or ISA, based in Jamaica, to regulate deep seabed mining.

Critically, the ISA framework calls for some of the profits derived from commercial mining to be shared with the international community. In this way, even countries that did not have the resources to mine the deep seabed could share in its benefits. This part of the ISA’s mandate was controversial, and it was one reason that the United States did not join the Convention on the Law of the Sea.

Where large numbers of manganese nodules are found. The areas with the greatest concentrations are circled. (GEOMAR)

Where large numbers of manganese nodules are found. The areas with the greatest concentrations are circled. (GEOMAR)

With little public attention, the ISA worked slowly for several decades to develop regulations for exploration of undersea minerals, and those rules still aren’t completed. More than a dozen companies and countries have received exploration contracts, including The Metals Company’s work under the sponsorship of the island nation of Nauru.

ISA’s work has started to draw criticism as companies have sought to initiate commercial mining. A recent New York Times investigation of internal ISA documents suggested the agency’s leadership has downplayed environmental concerns and shared confidential information with some of the companies that would be involved in seabed mining. The ISA hasn’t finalized environmental rules for mining.

Much of the coverage of deep seabed mining has been framed to highlight the climate benefits. But this overlooks the dangers this activity could pose for the Earth’s largest pristine ecology – the deep sea. We believe it would be wise to better understand this existing, fragile ecosystem better before rushing to mine it.

A Dirty Challenge for Autonomous Vehicle Designers

Image Credit: Christine Daniloff (MIT)

Computers that Power Self-Driving Cars Could be a Huge Driver of Global Carbon Emissions

Adam Zewe | MIT News Office

In the future, the energy needed to run the powerful computers on board a global fleet of autonomous vehicles could generate as many greenhouse gas emissions as all the data centers in the world today.

That is one key finding of a new study from MIT researchers that explored the potential energy consumption and related carbon emissions if autonomous vehicles are widely adopted.

The data centers that house the physical computing infrastructure used for running applications are widely known for their large carbon footprint: They currently account for about 0.3 percent of global greenhouse gas emissions, or about as much carbon as the country of Argentina produces annually, according to the International Energy Agency. Realizing that less attention has been paid to the potential footprint of autonomous vehicles, MIT researchers built a statistical model to study the problem. They determined that 1 billion autonomous vehicles, each driving for one hour per day with a computer consuming 840 watts, would consume enough energy to generate about the same amount of emissions as data centers currently do.

The researchers also found that in over 90 percent of modeled scenarios, to keep autonomous vehicle emissions from zooming past current data center emissions, each vehicle must use less than 1.2 kilowatts of power for computing, which would require more efficient hardware. In one scenario — where 95 percent of the global fleet of vehicles is autonomous in 2050, computational workloads double every three years, and the world continues to decarbonize at the current rate — they found that hardware efficiency would need to double faster than every 1.1 years to keep emissions under those levels.

“If we just keep the business-as-usual trends in decarbonization and the current rate of hardware efficiency improvements, it doesn’t seem like it is going to be enough to constrain the emissions from computing onboard autonomous vehicles. This has the potential to become an enormous problem. But if we get ahead of it, we could design more efficient autonomous vehicles that have a smaller carbon footprint from the start,” says first author Soumya Sudhakar, a graduate student in aeronautics and astronautics.

Sudhakar wrote the paper with her co-advisors Vivienne Sze, associate professor in the Department of Electrical Engineering and Computer Science (EECS) and a member of the Research Laboratory of Electronics (RLE); and Sertac Karaman, associate professor of aeronautics and astronautics and director of the Laboratory for Information and Decision Systems (LIDS). The research appears today in the January-February issue of IEEE Micro.

Modeling Emissions

The researchers built a framework to explore the operational emissions from computers on board a global fleet of electric vehicles that are fully autonomous, meaning they don’t require a backup human driver.

The model is a function of the number of vehicles in the global fleet, the power of each computer on each vehicle, the hours driven by each vehicle, and the carbon intensity of the electricity powering each computer.

“On its own, that looks like a deceptively simple equation. But each of those variables contains a lot of uncertainty because we are considering an emerging application that is not here yet,” Sudhakar says.

For instance, some research suggests that the amount of time driven in autonomous vehicles might increase because people can multitask while driving, and the young and the elderly could drive more. But other research suggests that time spent driving might decrease because algorithms could find optimal routes that get people to their destinations faster.

In addition to considering these uncertainties, the researchers also needed to model advanced computing hardware and software that didn’t exist yet.

To accomplish that, they modeled the workload of a popular algorithm for autonomous vehicles, known as a multitask deep neural network, because it can perform many tasks at once. They explored how much energy this deep neural network would consume if it were processing many high-resolution inputs from many cameras with high frame rates simultaneously.

When they used the probabilistic model to explore different scenarios, Sudhakar was surprised by how quickly the algorithms’ workload added up.

For example, if an autonomous vehicle has 10 deep neural networks processing images from 10 cameras, and that vehicle drives for one hour a day, it will make 21.6 million inferences each day. One billion vehicles would make 21.6 quadrillion inferences. To put that into perspective, all of Facebook’s data centers worldwide make a few trillion inferences each day (1 quadrillion is 1,000 trillion).

“After seeing the results, this makes a lot of sense, but it is not something that is on a lot of people’s radar. These vehicles could actually be using a ton of computer power. They have a 360-degree view of the world, so while we have two eyes, they may have 20 eyes, looking all over the place and trying to understand all the things that are happening at the same time,” Karaman says.

Autonomous vehicles would be used for moving goods, as well as people, so there could be a massive amount of computing power distributed along global supply chains, he says. And their model only considers computing — it doesn’t take into account the energy consumed by vehicle sensors or the emissions generated during manufacturing.

Keeping Emissions in Check

To keep emissions from spiraling out of control, the researchers found that each autonomous vehicle needs to consume less than 1.2 kilowatts of energy for computing. For that to be possible, computing hardware must become more efficient at a significantly faster pace, doubling in efficiency about every 1.1 years.

One way to boost that efficiency could be to use more specialized hardware, which is designed to run specific driving algorithms. Because researchers know the navigation and perception tasks required for autonomous driving, it could be easier to design specialized hardware for those tasks, Sudhakar says. But vehicles tend to have 10- or 20-year lifespans, so one challenge in developing specialized hardware would be to “future-proof” it so it can run new algorithms.

In the future, researchers could also make the algorithms more efficient, so they would need less computing power. However, this is also challenging because trading off some accuracy for more efficiency could hamper vehicle safety.

Now that they have demonstrated this framework, the researchers want to continue exploring hardware efficiency and algorithm improvements. In addition, they say their model can be enhanced by characterizing embodied carbon from autonomous vehicles — the carbon emissions generated when a car is manufactured — and emissions from a vehicle’s sensors.

While there are still many scenarios to explore, the researchers hope that this work sheds light on a potential problem people may not have considered.

“We are hoping that people will think of emissions and carbon efficiency as important metrics to consider in their designs. The energy consumption of an autonomous vehicle is really critical, not just for extending the battery life, but also for sustainability,” says Sze.

Reprinted with permission of MIT News” (http://news.mit.edu/)

Release – Alvopetro Announces Record December 2022 Sales Volumes and an Operational Update

Research News and Market Data on ALVOF

Jan 06, 2023

CALGARY, AB, Jan. 6, 2023 /CNW/ – Alvopetro Energy Ltd. (TSXV: ALV) (OTCQX: ALVOF) announces record sales volumes in December 2022 and an operational update.

December 2022 sales volumes

December sales volumes averaged 2,785 boepd, including natural gas sales of 15.9 MMcfpd and associated natural gas liquids sales from condensate of 125 bopd, and 15 bopd of oil sales, based on field estimates, a 4% increase from our November 2022 average daily volumes.  Our sales volumes averaged 2,724 boepd in the fourth quarter of 2022, an increase of 3% from the third quarter of 2022.

Operational Update

We have completed testing our 182-C2 well on our 100% owned and operated Block 182. We completed drilling the 182-C2 well in October to a total measured depth (“MD”) of 3,185 metres. As previously announced, based on open-hole wireline logs, the well encountered a 223.7-metre-thick section with 121.3 metres of sand estimated above 6% porosity in the sand-dominated interval between 2,704.1 and 2,927.8 metres total vertical depth in the Sergi Formation. The well also encountered 10.9 metres of potential net hydrocarbon pay in the Agua Grande Formation, with an average porosity of 8.9% and average water saturation of 25.1%, using a 6% porosity cut-off, 50% Vshale cut-off and 50% water saturation cut-off. During testing operations of the Sergi and Agua Grande Formations we recovered non-commercial amounts of oil and natural gas. These results indicate lower than anticipated permeability and we are evaluating alternatives to remove any near well bore formation damage and reservoir stimulations to enhance permeability in the Agua Grande and Sergi Formations in this well, and the Sergi Formation in our 183-B1 well.

Corporate Presentation

Alvopetro’s updated corporate presentation is available on our website at:http://www.alvopetro.com/corporate-presentation

Social Media

Follow Alvopetro on our social media channels at the following links:     Twitter – https://twitter.com/AlvopetroEnergy     Instagram – https://www.instagram.com/alvopetro/     LinkedIn – https://www.linkedin.com/company/alvopetro-energy-ltd     YouTube –https://www.youtube.com/channel/UCgDn_igrQgdlj-maR6fWB0w

Alvopetro Energy Ltd.’s vision is to become a leading independent upstream and midstream operator in Brazil. Our strategy is to unlock the on-shore natural gas potential in the state of Bahia in Brazil, building off the development of our Caburé natural gas field and our strategic midstream infrastructure.

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this news release.

All amounts contained in this new release are in United States dollars, unless otherwise stated and all tabular amounts are in thousands of United States dollars, except as otherwise noted.

Abbreviations:bbls                        =              barrelsboepd                    =              barrels of oil equivalent (“boe”) per daybopd                      =              barrels of oil and/or natural gas liquids (condensate) per dayMMcf                     =              million cubic feetMMcfpd                 =              million cubic feet per day

BOE Disclosure. The term barrels of oil equivalent (“boe”) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet per barrel (6Mcf/bbl) of natural gas to barrels of oil equivalence is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. All boe conversions in this news release are derived from converting gas to oil in the ratio mix of six thousand cubic feet of gas to one barrel of oil.

Testing and Well Results. Data obtained from the 182-C2 well identified in this press release, including hydrocarbon shows, open-hole logging, net pay and porosities and initial testing data, should be considered to be preliminary until detailed pressure transient and other analysis and interpretation has been completed. Hydrocarbon shows can be seen during the drilling of a well in numerous circumstances and do not necessarily indicate a commercial discovery or the presence of commercial hydrocarbons in a well. There is no representation by Alvopetro that the data relating to the 182-C2 well contained in this press release is necessarily indicative of long-term performance or ultimate recovery. The reader is cautioned not to unduly rely on such data as such data may not be indicative of future performance of the well or of expected production or operational results for Alvopetro in the future.

Forward-Looking Statements and Cautionary Language. This news release contains “forward-looking information” within the meaning of applicable securities laws. The use of any of the words “will”, “expect”, “intend” and other similar words or expressions are intended to identify forward-looking information. Forward–looking statements involve significant risks and uncertainties, should not be read as guarantees of future performance or results, and will not necessarily be accurate indications of whether or not such results will be achieved. A number of factors could cause actual results to vary significantly from the expectations discussed in the forward-looking statements. These forward-looking statements reflect current assumptions and expectations regarding future events. Accordingly, when relying on forward-looking statements to make decisions, Alvopetro cautions readers not to place undue reliance on these statements, as forward-looking statements involve significant risks and uncertainties. More particularly and without limitation, this news release contains forward-looking information concerning potential hydrocarbon pay in the 182-C2 well, exploration and development prospects of Alvopetro and the expected timing of certain of Alvopetro’s testing and operational activities. The forward–looking statements are based on certain key expectations and assumptions made by Alvopetro, including but not limited to expectations and assumptions concerning testing results of the 183-B1 well and the 182-C2 well, equipment availability, the timing of regulatory licenses and approvals, the success of future drilling, completion, testing, recompletion and development activities, the outlook for commodity markets and ability to access capital markets, the impact of the COVID-19 pandemic, the performance of producing wells and reservoirs, well development and operating performance, foreign exchange rates, general economic and business conditions, weather and access to drilling locations, the availability and cost of labour and services, environmental regulation, including regulation relating to hydraulic fracturing and stimulation, the ability to monetize hydrocarbons discovered, expectations regarding Alvopetro’s working interest and the outcome of any redeterminations, the regulatory and legal environment and other risks associated with oil and gas operations. The reader is cautioned that assumptions used in the preparation of such information, although considered reasonable at the time of preparation, may prove to be incorrect. Actual results achieved during the forecast period will vary from the information provided herein as a result of numerous known and unknown risks and uncertainties and other factors. Although Alvopetro believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Alvopetro can give no assurance that it will prove to be correct. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on factors that could affect the operations or financial results of Alvopetro are included in our annual information form which may be accessed on Alvopetro’s SEDAR profile at www.sedar.com. The forward-looking information contained in this news release is made as of the date hereof and Alvopetro undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.

SOURCE Alvopetro Energy Ltd.

Oil Producers Had a Great Year; They Could Repeat in 2023

Image Credit: Mike Mozart (Flickr)

Can Oil Companies Continue Their Outperformance?

If you predicted that oil prices would go up last year, you were correct. If you predicted they’d go down, you were also correct. I dare say that even with insight as to what was to come, many analysts would have had the timing completely reversed from what actually happened. Why? What caused the volatility? And most importantly, what can we learn from this to help us in 2023 and beyond? After all, in 2022, oil company Exxon increased in market value more than any other company in the S&P 500. It became the eighth largest with a 74.3% increase in share price, up from the 27th largest a year ago. In contrast, WTI Crude closed near its low for the year, the dynamics involved are certainly worth investor exploration.

Background

Twelve months ago, according to the Energy Information Administration (EIA) the price of West Texas Intermediate (WTI) crude oil was considered high at $75.99/bbl. WTI closed the year less than 6% higher at $80.47/bbl. But this is not indicative of the wild surprises in between. There are two events that had a major impact during those twelve months.

Russia’s late February invasion of its neighbor helped crude prices to shoot up above $120/bbl. Oil has only visited that level once before (2008). Very few could have expected this event, so the expectations leading up to the early months of 2022 were, at worst moderate price declines to moderate increases. Those expecting some price increases pointed to the ongoing supply shortfall related to the pandemic response. This is the period that surprised traders with oil on the way up. Then as it became evident the war would be prolonged and Europe and other regions would take steps to move away from Russia’s output, expectations were for further price increases. What was not anticipated was a massive release of oil from the U.S. Strategic Petroleum Reserves. Along with releases from reserves in other parts of the world, oil prices sank. But, fear of the European winter, lack of support from OPEC+, and anticipation of price caps on Russian oil creating a loss of supply had many talking about upward pressure by year-end. It has not materialized.

The Crude World Order (OPIC?)

What’s changed the expected results related to oil prices and even producer prices? First off, there was a level of unity never-before-experienced and organization among petroleum-importing countries among consuming nations. The pushback and, to some degree taking charge, by nations that are net consumers began in late Spring 2022 when 31 members of the International Energy Agency (IEA) decided to all release oil from reserves to quench demand and impact prices.

The Paris-based IEA promotes what it believes are beneficial energy situations for consumers. It had taken the lead on emergency measures before, but never with this much unity or on this scale.  The amount of reserves sold into the oil market amounts to less than 1%, but it is estimated to have shaved $20 or more off per barrel oil prices in the spring and summer. Brent crude, the international oil benchmark, hit its peak settlement value of $127.98 per barrel in March but had fallen below $100 by July. Recently it has been trading near $80.

Certainly, the drawdown on reserves which borrowed from the future will need to be replenished. Pulling from reserves is unsustainable and therefore limits bargaining power. Nations have pledged to return their reserves to a level deemed in line with national security (the U.S. has a 50-day reserve supply), but the timing is uncertain.

What is positive for consumers is the IEA has learned to stand firm and work together.

Why are Oil Company Stocks Outperformers?

Crude is roughly the same price now as it was at the beginning of last year. Yet, factors including conservation efforts and China Covid policies have caused limited demand growth. And despite favorable economics currently, energy companies have been slow to drill new wells. U.S. rig count, as reported by Baker Hughes, crept up to 779 rigs by the end of the year. This compares to a peak level of 1,600 in 2014.

So why, as mentioned earlier, are oil companies performing as tech companies did in 2021?

On the surface, one might think energy company stock prices would be weakening, but this isn’t the case there are other factors at play. Michael Heim, Senior Energy Analyst, at Noble Capital Markets, explains in his newly released Q4 2022 Energy Industry Report, “Operating cash flow has soared over the last two years, but capital expenditures have barely increased. The result has been a large increase in dividend payments, share repurchases, and debt reduction.” Heim’s report further explains that while capital expenditures lagged well behind, it is inaccurate to conclude that oil production has not increased. The Noble Capital Markets analyst explains, “…current production levels are above that during peak drilling periods in 2014. The implication is that drilling has become more productive. While drilling advances such as the use of horizontal drill and fracking in shale deposits may be old hat, it is worth noting that drillers have been refining drilling techniques for individual drilling locations.” Drillers are improving techniques, improving efficiencies and maximizing production per dollar spent. Heim also attributes some of the efficiencies to well recompletions, which he explains are less expensive to put in service.

Read the Noble Capital Markets Energy industry report here.

Take Away

The S&P index that tracks the Energy sector gained 53.8% last year. If you had had a crystal ball that told you about the events that would transpire, such as the European war, and oil returning to its starting place, it’s a rare investor that would expect the drillers/producers to increase over 50%. While all situations have their own circumstances, understanding why price action happened can provide greater preparedness to face the markets each year.

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Paul Hoffman

Managing Editor, Channelchek

Sources

https://www.iea.org/

https://oilprice.com/Energy/Energy-General/The-Fall-Of-Tesla-And-The-Rise-of-Exxon-Amid-The-Energy-Crisis.html

https://oilprice.com/Energy/Energy-General/The-Fall-Of-Tesla-And-The-Rise-of-Exxon-Amid-The-Energy-Crisis.html

https://www.forbes.com/sites/rrapier/2022/12/31/the-year-in-energy-prices/?sh=59b071fa5314

https://www.eia.gov/petroleum/weekly/

https://www.channelchek.com/news-channel/energy-industry-report-energy-stocks-resume-their-upward-trend-is-80-oil-the-new-norm