Tag: business

Cal/OSHA COVID-19 Regulations Will Likely Continue in 2023

The current Cal/OSHA COVID-19 Emergency Temporary Standard (ETS) expires at the end of 2022. But Cal/OSHA is not done with COVID-19 regulations. There is a Non-Emergency Regulation in process. The Standards Board recently published its proposed non-emergency regulation and announced a public hearing for September 15, 2022.

Though the proposal is a non-emergency regulation, the proposed text states the requirements would only remain in effect for two years, except for certain recordkeeping requirements.

Here are other highlights of the proposed regulation:

  • Directs employers to include COVID-19 procedures in their written Injury and Illness Prevention Program (IIPP) or as a separate document.

  • As part of an employer’s COVID-19 procedures, an employer must provide training to employees regarding COVID-19

  • Employers must have effective methods and procedures for responding to COVID-19 cases in the workplace such as exclusion and quarantine requirements.

  • Employers will still have certain notice requirements regarding positive cases in the workplace.

  • Face covering requirements shall still follow California Department of Public Health requirements

One notable omission from the proposed regulation is exclusion pay, which was a very contentious requirement under the ETS.

Article By Sean Paisan of Jackson Lewis P.C.

For more coronavirus legal news, click here to visit the National Law Review.

Jackson Lewis P.C. © 2022

5 Keys to SEC Compliance Success

The best way to avoid the scrutiny from the Securities and Exchange Commission (SEC) that can lead to significant legal liability is to strictly comply with all of the agency’s rules and regulations. Unfortunately, given the complexity of these regulations and the constantly changing legal landscape of securities laws, such as the Securities Act of 1933 and Securities Exchange Act of 1934, this is much easier said than done.

Here are five keys to SEC compliance.

1. Identify Your Particular Needs

It should be an obvious first step, but many compliance attorneys treat all clients the same and offer a one-size-fits-all approach to complying with the regulations promulgated by the Securities and Exchange Commission (SEC). While this might not be a terrible approach – so long as it is all-encompassing, it will keep your company in line with the SEC across the board – it can saddle your firm with concerns and extraneous internal rules that have no bearing on how you conduct business.

A great example is a cryptocurrency. The SEC is, belatedly, beginning to issue rules and regulations for financial firms that focus on and trade in Bitcoin and other cryptocurrencies. If your brokerage firm is not buying or selling securities in crypto-assets and has no plans to do so soon, then implementing compliance measures for cryptocurrency regulations has no benefit to your company. Those measures will, however, make the regulated securities professionals who work for your firm jump through pointless hoops in the ordinary course of their business.

Adopting a compliance strategy that more precisely meets your company’s needs will let your workers perform to their full capacity while still insulating your firm from legal liability or SEC scrutiny. It will just have to be updated if you choose to expand into new forms of securities trading.

2. Craft an All-Encompassing Compliance Strategy

Based on your firm’s precise regulatory needs, the next key to success is to come up with a compliance strategy that takes into account all of the SEC’s rules that could impact your company. Given the breadth of the SEC’s jurisdiction and the sheer number of regulations that it has put forth, this can take a while.

Once your firm’s legal requirements have been ascertained, the next step is to come up with ways that you can satisfy them during the day-to-day business activities at your firm. This is another reason why every compliance strategy should be tailored to your business – a compliance technique that works well and is easy for one firm may be onerous and inconvenient for another one.

As Dr. Nick Oberheiden, founding partner of the SEC compliance law firm Oberheiden P.C., often tells clients, “All SEC compliance measures should protect the securities firm from SEC liability. However, those measures should also be judged by how burdensome they are on the firm that is employing them. The least inconvenient method to adequately insulate your firm from liability is the best. Learning about a brokerage firm and understanding its strengths and weaknesses and its capabilities help compliance lawyers craft the best solutions for their clients. Unfortunately, one of the most common complaints that securities professionals have about attorneys is that they do not listen to their particular concerns. We strive to do better.”

3. Train, Train, and Retrain Your Workers

No compliance strategy is effective if it is not implemented. Training your employees and workers in the intricacies of the compliance strategy, explaining why it is important for them to follow it strictly, and describing the penalties for noncompliance is the next key to success.

Even here, though, it is not a matter of simply giving your employees a handbook of rules, policies, and procedures to memorize. Just like how the compliance strategy should be tailored to your firm, so too should the instruction materials be tailored to each type of worker at your company. While it can help to train non-regulated administrative staff how to detect the signs of financial misconduct or fraud, there is no reason to bog them down in the details of SEC regulations that only pertain to traders – doing so can overload them with irrelevant information and make them lose sight of what they need to know.

It is also important to remember that training is not a one-time ordeal. New hires must be onboarded and taught the rules of internal compliance. Existing workers should be retrained to keep them apprised of any updates and to ensure that they remember their roles in the compliance protocol.

4. Keep Your Compliance Strategy Updated

Keeping your compliance strategy updated is also essential when it comes to compliance inspections. An out-of-date compliance protocol may still cover many of the bases for SEC compliance. However, there will be gaps in the compliance requirements that you will be unaware of, giving you a false sense of security.

The compliance strategy should not just be updated to account for new SEC regulations, though: It should also get updated whenever your brokerage firm branches out into new types of trading or adds a new kind of financial service to its portfolio. With that new line of business will likely come new SEC regulations to abide by.

5. Audit Yourself Regularly

Even if you have a good compliance program or plan, have trained workers to follow it, and keep the protocols updated, you are still moving forward blindly if you do not regularly conduct internal audits of your company to make sure that those compliance rules are working. Many compliance programs and strategies check off all of the boxes, only to lead to an SEC investigation that finds problems because a single worker did not actually understand how to correctly perform a job task.

These situations of compliance issues are incredibly frustrating. They can also be detected, identified, and corrected through a compliance strategy that includes internal auditing by outside counsel or an SEC compliance attorney with prior experience investigating securities fraud.

Article By Dr. Nick Oberheiden of Oberheiden P.C.

For more securities and SEC legal news, click here to visit the National Law Review.

Oberheiden P.C. © 2022

DOJ Forces $85M End to “Long-Running Conspiracy” to Suppress Poultry Wages

Three poultry processors and a consulting firm that circulated wage information among them have entered a consent decree with the Department of Justice to end a “long-running conspiracy to exchange information about wages and benefits for poultry processing plant workers and collaborate with their competitors on compensation decisions,” a violation of the Sherman Antitrust Act. The poultry companies — Cargill Inc. and Cargill Meat Solutions Corp., Sanderson Farms Inc., and Wayne Farms LLC – agreed to pay nearly $85 million. In addition to the payment, the producers must submit to antitrust monitoring for 10 years.

The decree brings a halt to the exchange of compensation information and deceptive conduct toward chicken growers designed to lower their compensation. The DOJ charged two of the poultry processors – Sanderson Farms, which was just acquired via joint venture between Cargill and Continental Grain Co., and Wayne Farms, owned by Continental – with violating the Packers and Stockyards Act. The companies engaged in deceptive practices via a “tournament system” which pit chicken growers against each other to determine their compensation. Jonathan Meng, meanwhile, president of the data firm Webber, Meng, Sahl & Company, is banned from the industry for his role as information broker for the producers.

Cargill is a privately held, multinational corporation based in Minnetonka, Minn. The corporation’s major businesses are trading, purchasing and distributing grain and other agricultural commodities. In 2021, Cargill generated revenue of about $134.4 billion. In the meat and poultry processing industry, Cargill’s $20 billion in revenue in 2021 put it in third place behind Tyson Foods Inc. ($43 billion) and JBS USA Holdings, Inc. ($39 billion) and one notch ahead of Sysco Corp. ($18 billion).

Just days before the settlement, Bloomberg Law reporter Dan Papsucn wrote, Sanderson Farms was acquired for $4.5 billion via joint venture between Cargill and Continental Grain Co. Wayne Farms was already owned by Continental. The acquisition combined the third and sixth-largest companies in U.S. chicken production to form the new Wayne-Sanderson Farms company. Before they were merged, Sanderson Farms and Wayne Farms annually were generating approximately $3.56 billion and $2.2 billion, respectively.

The DOJ’s investigation continues into the activities of several unnamed co-conspirators.  The government’s suit was filed in federal court in Maryland (U.S. v. Cargill Meat Solutions Corp., et al., No. 1:22-cv-01821 D. Md.).

Increased Federal Attention

The poultry industry case demonstrates that the antitrust law enforcers at DOJ, in addition to those at the Federal Trade Commission, remain dedicated to increasing competition in such concentrated labor markets. Worker mobility is something President Biden has promised to protect. FTC Chairwoman Lina Khan is considering new regulations to ban non-competes and to target them with enforcement actions, according to Wall Street Journal reporters Dave Michaels and Ryan Tracy.

Agreements entered without the cloak of legitimate competitive concerns by employers are called “naked” agreements. In 2016 DOJ and FTC jointly declared that naked wage-fixing or no-poaching agreements were per se illegal under antitrust laws. If the agreement is separate from or not reasonably necessary to achieve a larger legitimate collaboration between the employers, the agreement is deemed illegal without any inquiry into its competitive effects. Legitimate joint ventures (including, for example, appropriate shared use of facilities) are not considered per se illegal under antitrust laws. For these legitimate ventures the DOJ advocates the “rule of reason” or “quick-look analysis.” Also in 2016, DOJ said it would proceed with criminal actions against naked wage-fixing or no-poaching agreements.

Of course, support for the legitimacy of non-competes and no-poaching agreements splits along party lines. Sometimes the issue isn’t whether the agreements should be eliminated, but who should eliminate them. The question becomes: Is this the purview of the federal government or is it up to state legislatures?

Private Litigation

Private actions are another consideration for employers. Auto repair chain Jiffy Lube, which is owned by Shell Oil Company, recently agreed to pay $2 million to settle claims that it used illegal no-poaching agreements which prevented franchise owners from hiring current or recent employees of other Jiffy Lube franchises. The settlement will be shared among 1,250 hourly workers in the Philadelphia metropolitan area in Pennsylvania, New Jersey and Delaware.

According to the class action complaint, Jiffy Lube used these agreements to suppress wages and prevent workers from achieving better terms of employment. Employees had to wait six months after leaving one Jiffy Lube shop before attempting to work at another, according to the terms. Workers sued claiming this was a violation of the Sherman Antitrust Act.

The case was filed in U.S. District Court for the Eastern District of Pennsylvania (Victor Fuentes v. Royal Dutch Shell PLC, et al., Case No. 2:18-cv-05174, E.D. Pa.).

Employers Beware

As these cases demonstrate, many employers don’t realize (or may not care) that these types of arrangements can be considered anticompetitive or that their employment agreements can create substantial antitrust liabilities. In addition to public and private litigation, restrictive employment agreements can tank business deals. Imagine your M&A deal craters when a buyer discovers you have a no-poach agreement with competitors.  You might not have seen it as problematic until your prospective buyer walks away because of the risk and your once promising deal is over.

Employers and business owners who wish to protect themselves when employees leave for new positions need to be careful how they go about building their defenses because doing it wrong can mean both civil and criminal charges against corporations and individuals, as these cases illustrate. Critical questions need to be answered in employment agreements and business deals. Is the employer – such as a franchisor – trying to stop intramural poaching within its own system, effectively causing vertical restraint? Or is it trying to legitimately protect itself from losing employees to competitors, or horizontal restraint? These are questions best addressed by counsel with a sophisticated understanding of antitrust law, employment agreements, and mergers and acquisitions.

Article By Jennifer M. Oliver of MoginRubin

For more antitrust legal news, click here to visit the National Law Review.

© MoginRubin LLP

Federal Reserve Doubles Down on Oversight of Crypto Activities for Banks

The Federal Reserve Board (the “FRB”) issued Supervision and Regulation Letter 22-6 (“SR 22-6”), providing guidance for FRB-supervised banking organizations (referred to collectively herein as “FRB banks”) seeking to engage in activities related to cryptocurrency and other digital assets.  The letter states that prior to engaging in crypto-asset-related activities, such FRB banks must ensure that their activities are “legally permissible” and determine whether any regulatory filings are required.  SR 22-6 further states that FRB banks should notify the FRB prior to engaging in crypto-asset-related activities.  Any FRB bank that is already engaged in crypto-asset-related activities should notify the FRB promptly regarding the engagement in such activities, if it has not already done so.  The FRB also encourages state member banks to contact state regulators before engaging in any crypto-asset-related activity.

These requirements send a clear message to FRB banks and in fact to all banks that their crypto-asset related activities are considered to be risky and not to be entered into lightly.

Indeed, the FRB noted that crypto-asset-related activities may pose risks related to safety and soundness, consumer protection, and financial stability, and thus a FRB bank should have in place adequate systems, risk management, and controls to conduct such activities in a safe and sound manner and consistent with all applicable laws.

SR 22-6 is similar to guidance previously issued by the OCC and FDIC; in all cases, the agencies require banks to notify regulators before engaging in any kind of digital asset activity, including custody activities. The three agencies also released a joint statement last November in which they pledged to provide greater guidance on the issue in 2022.  Further, in an August 17, 2022 speech, FRB Governor Bowman stated that the FRB staff is working to articulate supervisory expectations for banks on a variety of digital asset-related activities, including:

  • custody of crypto-assets
  • facilitation of customer purchases and sales of crypto-assets
  • loans collateralized by crypto-assets, and
  • issuance and distribution of stablecoins by banking organizations

Interestingly, SR 22-6 comes a few days after a group of Democratic senators sent a letter to the OCC requesting that the OCC withdraw its interpretive letters permitting national banks to engage in cryptocurrency activities and a day after Senator Toomey sent a letter to the FDIC questioning whether it is deterring banks from offering cryptocurrency services.

Although past guidance already required banks to notify regulators of crypto activity, this guidance likely could discourage additional banks from entering into crypto-related activities in the future or from adding additional crypto services. In the end, it could have the unfortunate effect of making it more difficult for cryptocurrency companies to obtain banking services.

Article By Grant F. Butler, Jeremy M. McLaughlin, Anthony R.G. Nolan, and Judith E. Rinearson of K&L Gates

For more finance and banking legal news, click here to visit the National Law Review.

Copyright 2022 K & L Gates

CERCLA PFAS Designation Major Step Forward

On January 10, 2022, the EPA submitted a plan for a PFAS Superfund designation to the White House Office of Management and Budget (OMB) when it indicated an intent to designate two legacy PFAS – PFOA and PFOS – as “hazardous substances” under the Comprehensive Environmental Response, Compensation & Liability Act (CERCLA, also known as the Superfund law). The EPA previously stated its intent to make the proposed designation by March 2022 when it introduced its PFAS Roadmap in October 2021. Under the Roadmap, the EPA planned to issue its proposed CERCLA designation in the spring of 2022. On Friday, a CERCLA PFAS designation took a significant step forward when the OMB approved the EPA’s plan for PFOA and PFOS designation. This step opens the door for the EPA to put forth its proposed designation of PFOA and PFOS under CERCLA and engage in the required public comment period.

Any PFAS designation will have enormous financial impacts on companies with any sort of legacy or current PFOA and PFOS pollution concerns. Corporations, insurers, investment firms, and private equity alike must pay attention to this change in law when considering risk issues.

Opposition to CERCLA Designation

Since the EPA’s submission of its intent to designate PFOA and PFOS as hazardous substance to the OMB, the EPA has been met with industry pushback on the proposal. Three industries met with the OMB earlier in 2022 to explain the enormity of regulatory and cleanup costs that the industries would face with a CERCLA designation of PFOA and PFOS – water utilities, waste management companies, and the International Liquid Terminals Association. These industries in particular are concerned about bearing the burden of enormous cleanup costs for pollution that third parties are responsible for. Industries are urging the OMB and EPA to consider other ways to achieve regulatory and remediation goals aside from a CERCLA designation.

During an April 5, 2022 meeting of the Environmental Council of the States (ECOS), several states also expressed concerns regarding the impact that a CERCLA designation for PFAS types would have in their states and on their constituent companies. The state environmental leaders discussed with EPA representatives how the EPA would view companies in their states that fall into categories such as waste management and water utilities, who are already facing uphill battles in disposing of waste or sludge that contains PFAS.

Realizing that the EPA is likely set on its path to designate at least two PFAS as “hazardous substances”, though, industries are asking the EPA to consider PFAS CERCLA exemptions for certain industries, which would exempt certain industry types from liability under CERCLA. Industries are also pushing the EPA, OMB and the U.S. Chamber of Commerce to conduct a robust risk analysis to fully vet the impact that the designation will have on companies financially. The EPA is statutorily required to conduct a risk analysis as part of its CERCLA designation process, so it is likely that the EPA’s delay in issuing a proposed hazardous substance designation until it feels that adequate time has passed for its designation to survive the likely legal challenges that will likely follow the designation.

CERCLA PFAS Designation: Impact On Businesses

Once a substance is classified as a “hazardous substance” under CERCLA, the EPA can force parties that it deems to be polluters to either cleanup the polluted site or reimburse the EPA for the full remediation of the contaminated site. Without a PFAS Superfund designation, the EPA can merely attribute blame to parties that it feels contributed to the pollution, but it has no authority to force the parties to remediate or pay costs. The designation also triggers considerable reporting requirements for companies. Currently, those reporting requirements with respect to PFAS do not exist, but they would apply to industries well beyond just PFAS manufacturers.

The downstream effects of a PFOA and PFOS designation would be massive. Companies that utilized PFOA and PFOS in their industrial or manufacturing processes and sent the PFOA/PFOS waste to landfills or otherwise discharged the chemicals into the environment will be at immediate risk for enforcement action by the EPA given the EPA’s stated intent to hold all PFAS polluters of any kind accountable. Waste management companies should be especially concerned given the large swaths of land that are utilized for landfills and the likely PFAS pollution that can be found in most landfills due to the chemicals’ prevalence in consumer goods. These site owners may be the first targeted when the PFOA/PFOS designation is made, which will lead to lawsuits filed against any company that sent waste to the landfills for contribution to the cost of cleanup that the waste management company or its insured will bear.

Also of concern to companies are the re-opener possibilities that a CERCLA designation would result in. Sites that are or were previously designated as Superfund sites will be subject to additional review for PFOA/PFOS concerns. Sites found to have PFOA/PFOS pollution can be re-opened by the EPA for investigation and remediation cost attribution to parties that the EPA finds to be responsible parties for the pollution. Whether through direct enforcement action, re-opener remediation actions, or lawsuits for contribution, the costs for site cleanup could amount to tens of millions of dollars, of course depending on the scope of pollution.

Conclusion

Now more than ever, the EPA is clearly on a path to regulate PFAS contamination in the country’s water, land and air. The EPA has also for the first time publicly stated when they expect such regulations to be enacted. These regulations will require states to act, as well (and some states may still enact stronger regulations than the EPA). Both the federal and the state level regulations will impact businesses and industries of many kinds, even if their contribution to drinking water contamination issues may seem on the surface to be de minimus. In states that already have PFAS drinking water standards enacted, businesses and property owners have already seen local environmental agencies scrutinize possible sources of PFAS pollution much more closely than ever before, which has resulted in unexpected costs. Beyond drinking water, though, the EPA PFAS plan shows the EPA’s desire to take regulatory action well beyond just drinking water, and companies absolutely must begin preparing now for regulatory actions that will have significant financial impacts down the road.

Article By John Gardella of CMBG3 Law

For more energy and environmental legal news, click here to visit the National Law Review.

©2022 CMBG3 Law, LLC. All rights reserved.

Relief Arrives for Renewable Energy Industry – Inflation Reduction Act of 2022

On August 12, 2022, Congress passed the Inflation Reduction Act of 2022 (“Act” or “IRA”), a $400 billion legislative package containing significant tax and other governmental incentives for the energy industry, in particular the renewable energy industry. The bill will have an immediate impact on the wind and solar industries, along with other clean energy projects and businesses.

SUMMARY

The IRA is a slimmed down substitute for the Build Back Better bill resulting from a compromise with Senator Joe Manchin (D-WV), whose support was necessary for the bill to pass the Senate.

The IRA comes as welcome news to the renewable energy industry as important tax incentives for wind, solar and other renewable energy resources are set to expire or wind down. Existing law also did not provide any federal tax incentives for the rapidly growing stand-alone energy storage and clean hydrogen industries.

The IRA fixes that, and more. The Act extends the investment tax credit (ITC) for solar, geothermal, biogas, fuel cells, waste energy recovery, combined heat and power, small wind property, and microturbine and microgrid property for projects beginning construction before January 1, 2025. It also extends the production tax credit (PTC) for wind, biomass, geothermal, solar (which previously expired at the end of 2005), landfill gas, municipal solid waste, qualified hydropower, and marine and hydrokinetic resources for projects beginning construction before January 1, 2025. The IRA also allows taxpayers to include their interconnection costs as part of their eligible basis for the ITC.

The Act now allows the ITC to be taken for stand-alone energy storage (previously storage was only allowed an ITC if it was part of another project, e.g., solar). Other technologies are also benefitted from the IRA, including carbon capture and sequestration (CCS) (tax credit extended and modified), clean hydrogen (a new credit of up to $3.00 per kilogram of clean hydrogen produced), nuclear power (a new credit of up to 1.5c/kWh) and biofuel (existing credit extended).

The ITC and PTC now come with strings attached. To qualify for the restored 30% ITC and the 2.6c/kWh PTC (adjusted for inflation), projects must pay prevailing wages during construction and the first five years (in the case of the ITC) and 10 years (in the case of the PTC) of operation, while also meeting registered apprenticeship requirements. Projects that fail to satisfy the prevailing wage and apprenticeship requirements will only receive an ITC of 6% or a PTC of .3c/kWh (adjusted for inflation). The prevailing wage and apprenticeship requirements apply to employees of contractors and subcontractors as well as the company. These requirements are effective for projects that begin construction 60 days after the IRS issues additional guidance on this issue. Certain exceptions apply, including for certain small (less than 1 MW) facilities.

On the flip side, the Act includes enhancements that, in the case of the ITC, can increase the credit percentage if a project satisfies certain additional criteria. Bonuses are available for projects that (1) satisfy certain U.S. domestic content requirements (10%) or (2) are located in an “energy community” (10%) or an “environmental justice” area (10% or 20%). An “energy community” is defined as a brownfield site, an area which has or had significant employment related to oil, gas, or coal activities, or a census tract or any adjoining tract in which a coal mine closed after December 31, 1999, or in which a coal-fired electric power plant was retired after December 31, 2009. An “environmental justice” area is a low-income community or Native American land (defined in the Energy Policy Act of 1992) (10%) or a low-income residential building or qualified low-income economic benefit project (20%).

The Act also creates two new methods for monetizing the ITC, PTC, and certain other credits. Tax-exempt organizations will be permitted to elect a “direct pay” option in lieu of a tax credit. In a dramatic change that may have substantial impacts on renewable project finance, the Act permits most taxpayers to transfer the ITC, PTC, and certain other tax credits for cash.

For the first time, the Act includes a tax credit, known as the Advanced Manufacturing Production Credit, for companies manufacturing clean energy equipment in the U.S. such as PV cells, PV wafers, solar grade polysilicon, solar modules, wind energy components, torque tubes, structural fasteners, electrode active materials, battery cells, battery modules, and critical minerals.

The Act also contains major tax incentives, in the form of credits and enhanced deductions to spur electric and hydrogen-fueled vehicles, alternative fuel refueling stations, nuclear power, energy efficiency, biofuels, carbon sequestration and clean hydrogen. Additional grants are available for interregional and offshore wind and electricity transmission projects, including for interconnecting offshore wind farms to the transmission grid.

Additional detail regarding these provisions follow below.

KEY ENERGY PROVISIONS OF THE INFLATION REDUCTION ACT OF 2022

Investment Tax Credit (ITC)

The ITC is extended for projects beginning construction prior to January 1, 2025. The ITC starts at a base rate of 6%. The ITC increases to 30% if a project (1) pays prevailing wages during the construction phase and for the first five years of operation and (2) meets registered apprenticeship requirements. The ITC applies to solar, fuel cells, waste energy recovery, geothermal, combined heat and power, and small wind property, and is now expanded to include stand-alone energy storage projects (including thermal energy storage), qualified biogas projects such as landfill gas, electrochromic glass, and microgrid controllers. For microturbine property the base rate is 2%, which increases to 10% if the prevailing wage and apprenticeship requirements are met.

Projects under one megawatt (AC) and projects that begin construction prior to 60 days after the Secretary of the Treasury publishes guidance on the wage and registered apprenticeship requirements do not have to meet the prevailing wage and apprenticeship requirements to qualify for the 30% ITC.

PREVAILING WAGE REQUIREMENT

The new prevailing wage requirement is intended to ensure that laborers and mechanics employed by the project company and its contractors and subcontractors for the construction, alteration or repair of qualifying projects are paid no less than prevailing rates for similar work in the locality where the facility is located. The prevailing rate will be determined by the most recent rates published by the U. S. Secretary of Labor. Prevailing wages for the area must be paid during construction and for the first five years of operation for repairs or alterations once the project is placed in service. Failure to satisfy the standard will result in a significant penalty, including an 80% reduction in the ITC (i.e., an ITC of 6%), remittance of the wage shortfall to the underpaid employee(s) and a $5,000 penalty per failure. For intentional disregard of the requirement the penalty increases to three times the wage shortfall and $10,000 penalty per employee.

The prevailing wage requirement takes effect for projects that begin construction after December 31, 2022, but not before 60 days after the Secretary publishes its guidance. Projects under 1 MW (AC) are exempt from the requirement.

APPRENTICESHIP REQUIREMENT

For projects with four or more employees, work on the project by contractors and subcontractors must be performed by qualified apprentices for the “applicable percentage” of the total number of labor hours. A qualified apprentice is an employee who participates in an apprenticeship program under the National Apprenticeship Act. The applicable percentage of labor hours phases in and is equal to 10% of the total labor hours for projects that begin construction in 2022, 12.5% for projects beginning construction in 2023, and 15% thereafter. Similar penalties to the prevailing wage penalties apply for failure to satisfy the apprenticeship requirement. A “good faith” exception applies where an employer attempts but cannot find apprentices in the project’s locality.

The apprenticeship requirement takes effect for projects that begin construction after December 31, 2022, but not before 60 days after the Secretary publishes its relevant guidance. Projects under 1 MW (AC) are exempt from the requirement.

Credit Enhancements

Domestic Content. Assuming a project meets the prevailing wage and apprenticeship requirements, a qualifying project can earn a 10% ITC bonus (i.e., bringing the ITC to 40%), if it satisfies the domestic content requirement. To satisfy the domestic content requirement a project must use 100% U.S. steel and iron, and an “adjusted percentage” of the total costs of its manufactured components with products that are mined, produced or manufactured in the U.S. The applicable percentage for projects other than for offshore wind facilities initially is set at 40%, increasing to 45% in 2025, 50% in 2026, and 55% in 2027. For offshore wind facilities the adjusted percentage initially is 20%, and phases up to 27.5% in 2025, 35% in 2026, 45% in 2027, and 55% in 2028 and after. The initial domestic content bonus for projects failing to meet the prevailing wage and apprenticeship requirement is 2%, which percentage similarly phases up.

Two exceptions exist to the domestic content requirement: (1) if the facility is less than 1 MW (AC) and (2) if satisfying the requirement will increase the overall cost of construction by more than 25 percent, or if the relevant products are not produced in the U.S. in sufficient and reasonably available quantities or quality. Under these circumstances, the unavailability of the product is counted 100% against the adjusted percentage, that is, the adjusted percentage is calculated as if 100% U.S. content was supplied for the unavailable items.

The domestic content bonus is only available for projects placed in service after December 31, 2022.

Energy Community Bonus. A project can earn an additional 10% ITC bonus if it is built in an energy community. An energy community is defined as (a) a brownfield site (as defined under CERCLA), (b) an area that has or had significant employment related to the coal, oil, or gas industry and has an unemployment rate at or above the national average, or (c) a census tract or adjoining tract in which a coal mine closed after December 31, 1999 or a coal-fired electric power plant was retired after December 31, 2009.

The Energy Community Bonus is only available for projects placed in service after January 1, 2023.

Environmental Justice. An additional 10% and, in some cases, 20% ITC bonus, is available for solar and wind projects of 5 MW AC or less where the project is located in, or services, a low-income community. The environmental justice bonus is limited to a maximum of 1.8 gigawatts of solar and wind capacity in each of calendar years 2023 and 2024, for which a project must receive an allocation from the U.S. Treasury Secretary. The 10% bonus is for projects located in a low-income community or on Native American land (defined in the Energy Policy Act of 1992). The 20% bonus is available for projects that are part of a qualified low-income residential building project or a qualified low-income economic benefit project. A qualified low-income residential project is a residential rental building that participates in a housing program such as those covered under the Violence Against Women Act of 1994, a housing assistance program administered by the Department of Agriculture under the Housing Act of 1949, a housing program administered under the Native American Housing Assistance and Self-Determination Act of 1996, or similar affordable housing programs. A qualified low-income economic benefit project is one where at least 50% of the households have income at less than 200% of the poverty line or at less than 80% of the area’s median gross income.

Storage projects installed in connection with a solar project also qualify for the environmental justice bonus, but not stand-alone storage projects. A project receiving an allocation for the environmental justice credit must be placed in service within four years of the date it receives the allocation.

Stand-Alone Storage. The Act now provides a tax credit for stand-alone energy storage projects. To qualify, the storage project must be capable of receiving, storing and delivering electrical energy and have a nameplate capacity of at least 5 kWh. Thermal storage projects and hydrogen storage projects qualify under the new provision. Like the ITC for other technologies, the base ITC for stand-alone storage is 6%, and increases to 30% for projects that satisfy the prevailing wage and apprenticeship requirements or if they are placed into service prior to 60 days after the Treasury Secretary issues guidance on prevailing wage and apprenticeship standards.

Interconnection Equipment. Qualifying projects under 5 MW (AC) now may claim an ITC on their interconnection costs. The credit applies even if the interconnection facilities are owned by the interconnecting utility, so long as they were paid for by the taxpayer. This is not a stand-alone tax credit, but rather an additional cost added to a project’s basis eligible for the ITC.

Production Tax Credit (PTC)

The Act extends the production tax credit (PTC) for projects beginning construction before January 1, 2025. The PTC is set at an initial Base Rate of .3c/kwh. Like the ITC, the credit increases to 1.5c/kwh for projects satisfying the prevailing wage and apprenticeship requirements. The 1.5 c/kWh, with the inflationary adjustment provided for the PTC, brings the PTC up to 2.6c/kWh in 2022. In addition to wind projects, the PTC is available to solar, closed-loop and open-loop biomass, geothermal, landfill gas, municipal solid waste, qualifying hydropower, and marine and hydrokinetic facilities. Thus, solar projects may now choose either the PTC or the ITC. They cannot receive both.

CREDIT ENHANCEMENTS

Like the ITC, a project can receive an enhanced PTC similar in degree to those under the ITC for satisfying the domestic content, energy community and/or environmental justice requirements. For projects meeting the prevailing wage and apprenticeship requirements the increase for each applicable bonus is generally 10% of the underlying credit and, for projects failing to satisfy those requirements, 2%.

Clean Electricity Investment Tax Credit

The Act creates a new clean electricity tax credit (ITC and PTC) that replaces the existing ITC and PTC once they phase out at the end of 2024. The successor ITC/PTC is technology neutral. Any project producing electricity can qualify for the tax credit if its greenhouse gas emissions rate is not greater than zero. The successor ITC is 30% and the PTC is 1.5c/kWh, escalated annually with inflation. The Clean Energy ITC/PTC will phase out the later of 2032 or when emission targets are achieved (i.e., the electric power sector emits 75% less carbon than 2022 levels). Once the target is reached, facilities will be able to claim a credit at 100% value in the first year, then 75%, then 50%, and then 0%.

Clean Hydrogen Production Credit

This Act for the first time provides a tax credit for qualifying clean hydrogen projects. The credit is available for clean hydrogen produced at a qualifying facility during the facility’s first 10 years of operation. The base credit amount is $0.60 per kilogram (kg) times the “applicable percentage,” adjusted annually for inflation. For projects meeting the prevailing wage and apprenticeship requirements the credit amount is five times that base amount, or $3.00/kg times the applicable percentage, adjusted annually for inflation.

The applicable percentage for hydrogen projects achieving a lifecycle greenhouse gas emissions rate of less than 0.45 kilograms of carbon dioxide equivalent (CO2e) per kg is 100%. The applicable percentage falls to 33.4% for hydrogen projects with an emissions rate between .45kg and 1.5kg, and to 25% for hydrogen projects with an emissions rate between 1.5 kg and 2.5 kg. For hydrogen projects with a lifecycle greenhouse gas emissions rate between 4 kg and 2.5 kg of CO2e per kg, the applicable percentage is 20%.

To qualify for the credit, the facility must begin construction before January 1, 2033. Facilities existing before January 1, 2023 can qualify for a credit based on the date that modifications to their facility required to produce clean hydrogen are placed into service. Taxpayers may also claim the PTC for electricity produced from renewable resources by the taxpayer if the electricity is used at a clean hydrogen facility to produce qualified clean hydrogen. The Direct Pay option, discussed below, is available for clean hydrogen projects.

Taxpayers can elect to claim the ITC in lieu of the clean hydrogen production credit. However, taxpayers claiming the clean hydrogen credit cannot also claim a tax credit for carbon capture under Section 45Q, and vice versa.

Carbon Capture and Sequestration (CCS) Credit

Under prior law, industrial carbon capture or direct air capture (DAC) facilities that began construction by December 31, 2025, could qualify for the Section 45Q tax credit for carbon oxide sequestration. This credit could be claimed for carbon oxide captured during the 12-year period following the facility being placed in service. The per metric ton tax credit for geologically sequestered carbon oxide was set to increase to $50 per ton by 2026 ($35 per ton for carbon oxide that is reused, such as for enhanced oil recovery) and adjusted for inflation thereafter.

The Act extends the deadline for construction to January 1, 2033 and increases the credit amount. The base credit amount for CCS is $17 per metric ton for carbon oxide that is captured and geologically sequestered, and $12 per metric ton for carbon oxide that is reused. For facilities that meet the prevailing wage and apprenticeship requirements during construction and for the first 12 years of operation, the credit amounts are $85 per ton and $60 per ton, respectively.

The credit amount for carbon oxide captured using DAC and geologically sequestered is also increased under the Act to a base rate of $36 per metric ton, and to $180 per metric ton for projects that meet prevailing wage and apprenticeship requirements. The rates are indexed for inflation beginning in 2026.

The Act reduces the minimum plant size required to qualify for the credit:  from 100,000 to 1,000 tons per year for DAC; from 500,000 to 18,750 metric tons per year for electric generating facilities paired with qualifying CCS equipment, and from 25,000 to 12,500 metric tons per year for any other facility. A CCS project paired with an electric generating unit will be required to capture at least 75% of unit (not facility) CO2 production.

Advanced Energy Project Credit

The Act provides a 30% credit for investments in projects that re-equip, expend, or establish certain domestic manufacturing or industrial facilities to support the production or recycling of renewable energy property. Examples of such facilities include those producing or recycling components for:

  • Energy storage systems and components;
  • Grid modernization equipment or components;
  • Equipment designed to remove, use, or sequester carbon oxide emissions;
  • Equipment designed to refine, electrolyze, or blend any fuel, chemical, or product which is renewable or low-carbon and low-emission;
  • Property designed to produce energy conservation technologies (residential, commercial and industrial);
  • Electric or fuel-cell vehicles, including for charging and refueling infrastructure;
  • Hybrid vehicles weighing less than 14,000 pounds and associated technologies, components, or materials;
  • Re-equipping industrial and manufacturing facilities to reduce their greenhouse gas emissions by at least 20%;
  • Re-equipping, expanding, or establishing an industrial facility for the processing, refining or recycling of critical materials.

Projects not satisfying the prevailing wage and apprenticeship requirements will only receive the base ITC credit of 6%.

The Act makes $10 billion available for qualifying advanced energy projects. Of that amount, at least $4 billion must be allocated to projects located in energy communities. The Treasury Secretary will establish a program to award credits to qualifying advanced energy projects. Applicants awarded credits will have two years to place the property in service. The provision goes into effect on January 1, 2023.

Advanced Manufacturing Production

The Act creates a new production tax credit that can be claimed for the domestic production and sale of qualifying solar and wind components, such as inverters, battery components and critical minerals needed to produce these components.

Credits for solar components include:

  • for thin film photovoltaic cell or crystalline photovoltaic cell, 4 cents per DC watt of capacity;
  • for photovoltaic wafers, $12 per square meter;
  • for solar grade polysilicon, $3 per kilogram;
  • for polymeric backsheet, 40 cents per square meter; and
  • for solar modules, 7 cents per DC watt of capacity.

For wind energy components, if the component is an offshore wind vessel, the credit is equal to 10% of the sales price of the vessel. Otherwise, the credits for various wind components vary as set forth below, which amount is multiplied by the total rated capacity of the completed wind turbine on a per watt basis for which the component is designed.

The applicable amounts for wind energy components are:

  • 2 cents for blades
  • 5 cents for nacelles
  • 3 cents for towers
  • 2 cents for fixed platform offshore wind foundations
  • 4 cents for floating platform offshore wind foundations
  • for torque tubes and longitudinal purlin, $0.87 per kg
  • for structural fasteners, $2.28 per kg
  • for inverters, the credit is an amount multiplied by the inverter’s AC capacity, with different types of inverters eligible for specified credit amounts ranging from 1.5 cents to 11 cents per watt
  • for electrode active materials, the credit is 10% of the production cost
  • for battery cells the credit is $35 per kilowatt hour of battery cell capacity. Battery modules qualify for a credit of $10 per kilowatt hour of capacity (or $45 in the case of a battery module which does not use battery cells).

A 10% credit is also available for the production of critical minerals. Critical minerals include aluminum, antimony, barite, beryllium, cerium, cesium, chromium, cobalt, dysprosium, europium, fluorspar, gadolinium, germanium, graphite, indium, lithium, manganese, neodymium, nickel, niobium, tellurium, tin, tungsten, vanadium and yttrium.

For purposes of the credits for battery cells and modules, to qualify the capacity-to-power ratio cannot exceed 100:1. The term ‘capacity-to-power ratio’ means the ratio of the capacity of the cell or module to the maximum discharge amount of the cell or module.

The advanced manufacturing credit phases out for components sold after December 31, 2029. Components sold in 2030 are eligible for 75% of the full credit amount. Components sold in 2031 and 2032 are eligible for 50% and 25% of the full credit amount, respectively. No credit is available for components sold after December 31, 2032. The phase-out does not apply to the production of critical minerals.

DIRECT PAY

The Act contains a valuable cash payment option that allows certain organizations to treat certain tax credit amounts including, among others, the ITC, PTC, clean hydrogen, and carbon capture credits, as payments of tax and then receive a refund for that tax that is deemed paid. Under the so-called “direct pay” option, in lieu of receiving a tax credit, an eligible entity will be treated as if it had paid taxes in the amount of the credit, for which it can then receive a cash refund. Entities eligible for the direct pay option include tax-exempt organizations, state and local governments, Indian tribes (as defined in the Act), the Tennessee Valley Authority, and any Alaska Native Corporation. The direct pay option is subject to an annual election and must be claimed by a partnership or S corporation rather than its partners or S corporation shareholders. Refunds under the direct pay provisions are treated the same as tax credits for purposes of basis reduction, depreciation rules, and recapture.

For qualifying facilities electing direct pay that do not meet the domestic content requirements, a reduction applies for projects beginning construction in 2024 (90%) and 2025 (85%). Thereafter, the direct pay option will not be available for projects that do not satisfy the domestic content requirement.

TRANSFERRABLE CREDITS

The IRA allows eligible taxpayers that do not elect the direct pay option to transfer certain credits to unrelated taxpayers including, among others, the ITC, PTC, clean hydrogen, and carbon capture credits. The transferred credit must be exchanged for cash. Credits may only be transferred once. Carryforwards or carrybacks are not transferable. Payments made to the transferor of the credit are not taxable to the transferor, nor is the payment by the transferee to the transferor deductible to the transferee.

The credit period for transferred credits is 23 years (including three years for carrybacks). The credit must be used in earliest possible year of transferee. A 20% penalty may apply for both direct payments and transfers where excessive payments have occurred.

Zero Emission Nuclear Power Production Credit

The Act includes a new PTC for the production of electricity from an existing nuclear facility that was placed in service before the date of enactment of the Act. To qualify, the electricity from the facility must be produced and sold to an unrelated person after December 31, 2023. The credit terminates on December 31, 2032. The base PTC amount is 3 cents per kWh, but is increased five times if wage and apprenticeship requirements are met (to 1.5 cents per kWh), in each case adjusted annually for inflation and reduced by a reduction amount to the extent electricity from the plant is sold at a price over $0.025/kWh.

Electric Vehicles and Hydrogen-Fueled Cars

The Act includes a $7,500 credit for taxpayers purchasing new electric vehicles and a $4,500 tax credit for used ones. The Act eliminates the previous “per-manufacturer” limits that applied to the new vehicle credit, but imposes new domestic content and assembly requirements, as well as caps on the retail price of new vehicles, and the income of the taxpayers purchasing the vehicle.

The Act also sets aside financing and credits to promote electric vehicle manufacturing. It calls for $2 billion in grants to help convert existing auto manufacturing factories into ones that make electric vehicles and $20 billion of loans for new clean vehicle manufacturing facilities. The Act extends the credits to hydrogen-fueled cars in addition to EVs.

Alternative Fuel Refueling Property Credit

The Act revives the expired credit for alternative fuel refueling property (i.e., electric vehicle chargers), allowing it for property placed in service before December 31, 2032. The base credit is 6% of the cost of property, and is increased to 30% if wage and apprenticeship requirements are met. The previous $30,000 cap is also increased to $100,000.

OFFSHORE WIND

The IRA puts in place a 10-year window in which a lease for offshore wind development cannot be issued unless an oil and gas lease sale has also been held in the year prior and is not less than 60 million acres. The Act also withdraws the Trump administration’s moratorium on offshore wind leasing in the southeastern U.S. and eastern Gulf of Mexico.

GREEN BANK

The Act includes $27 billion toward a clean energy technology accelerator to support deployment of emission-reduction technologies, especially in disadvantaged communities. The EPA Administrator would be permitted to disburse $20 billion to “eligible recipients,” which are defined as non-profit green banks that “provide capital, including by leveraging private capital, and other forms of financial assistance for the rapid deployment of low- and zero-emission products, technologies, and services.

Clean Fuel Production Credit

The Act creates a new tax credit for domestic clean fuel production starting in 2025 and expires for transportation fuels sold after December 31, 2027. The tax credit is calculated as the applicable amount multiplied by the emissions factor of the fuel. The base credit is $0.20 per gallon of transportation fuel produced at a qualified facility and sold, which increases to $1.00 if prevailing wage requirements are met. The base credit is $0.35/gallon for sustainable aviation fuel, $1.75 if labor and wage requirements are satisfied. The emissions factor of the fuel may reduce the credit amount. The credits are adjusted for inflation. The credit cannot be claimed if other clean fuel credits are claimed, including clean hydrogen production.

Article By Kris J. Eimicke and Merrill Kramer of Pierce Atwood LLP

For more energy and environmental legal news, click here to visit the National Law Review.

©2022 Pierce Atwood LLP. All rights reserved.

EPA Updates Safer Chemical Ingredients List, Adding 22 Chemicals and Changing the Status of One Chemical

The U.S. Environmental Protection Agency (EPA) announced on August 11, 2022, that it updated the Safer Chemical Ingredients List (SCIL), “a living list of chemicals by functional-use class that EPA’s Safer Choice program has evaluated and determined meet the Safer Choice Standard.” EPA added 22 chemicals to the SCIL. EPA states that to expand the number of chemicals and functional-use categories on the SCIL, it encourages manufacturers to submit their safer chemicals for review and listing on the SCIL. In support of the Biden Administration’s goals, the addition of chemicals to the SCIL “incentivizes further innovation in safer chemistry, which can promote environmental justice, bolster resilience to the impacts of climate change, and improve water quality.” According to EPA, chemicals on the SCIL “are among the safest for their functional use.”

EPA also changed the status for one chemical on the SCIL and will remove the chemical from the list in one year “because of a growing understanding of the potential health and environmental effects.” According to EPA, the chemical was originally listed on the SCIL based on data from a closely related substance that EPA marked with a grey square earlier this year. EPA’s process for removing a chemical from the SCIL is first to mark the chemical with a grey square on the SCIL web page to provide notice to chemical and product manufacturers that the chemical may no longer be acceptable for use in Safer Choice-certified products. A grey square notation on the SCIL means that the chemical may not be allowed for use in products that are candidates for the Safer Choice label, and any current Safer Choice-certified products that contain this chemical must be reformulated unless relevant health and safety data are provided to justify continuing to list the chemical on the SCIL. EPA states that the data required are determined on a case-by-case basis. In general, data useful for making such a determination provide evidence of low concern for human health and environmental impacts. Unless information provided to EPA adequately justifies continued listing, EPA then removes the chemical from the SCIL 12 months after the grey square designation.

According to EPA, after this update is made, there will be 1,055 chemicals listed on the SCIL. EPA is committed to updating the SCIL with safer chemicals on a regular basis. EPA states that the SCIL is a resource that can help many different stakeholders:

  • Product manufacturers use the SCIL to help make high-functioning products that contain safer ingredients;
  • Chemical manufacturers use the SCIL to promote the safer chemicals they manufacture;
  • Retailers use the SCIL to help shape their sustainability programs; and
  • Environmental and health advocates use the SCIL to support their work with industry to encourage the use of the safest possible chemistry.

EPA’s Safer Choice program certifies products containing ingredients that have met the program’s rigorous human health and environmental safety criteria. The Safer Choice program allows companies to use its label on products that meet the Safer Choice Standard. The EPA website contains a complete list of Safer Choice-certified products.

Article By Lynn L. Bergeson and Carla N. Hutton of Bergeson & Campbell, P.C.

For more environmental legal news, click here to visit the National Law Review.

©2022 Bergeson & Campbell, P.C.

How to Practice Law in a Different State

There are plenty of benefits to being a multi-state lawyer.  Besides the most obvious advantage which is expanding your client base, it can also be practical when you live near a border between two different states. So, if you find yourself asking how to practice law in multiple states, you’re certainly not the first.  

In this article, we’ll detail how to become a multijurisdictional lawyer as well as some of the perks and drawbacks involved.

The Benefits of Practicing Law in Two or More States

Greater Client Base

It’s understandably appealing to be able to take on clients in different states.  It’s economically advantageous to generate more business in multiple locations.  Not to mention one state may have more demand for a certain practice area than another which can be practical for tapping into your niche market.

Furthermore, you may have clients that need representation in different states who don’t want to have to hire multiple lawyers.  Being able to offer all-in-one legal services can give you an edge over the competition. Of course, it goes without saying that you’ll need to allocate a bigger law firm marketing budget to market in not just one but multiple states. Or, just be more savvy with marketing strategies, such as familiarizing yourself with email marketing for law firms.

Greater Flexibility

Life events can spring up suddenly, forcing lawyers to relocate to a different state. Some states may only offer bar exams as little as twice a year, and as such, it can cause a significant delay before being able to accept clients. For many lawyers, anticipating the possibility of relocation without the worry of having to lose a second of work is an important advantage. So, ensuring they can practice anywhere is a nice added security to their business.

Ethical Responsibilities of Practicing Law In Multiple States

As more and more lawyers are working remotely since the onset of COVID, many are  accepting clients in other states.  Unfortunately, in many cases, these lawyers are violating the rules.

Rule 5.5 of the American Bar Association Model Rules of Professional Conduct states that lawyers may not practice in jurisdictions where they are not admitted. The consequences of violating these rules can range from a fine to disbarment depending on the gravity of the violation.   That being said, there are some exceptions to this rule.

For example, a licensed attorney may provide legal services temporarily in a different jurisdiction as long as they are associated with a lawyer who is admitted in that state.

How to Practice Law In Multiple States

Check For States That Offer Reciprocity

Some states offer reciprocity if you meet certain conditions.  Usually, these conditions depend on the amount of time you’ve been practicing and they may consider you eligible to practice in their state depending on the state bar that you’ve already passed.

It’s important to note, however, that you should never assume that just because a state offers reciprocity, you’ll be qualified.  It’s always important to contact the reciprocity state bar to ensure you are up to date with the latest policies otherwise you could risk serious disciplinary consequences.

Take the Uniform Bar

You might need to brush up on your legal education to retake the Uniform Bar Exam. The  Uniform Bar exam, also known as UBE, is a version of the bar exam that lets you practice between states with greater ease.  It’s important to note, however, that each state has its own bar admission requirements for the examination, and the passing score may vary by state. So, although it can be a solution in some scenarios, it’s not a sure thing. This is certainly more convenient than taking New York State, North Carolina, or any other state’s bar exam each time.

Take The Bar Exam For The States You Want to Work In

The most practical way to practice in another state is to pass the bar for that state.  However, there are significant costs and challenges involved which may not be ideal for everyone, and taking the UBE or opting for a state that offers reciprocity is much more common.

Take on Federal Court Cases

In theory, if you’re allowed to practice law in any state then you should be able to do so out of state. Yet, there is still some debate around this topic, and it’s still possible to find yourself in hot water with the state bar if you take this route.

Is Getting Licensed in Multiple States Right For You?

In the big picture, it’s much more convenient to practice in one jurisdiction for your entire career.  Yet, lawyers looking to take their practice to the next level may choose to pursue the route of becoming a multi-state lawyer despite the challenges.

The good news is that thanks to advancements like the UBE and reciprocity laws (as well as advancements in law firm technology), practicing law in another state is much easier than it was 20 years ago.  Deciding whether to get licensed in multiple states will come down to your unique circumstances and above all, how much time you have on your hands.

Getting licensed out of state requires a time commitment and administrative pile-up that may be difficult depending on your firm’s current workload.  Putting in the work it takes to acquire additional state licenses will be much easier if your practice is streamlined with the help of modern legal technology like a CRM and client intake software.  Not only can you access your firm from wherever you are thanks to cloud technology, but automation can help you stay on top of your most important tasks, and put your firm on autopilot while you’re focusing on passing the bar in another state.

FOOTNOTES

Shari Davison,  Reciprocity: What States Can You Practice Law?
https://www.onbalancesearch.com/reciprocity-what-states-can-you-practice-law/

Richard J. Rosensweig, Unauthorized Practice of Law: Rule 5.5 in the Age of COVID-19 and Beyond August 12, 2020
https://www.americanbar.org/groups/litigation/committees/ethics-professionalism/articles/2020/unauthorized-practice-of-law-rule-55-in-the-age-of-covid-19-and-beyond/

Article By Sarah Bottorff of Lawmatics

For more business of law legal news, click here to visit the National Law Review.

©2022 — Lawmatics

Tillis Bill Tries to Fix Section 101

This recently introduced bill would replace section 101 with a lot of text. The commentators are all commentating, but I have yet to read whether or not the “outlaw” status of claims to diagnostic methods—led by varying interpretations of Mayo v. Prometheus—has been clearly lifted by this bill. Here are the relevant parts, at least setting up the discussion on this point.

Section 101. Patent Eligibility

(a) IN GENERAL—Whoever [post- Thaler v. Vidal, we know that this must be a human being] invents or discovers any useful process, machine, manufacture, or composition of matter, or any useful improvement thereof, may obtain a patent therefore, subject only to the exclusions in section (b) and to the further conditions and requirements of this title.

(b) ELIGIBILITY EXCLUSIONS.—

(1) IN GENERAL.—Subject to paragraph (2), a person may not obtain a patent for any of the following, if claimed as such:

***

(B) A process that—

          ***

(iii) occurs in nature wholly independent of, and prior to, any human activity.

(C) An unmodified human gene, as that gene exists in the human body.

(D) An unmodified natural material, as that material exists in nature.

(2)  CONDITIONS.—

 ***

(B) HUMAN GENES AND NATURAL MATERIALS.—For the purposes of subparagraphs (C) and (D) of paragraph (1), a human gene or natural material that is isolated, purified, enriched, or otherwise altered by human activity, or that is otherwise employed in a useful invention or discovery, shall not be considered to be unmodified.

(c) ELIGIBILITY

(1) IN GENERAL.—In determining whether, under this section, a claimed invention is eligible for a patent, eligibility shall be determined

(A) By considering the claimed invention as a whole and without discounting or disregarding any claim element; and

(B) Without regard to—

***

(ii) whether a claim element is known, conventional, routine, or naturally occurring

***

Well now, does this bill abrogate Mayo v. Prometheus and permit patents on diagnostic assays as simple as “If A, then B” (If assay indicates high homocysteine then diagnostic conclusion is low cobalamin)? Let’s start with a simple “If A, then B” claim, like the one in Athena (If autoantibodies to MuSK are detected, subject may be afflicted with MG). The presence of antibodies that bind to MuSK occurs in nature wholly independently and prior to any human activity. See, section I (B) (iii). So to be patentable, a process comprising the detection of the antibodies or of a MuSK-antibody complex in order to diagnose MG must fall within one of the “conditions” of the statute as set forth in 2(B).

The problem, and I hope it is not a big one, is that 2(B) does not mention “processes” employing “natural materials.” Applicants are left to argue that the anti-MuSK antibodies per se are altered by human activity, e.g., by binding to MuSK, and so are “modified.” They can also argue that the antibodies are employed in a useful discovery since they are the biomarker for MG. But, of course, the applicants wanted to claim a process, not just the biomarker detected by the assay.

Regarding diagnostics, is the key phrase “otherwise employed in a useful invention or discovery”? Of course, the argument is that the useful invention or discovery is the diagnostic process, from initial sampling to drawing a diagnostic conclusion. For years I have proposed that s. 101 bills on diagnostic clams need a sentence like, “A process includes recognition of the utility of a naturally occurring correlation.” In other words, you are not trying to patent the correlation itself, like “blood containing antibodies that bind to MuSK”. The necessary steps include both isolation and detection of the antibodies and recognition that their presence indicates something about the patient. (Note that Mayo did not invent the correlation between the level of the metabolites of the administered drug and the need to adjust the dose of the drug. Mayo took a known correlation and refined the optimal range of metabolite concentration that arose after administration of the “parent drug”. One could call this the recognition that an improved correlation could be reached, but nothing in the Tillis bill says that, apart from novelty, the invention needs to be improved over any earlier version or alternative. This draft of the bill needs some work but it is a valuable start to ending the s. 101 nightmare.

Article By Warren Woessner of Schwegman, Lundberg & Woessner, P.A.

For more intellectual property legal news, click here to visit the National Law Review.

© 2022 Schwegman, Lundberg & Woessner, P.A. All Rights Reserved.

Why More Than One Commodity May Not Be Commodities

A plural form of a noun usually implies a set having more than one member of the same type.  For example, a reference to “dogs” is understood to refer to more than one dog.  No one understands a reference to “dogs” to mean a dog, a cat and a mouse.  That is not necessarily the case, however, under the California Corporations Code.

Section 29005 of the Corporations Code defines “commodities” to mean “anything movable that is bought or sold”.  Section 29504 assigns a much broader definition to the singular term “commodity”:

“Commodity” means, except as otherwise specified by the commissioner by rule or order, any agricultural, grain, or livestock product or byproduct, any metal or mineral (including a precious metal set forth in Section 29515), any gem or gemstone (whether characterized as precious, semiprecious, or otherwise), any fuel (whether liquid, gaseous, or otherwise), any foreign currency, and all other goods, articles, products, or items of any kind.  However, the term “commodity” shall not include (a) a numismatic coin whose fair market value is at least 15 percent higher than the value of the metal it contains, or (b) any work of art offered or sold by art dealers, at public auction, or through a private sale by the owner of the work of art.

Putting these two definitions together, it is possible for a multiple items to be “commodities” even though a single item is not a “commodity”.  For example, a numismatic coin of the requisite value would not be a “commodity” even more than one such coin would meet the definition of “commodities”.   The explanation for these seemingly inconsistent definitions is that they are found in two different laws.  “Commodities” is defined in California’s Bucket Shop Law while “commodity” is defined in the California Commodity Law of 1990.

Article By Keith Paul Bishop of Allen Matkins Leck Gamble Mallory & Natsis LLP

For more corporate law legal news, click here to visit the National Law Review.

© 2010-2022 Allen Matkins Leck Gamble Mallory & Natsis LLP