Just Energy 6K Interim Condensed Consolidated Statements of Financial Position | JENGQ 10 Nov 21

Management’s discussion and analysis

– November 9, 2021

The following management’s discussion and analysis (“MD&A”) is a review of the financial condition and operating results of Just Energy Group Inc. (“Just Energy” or the “Company”) for the three and six months ended September 30, 2021. This MD&A has been prepared with all information available up to and including November 9, 2021. This MD&A should be read in conjunction with Just Energy’s unaudited Interim Condensed Consolidated Financial Statements (the “Interim Condensed Consolidated Financial Statements”) for the three and six months ended September 30, 2021. The financial information contained herein has been prepared in accordance with International Financial Reporting Standards (“IFRS”), as issued by the International Accounting Standards Board (“IASB”). All dollar amounts are expressed in Canadian dollars unless otherwise noted. Quarterly reports, the annual report and supplementary information can be found on Just Energy’s corporate website at www.investors.justenergy.com. Additional information can be found on SEDAR at www.sedar.com or on the U.S. Securities and Exchange Commission’s (“SEC”) website at www.sec.gov.

WEATHER EVENT AND CREDITOR PROTECTION FILINGS

In February 2021, the State of Texas experienced extremely cold weather (the “Weather Event”). The Weather Event led to increased electricity demand and sustained high prices from February 13, 2021 through February 20, 2021. As a result of the losses sustained and without sufficient liquidity to pay the corresponding invoices from the Electric Reliability Council of Texas, Inc. (“ERCOT”) when due, and accordingly, on March 9, 2021, Just Energy applied for and received creditor protection under the Companies’ Creditors Arrangement Act (Canada) (“CCAA”) from the Ontario Superior Court of Justice (Commercial List) (the “Ontario Court”) and under Chapter 15 (“Chapter 15”) in the United States from the Bankruptcy Court of the Southern District of Texas, Houston Division (the “Court Orders” or “CCAA Proceedings”). Protection under the Court Orders allows Just Energy to operate while it restructures its capital structure.

As part of the CCAA filing, the Company entered into a USD $125 million Debtor–In–Possession (“DIP Facility”) financing with certain affiliates of Pacific Investment Management Company (“PIMCO”). The Company entered into Qualifying Support Agreements with its largest commodity supplier and ISO services provider. The Company entered into a Lender Support Agreement with the lenders under its Credit Facility (for details refer to note 8(c) in the Interim Condensed Consolidated Financial Statements). The filings and associated USD $125 million DIP Facility arranged by the Company, enabled Just Energy to continue all operations without interruption throughout the U.S. and Canada and to continue making payments required by ERCOT and satisfy other regulatory obligations.

On September 15, 2021, the stay period under the CCAA Proceedings was extended by the Ontario Court to December 17, 2021.

On November 1, 2021, Generac Holdings Inc. (“Generac”) announced the signing of an agreement to acquire all of the issued and outstanding shares of ecobee Inc. (“ecobee”), including all of the ecobee shares held by the Company. The Company holds approximately 8% of the ecobee and at closing anticipates receiving approximately $61 million, comprised of approximately $18 million cash and $43 million of Generac stock. The Company can receive up to an additional approximate CAD $10 million in Generac stock over calendar 2022 and 2023, provided that certain performance targets are achieved by ecobee. Generac stock trades on the New York Stock Exchange under the symbol GNRC. The Company has designated these investments at fair value through profit and loss under the IFRS 9, “Financial Instruments” (“IFRS 9”). As a result of the above-mentioned transaction, a fair value gain of $29 million has been recorded in the Interim Condensed Consolidated Statement of Income in the three months ended September 30, 2021.

On November 3, 2021, the Company filed an application with the Ontario Court seeking an extension of the maturity date of the DIP Facility until September 30, 2022. The Company also requested that the stay period under the CCAA Proceedings be extended to February 17, 2022. The Ontario Court scheduled a hearing on November 10, 2021 to consider these matters.

As at September 30, 2021, in connection with the CCAA Proceedings, the Company identified $1,032.4 million of liabilities subject to compromise (see Note 1 in the Interim Condensed Consolidated Financial Statements). The Company also recorded Reorganization Costs (defined below in Key Terms) of $38.6 million in the six months ended September 30, 2021 (see Note 13 in the Interim Condensed Consolidated Financial Statements).

On September 15, 2021, the Ontario Court approved the Company’s request to establish a claims process to identify and determine claims against the Company and its subsidiaries that are subject to the ongoing CCAA Proceedings. As a result of the establishment of the claims process, additional claims may be made against the Company and ultimately determined that are not currently reflected in the Interim Condensed Financial Statements.

The Common Shares, no par value, of the Company (the “Common Shares”) are listed on the TSX Venture Exchange under the symbol “JE” and on the OTC Pink Market under the symbol “JENGQ”.

SECURITIZATION UNDER HOUSE BILL 4492

On June 16, 2021, Texas House Bill 4492 (“HB 4492”) became law in Texas. HB 4492 provides a mechanism for recovery of (i) ancillary service charges above USD $9,000/MWh during the Weather Event; (ii) reliability deployment price adders charged by ERCOT during the Weather Event; and (iii) amounts owed to ERCOT due to defaults of competitive market participants, which were subsequently “short–paid” to market participants, including Just Energy, (collectively, the “Costs”),incurred by various parties, including the Company, during the Weather Event, through certain securitization structures.

On July 16, 2021, ERCOT filed the request with the Public Utility Commission of Texas (the “Commission”) and on October 13, 2021, the Commission issued its final order (the “PUCT Order”). The ultimate amount of proceeds that Just Energy will receive has not been fully determined, as entities eligible to opt-out have until November 29, 2021 to decide pursuant to the PUCT Order. However, Just Energy anticipates that it will recover at least USD $100 million of Costs with such proceeds expected to be received in the fourth quarter of fiscal year 2022. The total amount that the Company may recover through the PUCT Order may change materially based on a number of factors, including the entities that decide to opt-out, the outcome of the dispute resolution process initiated by the Company with ERCOT, and any potential challenges to the PUCT Order. There is no assurance that the Company will be able to recover all of the Costs.

Forward–looking information

This MD&A may contain forward-looking statements, including, without limitation, statements with respect to the Company’s strategic investment in digital marketing, rebound of face-to-face retail channels following the impacts of the COVID-19 pandemic, navigating a challenging margin environment and working closely with the Company’s stakeholders towards a successful restructuring plan. These statements are based on current expectations that involve several risks and uncertainties which could cause actual results to differ from those anticipated. These risks include, but are not limited to, risks with respect to the ability of the Company to continue as a going concern; the final amount received by the Company with respect to the implementation of Texas House Bill 4492 to recover certain costs incurred during the Weather Event; the outcome of any invoice dispute with the Electric Reliability Council of Texas in connection with the Weather Event; the outcome of any potential litigation with respect to the Weather Event ; the outcome of the Company’s proceedings under the CCAA and similar legislation in the United States; the quantum of the financial loss to the Company from the Weather Event and its impact on the Company’s liquidity; the Company’s restructuring discussions with key stakeholders regarding the CCAA Proceedings and the outcome thereof; the impact of the evolving COVID-19 pandemic on the Company’s business, operations and sales; reliance on suppliers; uncertainties relating to the ultimate spread, severity and duration of COVID-19 and related adverse effects on the economies and financial markets of countries in which the Company operates; the ability of the Company to successfully implement its business continuity plans with respect to the COVID-19 pandemic; the Company’s ability to access sufficient capital to provide liquidity to manage its cash flow requirements; general economic, business and market conditions; the ability of management to execute its business plan; levels of customer natural gas and electricity consumption; extreme weather conditions; rates of customer additions and renewals; customer credit risk; rates of customer attrition; fluctuations in natural gas and electricity prices; interest and exchange rates; actions taken by governmental authorities including energy marketing regulation; increases in taxes and changes in government regulations and incentive programs; changes in regulatory regimes; results of litigation and decisions by regulatory authorities; competition; and dependence on certain suppliers. Additional information on these and other factors that could affect Just Energy’s operations or financial results are included in Just Energy’s annual information form and other reports on file with Canadian securities regulatory authorities which can be accessed through the SEDAR website at www.sedar.com on the U.S. Securities and Exchange Commission’s website at www.sec.gov or through Just Energy’s website at www.investors.justenergy.com.

Company overview

Just Energy is a retail energy provider specializing in electricity and natural gas commodities, energy efficient solutions, carbon offsets and renewable energy options to customers. Operating in the United States (“U.S.”) and Canada, Just Energy serves both residential and commercial customers, providing homes and businesses with a broad range of energy solutions

that deliver comfort, convenience and control. Just Energy is the parent company of Amigo Energy, Filter Group Inc. (“Filter Group”), Hudson Energy, Interactive Energy Group, Tara Energy and Terrapass.

Continuing operations overview

MASS MARKETS SEGMENT

The Mass Markets segment (formerly referred to as “Consumer Segment”) includes customers acquired and served under the Just Energy, Tara Energy, Amigo Energy and Terrapass brands. Marketing of the energy products of this segment is primarily done through digital and retail sales channels. Mass Market customers make up 74% of Just Energy’s Base Gross Margin (defined below in non–IFRS financial measures), which is currently focused on price–protected and flat–bill product offerings, as well as JustGreen products. To the extent that certain markets are better served by shorter–term or enhanced variable rate products, the Mass Markets segment’s sales channels offer these products.

Just Energy also provides home water filtration systems with its line of consumer product and service offerings through Filter Group.

COMMERCIAL SEGMENT

The Commercial segment includes customers acquired and served under Hudson Energy, as well as brokerage services managed by Interactive Energy Group. Hudson Energy sales are made through three main channels: brokers, door–to–door commercial independent contractors and inside commercial sales representatives. Commercial customers make up 26% of Just Energy’s Base Gross Margin. Products offered to Commercial customers range from standard fixed–price offerings to “one off” offerings, tailored to meet the customer’s specific needs. These products can be fixed or floating rate or a blend of the two, and normally have a term of less than five years. Gross margin per RCE for this segment is lower than it is for the Mass Markets segment, but customer acquisition costs and ongoing customer care costs per RCE are lower as well. Commercial customers also have significantly lower attrition rates than Mass Markets customers.

ABOUT JUST ENERGY’S PRODUCTS

Just Energy offers products and services to address customers’ essential needs, including electricity and natural gas commodities, energy efficient solutions, carbon offsets and renewable energy options as well as water quality and filtration devices to customers.

Electricity

Just Energy services various states and territories in U.S. and Canada with electricity. A variety of electricity solutions are offered, including fixed–price, flat–bill and variable–price products on both short–term and longer–term contracts. Most of these products provide customers with price–protection programs for the majority of their electricity requirements. Just Energy uses historical usage data for enrolled customers to predict future customer consumption and to help with long–term supply procurement decisions. Flat–bill products offer customers the ability to pay a fixed amount per period regardless of usage.

Just Energy purchases electricity supply from market counterparties for Mass Markets and Commercial customers based on forecasted customer aggregation. Electricity supply is generally purchased concurrently with the execution of a contract for larger Commercial customers. Historical customer usage is obtained from LDCs (as defined in key terms), which, when normalized to average weather, provides Just Energy with expected normal customer consumption. Just Energy mitigates exposure to weather variations through active management of the electricity portfolio and the purchase of options, including weather derivatives. Just Energy’s ability to successfully mitigate weather effects is limited by the degree to which weather conditions deviate from normal. To the extent that balancing electricity purchases are outside the acceptable forecast, Just Energy bears the financial responsibility for excess or short supply caused by fluctuations in customer usage. Any supply balancing not fully covered through customer pass–throughs, active management or the options employed may increase or decrease Just Energy’s Base Gross Margin (as defined below) depending upon market conditions at the time of balancing.

Natural gas

Just Energy offers natural gas customers a variety of products ranging from five–year fixed–price contracts to month–to–month variable–price contracts. Gas supply is purchased from market counterparties based on forecasted consumption. For larger Commercial customers, gas supply is generally purchased concurrently with the execution of a contract. Variable rate products allow customers to maintain flexibility while retaining the ability to lock into a fixed price at their discretion. Flat–bill products offer customers the ability to pay a fixed amount per period regardless of usage or changes in the price of the commodity.

The LDCs provide historical customer usage which, when normalized to average weather, enables Just Energy to purchase the expected normal customer consumption. Just Energy mitigates exposure to weather variations through active management of the gas portfolio, which involves, but is not limited to, the purchase of options, including weather derivatives. Just Energy’s ability to successfully mitigate weather effects is limited by the degree to which weather conditions deviate from normal. To the extent that balancing requirements are outside the forecasted purchase, Just Energy bears the financial responsibility for fluctuations in customer usage. To the extent that supply balancing is not fully covered through active management or the options employed, Just Energy’s Base Gross Margin may increase or decrease depending upon market conditions at the time of balancing.


Territory	Gas delivery method
Manitoba, Ontario, Quebec and Michigan	The volumes delivered for a customer typically remain constant throughout the year. Sales are not recognized until the customer consumes the gas. During the winter months, gas is consumed at a rate that is greater than delivery, resulting in accrued gas receivables, and, in the summer months, deliveries to LDCs exceed customer consumption, resulting in gas delivered in excess of consumption. Just Energy receives cash from the LDCs as the gas is delivered.
Alberta, British Columbia, Saskatchewan, California, Illinois, Indiana, Maryland, New Jersey, New York, Ohio and Pennsylvania	The volume of gas delivered is based on the estimated consumption and storage requirements for each month. The amount of gas delivered in the months of October to March is higher than in the months of April to September. Cash flow received from most of these markets is greatest during the fall and winter quarters, as cash is normally received from the LDCs in the same period as customer consumption.

JustGreen

Many customers have the ability to choose an appropriate JustGreen program to supplement their electricity and natural gas, providing an effective method to offset their carbon footprint associated with the respective commodity consumption.

JustGreen’s electricity products offer customers the option of having all or a portion of the volume of their electricity usage sourced from renewable green sources such as wind, solar, hydropower or biomass, via power purchase agreements and renewable energy certificates. JustGreen programs for gas customers involve the purchase of carbon offsets from carbon capture and reduction projects. Additional green products allow customers to offset their carbon footprint without buying energy commodity products and can be offered in all states and provinces without being dependent on energy deregulation.

Just Energy currently sells JustGreen electricity and gas in eligible markets across North America. Of all customers who contracted with Just Energy in the past year, 40% purchased JustGreen for some or all of their energy needs. On average, these customers elected to purchase 73% of their consumption as green supply. For comparison, as reported for the trailing 12 months ended September 30, 2020, 50% of Consumer customers who contracted with Just Energy chose to include JustGreen for an average of 93% of their consumption. As at September 30, 2021, JustGreen makes up 25% of the Mass Market electricity portfolio, compared to 22% in the year ago period. JustGreen makes up 17% of the Mass Market gas portfolio, compared to 17% in the year ago period.

Terrapass

Through Terrapass, customers can offset their environmental impact by purchasing high quality environmental products. Terrapass supports projects throughout North America and world–wide that destroy greenhouse gases, produce renewable energy and restore freshwater ecosystems. Each project is made possible through the purchase of carbon offsets, renewable energy credits and BEF Water Restoration Certificates®. Terrapass offers various purchase options for Mass Markets or Commercial customers, enabling businesses to incorporate seamless carbon offset options by providing marketing and product integration solutions.

Key terms

“6.5% convertible bonds” refers to the US$150 million in convertible bonds issued in January 2014, which were exchanged for Common Shares and a pro–rata portion of the Term loan as part of the September 2020 Recapitalization.

“6.75% $160M convertible debentures” refers to the $160 million in convertible debentures issued in October 2016, which were exchanged for Common Shares and its pro–rata allocation of the 7.0% $13M subordinated notes issued as part of the September 2020 Recapitalization.

“6.75% $100M convertible debentures” refers to the $100 million in convertible debentures issued in February 2018, which were exchanged for Common Shares and its pro–rata allocation of the 7.0% $13M subordinated notes issued as part of the September 2020 Recapitalization.

“8.75% loan” refers to the US$250 million non–revolving multi–draw senior unsecured term loan facility entered into on September 12, 2018. The 8.75% loan was exchanged for Common Shares and a pro–rata portion of the Term Loan as part of the September 2020 Recapitalization.

“Base Gross Margin per RCE” refers to the energy Base Gross Margin realized on Just Energy’s RCE customer base, including gains (losses) from the sale of excess commodity supply excluding the impacts of the Weather Event or Reorganization Costs.

“Commodity RCE attrition” refers to the percentage of energy customers whose contracts were terminated prior to the end of the term either at the option of the customer or by Just Energy.

“Customer count” refers to the number of customers with a distinct address rather than RCEs (see key term below).

“Failed to renew” means customers who did not renew expiring contracts at the end of their term.

“Filter Group financing” refers to the outstanding loan balance between Home Trust Company (“HTC”) and Filter Group. The loan bears an annual interest rate of 8.99%.

“LDC” means a local distribution company; the natural gas or electricity distributor for a regulatory or governmentally defined geographic area.

“Liquidity” means cash on hand.

“Maintenance capital expenditures” means the necessary property and equipment and intangible asset capital expenditures required to maintain existing operations at functional levels.

“Note Indenture” refers to the $15 million subordinated notes with a six–year maturity and bearing an annual interest rate of 7.0% (payable in kind semi–annually) issued in relation to the September 2020 Recapitalization, which have a maturity date of September 15, 2026. The principal amount was reduced through a tender offer for no consideration, on October 19, 2020 to $13.2 million.

“RCE” means residential customer equivalent, which is a unit of measurement equivalent to a customer using 2,815 m³ (or 106 GJs or 1,000 Therms or 1,025 CCFs) of natural gas on an annual basis or 10 MWh (or 10,000 kWh) of electricity on an annual basis, which represents the approximate amount of gas and electricity, respectively, used by a typical household in Ontario, Canada.

“Reorganization Costs” – means the amounts incurred related to the filings under the CCAA Proceedings. These costs include professional and advisory costs, key employee retention plan, contract terminations and prepetition claims, and other costs.

“Selling commission expenses” means customer acquisition costs amortized under IFRS 15, Revenue from contracts with customers, or directly expensed within the current period and consist of commissions paid to independent sales contractors, brokers and sales agents and is reflected on the Interim Condensed Consolidated Statements of Income as part of selling and marketing expenses.

“Selling non–commission and marketing expenses” means the cost of selling overhead, including digital marketing cost not directly associated with the costs of direct customer acquisition costs within the current period and is reflected on the Interim Condensed Consolidated Statements of Income as part of selling and marketing expenses.

“September 2020 Recapitalization” refers to the recapitalization transaction that the Company completed in September 2020.

“Strategic Review” means the Company’s formal review announced on June 6, 2019 to evaluate strategic alternatives available to the Company. The Company finalized the Strategic Review with the completed September 2020 Recapitalization.

“Term Loan” refers to the US$206 million senior unsecured 10.25% term loan facility entered into on September 28, 2020 pursuant to the September 2020 Recapitalization, which has a maturity date of March 31, 2024.

Non–IFRS financial measures

Just Energy’s Interim Condensed Consolidated Financial Statements are prepared in accordance with IFRS. The financial measures that are defined below do not have a standardized meaning prescribed by IFRS and may not be comparable to similar measures presented by other companies. These financial measures should not be considered as an alternative to, or more meaningful than, net income (loss), cash flow from operating activities and other measures of financial performance as determined in accordance with IFRS; however, the Company believes that these measures are useful in providing relative operational profitability of the Company’s business.

BASE GROSS MARGIN

“Base Gross Margin” represents gross margin adjusted to exclude the effect of applying IFRS Interpretation Committee Agenda Decision 11, Physical Settlement of Contracts to Buy or Sell a Non–Financial Item, for realized gains (losses) on derivative instruments, the one–time impact of the Weather Event, and the one–time non–recurring sales tax settlement. Base Gross Margin is a key measure used by management to assess performance and allocate resources. Management believes that these realized gains (losses) on derivative instruments reflect the long–term financial performance of Just Energy and thus have included them in the Base Gross Margin calculation.

EBITDA

“EBITDA” refers to earnings before finance costs, income taxes, depreciation and amortization with an adjustment for discontinued operations. EBITDA is a non–IFRS measure that reflects the operational profitability of the business.

BASE EBITDA

“Base EBITDA” refers to EBITDA adjusted to exclude the impact of unrealized mark to market gains (losses) arising from IFRS requirements for derivative financial instruments, Reorganization Costs, share–based compensation, impairment of inventory, Strategic Review costs, Restructuring costs, unrealized gain on investment, realized gains (losses) related to gas held in storage until gas is sold, and non–controlling interest. This measure reflects operational profitability as the impact of the non–cash gains (losses), impairment of inventory and Reorganization Costs are one–time non–recurring events. Non–cash share–based compensation expense is treated as an equity issuance for the purposes of this calculation as it will be settled in Common Shares; the unrealized mark to market gains (losses) are associated with supply already sold in the future at fixed prices; and, the unrealized mark to market gains (losses) of weather derivatives are not related to weather in the current period.

Just Energy ensures that customer margins are protected by entering into fixed–price supply contracts. Under IFRS, the customer contracts are not marked to market; however, there is a requirement to mark to market the future supply contracts. This creates unrealized and realized gains (losses) depending upon current supply pricing. Management believes that the unrealized mark to market gains (losses) do not impact the long–term financial performance of Just Energy and has excluded them from the Base EBITDA calculation.

Just Energy uses derivative financial instruments to hedge the gas held in storage for future delivery to customers. Under IFRS, the customer contracts are not marked to market: however, there is a requirement to report the realized gains (losses) in the current period instead of recognizing them as a cost of inventory until delivery to the customer. Just Energy excludes the realized gains (losses) to EBITDA during the injection season and includes them during the withdrawal season in accordance with the customers receiving the gas. Management believes that including the realized gains (losses) during the withdrawal season when the customers receive the gas is more reflective of the operations of the business.

Just Energy recognizes the incremental acquisition costs of obtaining a customer contract as an asset since these costs would not have been incurred if the contract was not obtained and are recovered through the consideration collected from the contract. Commissions and incentives paid for commodity contracts and value–added products contracts are capitalized and amortized over the term of the contract. Amortization of these costs with respect to customer contracts is included in the calculation of Base EBITDA (as selling commission expenses). Amortization of incremental acquisition costs on value–added product contracts is excluded from the Base EBITDA calculation as value–added products are considered to be a lease asset akin to a fixed asset whereby amortization or depreciation expenses are excluded from Base EBITDA.

FREE CASH FLOW AND UNLEVERED FREE CASH FLOW

Free cash flow represents cash flow from operations less Maintenance capital expenditures. Unlevered free cash flow represents free cash flows plus finance costs excluding the non–cash portion.

EMBEDDED GROSS MARGIN (“EGM”)

EGM is a rolling five–year measure of management’s estimate of future contracted energy and product gross margin. The commodity EGM is the difference between existing energy customer contract prices and the cost of supply for the remainder of the term, with appropriate assumptions for commodity RCE attrition and renewals. The product gross margin is the difference between existing value–added product customer contract prices and the cost of goods sold on a five– year undiscounted basis for such customer contracts, with appropriate assumptions for value–added product attrition and renewals. It is assumed that expiring contracts will be renewed at target margin renewal rates.

EGM indicates the gross margin expected to be realized over the next five years from existing customers. It is intended only as a directional measure for future gross margin. It is neither discounted to present value nor is it intended to consider administrative and other costs necessary to realize this margin.

Financial and operating highlights

For the three months ended September 30.

(thousands of dollars, except where indicated and per share amounts)


			% increase
	Fiscal 2022		(decrease)		Fiscal 2021
Sales	$	704,769	(5)	%	$	737,994
Base Gross Margin¹		116,577	(16)	%		138,274
Administrative expenses²		37,181	(15)	%		43,957
Selling commission expenses		27,851	(20)	%		34,894
Selling non-commission and marketing expense		16,936	30	%		13,017
Bad debt expense		3,692	(68)	%		11,662
Reorganization Costs		18,577	NMF	³		–
Finance costs		11,895	(60)	%		29,744
Profit (loss) for the period		326,049	NMF	³		(51,366)
Base EBITDA¹		30,897	(6)	%		32,774
RCE Mass Markets count		1,149,000	(5)	%		1,206,000
RCE Mass Markets net adds		9,000	NMF	³		(55,000)
RCE Commercial count		1,661,000	(12)	%		1,880,000

¹See “Non–IFRS financial measures” on page 6.

²Includes $0.3 million of Strategic Review costs for the second quarter of fiscal 2021.

³Not a meaningful figure.

Sales decreased by 5% to $704.8 million for the three months ended September 30, 2021 compared to $738.0 million for the three months ended September 30, 2020. The decrease was primarily driven by the loss of customers in the prior year from regulatory restrictions in Ontario, New York and California, selling constraints posed by COVID-19 pandemic on certain direct in–person channels and by competitive pressures on pricing in the Commercial segment. The overall decrease is partially offset by growth in sales through increased investment in digital marketing in Mass Markets.

Base Gross Margin decreased by 16% to $116.6 million for the quarter ended September 30, 2021 compared to $138.3 million for the quarter ended September 30, 2020. The decrease was primarily driven by a decline in the customer base, unfavourable exchange rate fluctuations and resettlements related to prior periods.

Base EBITDA decreased by 6% to $30.9 million for the three months ended September 30, 2021 compared to $32.8 million for the three months ended September 30, 2020. The decrease was driven by lower Base Gross Margin and increased investment in digital marketing and sales agent costs, partially offset by lower administrative, selling commission and bad debt expenses.

Administrative expenses decreased by 15% to $37.2 million for the three months ended September 30, 2021 compared to $44.0 million for the three months ended September 30, 2020. The decrease was primarily driven by higher professional fees and legal fees in the prior year, including a provision related to the Hurt and Hill class-action litigation.

Selling commission expenses decreased by 20% to $27.9 million for the three months ended September 30, 2021 compared to $34.9 for the three months ended September 30, 2020. The decrease is primarily driven by lower amortization expense of upfront acquisition cost from lower sales from direct in–person channels driven by the impacts of the COVID–19 pandemic in prior periods, as well as lower commercial sales driven by competitive price pressures.

Selling non–commission and marketing expenses increased by 30% to $16.9 million for the three months ended September 30, 2021 compared to $13.0 million for the three months ended September 30, 2020. The increase was driven by the investment in digital marketing and sales agent costs.

Bad debt expense decreased by 68% to $3.7 million for the three months ended September 30, 2021 compared to $11.7 million for the three months ended September 30, 2020. The decrease in bad debt was driven by the release of reserves due to continued consistent payment trends along with recovery of previous write-offs in the Commercial segment.

Reorganization Costs represent the amounts incurred related to the filings under the CCAA Proceedings. These costs include professional and advisory costs of $10.8 million, $2.7 million for the key employee retention plan and $5.1 million in prepetition claims, contract terminations and other costs.

Finance costs decreased by 60% to $11.9 million for the three months ended September 30, 2021 compared to $29.7 million for the three months ended September 30, 2020. The decrease is due to September 2020 Recapitalization together with no longer accruing finance costs on the unsecured debt due to the CCAA Proceedings as described in Note 8 of the Interim Condensed Consolidated Financial Statements.

Mass Markets RCE Net Adds for the three months ended September 30, 2021 was a gain of 9,000 compared to a loss of 55,000 for the three months ended September 30, 2020 driven by the increase investment in digital marketing and higher renewal rates.

Financial and operating highlights

For the six months ended September 30.

(thousands of dollars, except where indicated and per share amounts)


			% increase
	Fiscal 2022		(decrease)		Fiscal 2021
Sales	$	1,313,441	(8)	%	$	1,423,958
Base Gross Margin¹		216,194	(21)	%		274,553
Administrative expenses²		66,951	(18)	%		82,099
Selling commission expenses		53,145	(25)	%		70,873
Selling non-commission and marketing expense		31,314	30	%		23,998
Bad debt expense		11,110	(53)	%		23,602
Reorganization Costs		38,586	NMF	³		–
Finance costs		24,808	(52)	%		51,597
Profit (loss) for the period		601,348	NMF	³		27,784
Base EBITDA¹		53,919	(26)	%		73,253
Unlevered free cash flow¹		38,031	(28)	%		53,146
EGM Mass Market		1,047,200	(7)	%		1,130,000
EGM Commercial		336,400	(14)	%		390,800
RCE Mass Markets net adds		3,000	NMF	³		(117,000)

¹See “Non–IFRS financial measures” on page 6.

²Includes $2.1 million of Strategic Review costs for the second quarter of fiscal 2021.

³Not a meaningful figure.

Sales decreased by 8% to $1,313.4 million for the six months ended September 30, 2021 compared to $1,424.0 million for the six months ended September 30, 2020. The decrease was primarily driven by the loss of customers in the prior year from regulatory restrictions in Ontario, New York and California, selling constraints posed by COVID-19 pandemic on certain direct in–person channels and by competitive pressures on pricing in the Commercial segment. The overall decrease is partially offset by growth in sales through increased investment in digital marketing in Mass Markets.

Base Gross Margin decreased by 21% to $216.2 million for the six months ended September 30, 2021 compared to $274.6 million for the six months ended September 30, 2020. The decrease was primarily driven by resettlements related to prior periods, unfavourable exchange rate fluctuations and a decline in the customer base.

Base EBITDA decreased by 26% to $53.9 million for the six months ended September 30, 2021 compared to $73.3 million for the six months ended September 30, 2020. The decrease was driven by lower Base Gross Margin and increased investment in digital marketing and sales agent costs, partially offset by lower administrative, selling commission and bad debt expenses.

Administrative expenses decreased by 18% to $67.0 million for the six months ended September 30, 2021 compared to $82.1 million for the six months ended September 30, 2020. The decrease was primarily driven by higher professional fees and legal fees in the prior year, including a provision related to the Hurt and Hill class-action litigation.

Selling commission expenses decreased by 25% to $53.2 million for the six months ended September 30, 2021 compared to $70.9 for the six months ended September 30, 2020. The decrease is primarily driven by lower amortization expense of upfront acquisition cost from lower sales from direct in–person channels driven by the impacts of the COVID–19 pandemic in prior periods and lower commercial sales driven by competitive price pressures.

Selling non–commission and marketing expenses increased by 30% to $31.3 million for the six months ended September 30, 2021 compared to $24.0 million for the six months ended September 30, 2020. The increase was driven by the increased investment in digital marketing and sales agent cost.

Bad debt expense decreased by 53% to $11.1 million for the six months ended September 30, 2021 compared to $23.6 million for the six months ended September 30, 2020. The decrease was driven by the release of reserves due to continued consistent payment trends along with recovery of previous write-offs in the Commercial segment.

Reorganization Costs represent the amounts incurred related to the filings under the CCAA Proceedings. These costs include professional and advisory costs of $23.3 million, $5.2 million for the key employee retention plan and $10.0 million in prepetition claims, contract terminations and other costs.

Finance costs decreased by 52% to $24.8 million for the six months ended September 30, 2021 compared to $51.6 million for the six months ended September 30, 2020. The decrease is due to the September 2020 Recapitalization together with no longer accruing finance costs on the unsecured debt due to the CCAA Proceedings as described in Note 8 of the Interim Condensed Consolidated Financial Statements.

Unlevered free cash flow decreased by 28% to an inflow of $38.0 million for the six months ended September 30, 2021 compared to an inflow of $53.2 million for the six months ended September 30, 2020. The decrease is related to higher payments to ERCOT associated with the Weather Event, partially offset by the non–payment of trade and other payables subject to compromise under the CCAA Proceedings.

Mass Markets EGM decreased by 7% to $1,047.2 million as at September 30, 2021 compared to $1,130.0 million as at September 30, 2020. The decline resulted from the decline in the customer base and the unfavourable foreign exchange.

Commercial EGM decreased by 14% to $336.4 million as at September 30, 2021 compared to $390.8 million as at September 30, 2020. The decline resulted from the decline in the customer base and the unfavourable foreign exchange.

Base Gross Margin¹

For the Three months ended September 30.

(thousands of dollars)


	Fiscal 2022						Fiscal 2021
	Mass						Mass
	Market		Commercial		Total		Market		Commercial		Total
Gas	$	6,394	$	652	$	7,046	$	14,839	$	4,042	$	18,881
Electricity		80,217		29,314		109,531		89,607		29,786		119,393
	$	86,611	$	29,966	$	116,577	$	104,446	$	33,828	$	138,274
Decrease		(17)%		(11)%		(16)%

For the six months ended September 30.

(thousands of dollars)


	Fiscal 2022						Fiscal 2021
	Mass						Mass
	Market		Commercial		Total		Market		Commercial		Total
Gas	$	20,649	$	2,470	$	23,119	$	42,656	$	10,471	$	53,127
Electricity		140,937		52,138		193,075		172,816		48,610		221,426
	$	161,586	$	54,608	$	216,194	$	215,472	$	59,081	$	274,553
Decrease		(25)%		(8)%		(21)%

¹See “Non–IFRS financial measures” on page 6.

MASS MARKETS SEGMENT

Mass Markets Base Gross Margin decreased by 17% to $86.6 million for the three months ended September 30, 2021 compared to $104.5 million for the three months ended September 30, 2020. The decrease was driven by a decline in margin from higher energy and ancillary costs, unfavourable exchange rate fluctuations, and a decline in the customer base.

Mass Markets Base Gross Margin decreased by 25% to $161.6 million for the six months ended September 30, 2021 compared to $215.5 million for the six months ended September 30, 2020. The decrease was primarily driven by unfavourable exchange rate fluctuations, a decline in the customer base and lower margin from higher energy and ancillary costs.

Gas

Mass Markets Gas Base Gross Margin decreased by 57% to $6.4 million for the three months ended September 30, 2021 compared to $14.8 million for the three months ended September 30, 2020, primarily driven by a decline in the customer base and lower margin from higher costs.

Mass Markets Gas Base Gross Margin decreased by 52% to $20.6 million for the six months ended September 30, 2021 compared to $42.7 million for the six months ended September 30, 2020. The decrease was primarily driven by a decline in the customer base, favourable impact from resettlements in the prior year and lower margin from higher costs.

Electricity

Mass Markets Electricity Base Gross Margin decreased by 10% to $80.2 million for the three months ended September 30, 2021 compared to $89.6 million for the three months ended September 30, 2020. The decrease is primarily driven by lower margin from higher energy and ancillary costs, unfavourable exchange rate fluctuations and a decline in the customer base.

Mass Markets Electricity Base Gross Margin decreased by 18% to $140.9 million for the six months ended September 30, 2021 compared to $172.8 million for the six months ended September 30, 2020. The decrease is primarily driven by unfavourable exchange rate fluctuations, a decline in the customer base, lower fee revenue due to restrictions imposed on disconnections in Texas in the first quarter of Fiscal 2022 and lower margin from higher energy and ancillary costs.

COMMERCIAL SEGMENT

Commercial Base Gross Margin decreased by 11% to $30.0 million for the three months ended September 30, 2021 compared to $33.8 million six months ended September 30, 2020. The decrease was driven by resettlements related to prior periods and a decline in the customer base, partially offset by higher margin realized across several markets.

Commercial Base Gross Margin decreased by 8% to $54.6 million for the six months ended September 30, 2021 compared to $59.1 million for the six months ended September 30, 2020. The decrease was primarily due to resettlements related to prior periods, a decline in the customer base and unfavourable exchange rate fluctuations, partially offset by higher margin realized across several markets.

Gas

Commercial Gas Base Gross Margin decreased by 84% to $0.7 million for the three months ended September 30, 2021 compared to $4.0 million for the three months ended September 30, 2020. The decrease was primarily due to lower margin realized in the current year and resettlements related to prior periods.

10.

Commercial Gas Base Gross Margin decreased by 76% to $2.5 million for the six months ended September 30, 2021 compared to $10.5 million for the six months ended September 30, 2020. The decrease was primarily due to favourable impact from resettlements in the prior year and lower margin realized in the current year.

Electricity

Commercial Electricity Base Gross Margin decreased by 2% to $29.3 million for the three months ended September 30, 2021 compared to $29.8 million for the three months ended September 30, 2020. The decrease was primarily due to favourable impact from resettlements in the prior year, a decline in customer base and unfavourable exchange rate fluctuations, partially offset by higher margin across several markets.

Commercial Electricity Base Gross Margin increased by 7% to $52.1 million for the six months ended September 30, 2021 compared to $48.6 million for the six months ended September 30, 2020. The increase is primarily driven by higher margin realized across several markets, partially offset by favourable impact from resettlements in the prior comparable period, a decline in customer base and unfavourable exchange rate fluctuations.

Mass Markets average realized Base Gross Margin

For the trailing 12 months ended September 30.


	Fiscal 2022				Fiscal 2021
	GM/RCE		% Change		GM/RCE
Gas	$	353	(12)	%	$	399
Electricity		309	(13)	%		355
Total	$	319	(13)	%	$	367

Mass Markets average realized Base Gross Margin for the Mass Markets segment for the trailing 12 months ended September 30, 2021 decreased 13% to $319 compared to $367 for the trailing 12 months ended September 30, 2020. The decrease is primarily attributable to an increase in market costs, as well as competitive market pricing and changes to the sales channel mix.

Commercial average realized Base Gross Margin

For the trailing 12 months ended September 30.


	Fiscal 2022				Fiscal 2021
	GM/RCE		% Change		GM/RCE
Gas	$	76	(30)	%	$	109
Electricity		100	10	%		91
Total	$	95	-		$	95

Commercial Average realized Base Gross Margin for the trailing 12 months ended September 30, 2021 was $95, in line with the trailing 12 months ended September 30, 2020.

11.

Base EBITDA

For the three months ended September 30.

(thousands of dollars)


	Fiscal 2022		Fiscal 2021
Reconciliation to Interim Condensed Consolidated Statements of Income
Profit (Loss) for the period	$	326,049	$	(51,366)
Add:
Finance costs		11,895		29,744
Provision (recovery) for income taxes		(245)		673
Loss from discontinued operations		–		1,210
Amortization and depreciation		4,750		5,719
EBITDA	$	342,449	$	(14,020)
Add (subtract):
Unrealized (gain) loss of derivative instruments and other		(287,515)		84,968
Gain on September 2020 Recapitalization transaction, net		–		(52,152)
Weather Event		(3,051)		–
Reorganization Costs		18,577		–
Unrealized gain on investment		(29,000)
Non-cash adjustment to green obligations		(4,578)		–
Restructuring Costs		–		7,118
Share-based compensation		417		3,430
Strategic Review costs		–		295
Realized (gain) loss included in cost of goods sold		(6,399)		3,019
Loss attributable to non-controlling interest		(3)		116
Base EBITDA	$	30,897	$	32,774

Gross margin	$	81,471	$	220,711
Realized gain (loss) of derivative instruments and other		42,735		(82,438)
Non-cash adjustment to green obligations		(4,578)		–
Weather Event		(3,051)		–
Base Gross Margin		116,577		138,273
Add (subtract):
Administrative expenses		(37,181)		(43,957)
Selling commission expenses		(27,851)		(34,894)
Selling non-commission and marketing expense		(16,936)		(13,017)
Bad debt expense		(3,692)		(11,662)
Strategic Review costs		–		295
Amortization included in cost of sales		40		45
Loss attributable to non-controlling interest		(3)		116
Other income (expense)		(57)		(2,425)
Base EBITDA	$	30,897	$	32,774

12.

Base EBITDA

For the six months ended September 30.

(thousands of dollars)


	Fiscal 2022		Fiscal 2021
Reconciliation to Interim Condensed Consolidated Statements of Income
Profit for the period	$	601,348	$	27,784
Add:
Finance costs		24,808		51,597
Provision (recovery) for income taxes		(1,212)		1,307
Loss from discontinued operations		–		4,158
Amortization and depreciation		9,239		13,071
EBITDA	$	634,183	$	97,917
Add (subtract):
Unrealized (gain) loss of derivative instruments and other		(579,652)		7,619
Gain on September 2020 Recapitalization transaction, net		–		(50,341)
Weather Event		615		–
Reorganization Costs		38,586		–
Unrealized gain on investment		(29,000)		–
Restructuring Costs		–		7,118
Non-cash adjustment to green obligations		(4,578)		–
Share-based compensation		1,027		4,122
Impairment of inventory		648		–
Strategic Review costs		–		2,098
Realized (gain) loss included in cost of goods sold		(7,970)		4,607
Loss attributable to non-controlling interest		60		113
Base EBITDA	$	53,919	$	73,253

Gross margin	$	161,781	$	489,848
Realized gain (loss) of derivative instruments and other		58,376		(215,296)
Non-cash adjustment to green obligations		(4,578)		–
Weather Event		615		–
Base Gross Margin		216,194		274,552
Add (subtract):
Administrative expenses		(66,951)		(82,099)
Selling commission expenses		(53,145)		(70,873)
Selling non-commission and marketing expense		(31,314)		(23,998)
Bad debt expense		(11,110)		(23,602)
Strategic Review costs		–		2,098
Amortization included in cost of sales		82		119
Loss attributable to non-controlling interest		60		113
Other income (expense)		103		(3,057)
Base EBITDA	$	53,919	$	73,253

13.

Summary of quarterly results for continuing operations

(thousands of dollars, except per share amounts)


	Q2		Q1		Q4		Q3
	Fiscal 2022		Fiscal 2022		Fiscal 2021		Fiscal 2021
Sales¹	$	704,769	$	608,672	$	689,064	$	627,015
Cost of goods sold¹		623,298		528,363		3,131,485		446,571
Gross margin		81,471		80,309		(2,442,421)		180,445
Realized gain (loss) of derivative instruments and other		42,735		15,642		2,152,866		(56,778)
Weather Event		(3,051)		3,666		418,369		–
Sales Tax settlement		–		–		1,885		7,941
Non-cash adjustment to green obligations		(4,578)		–		–		–
Base Gross Margin		116,577		99,617		130,699		131,608
Administrative expenses		37,181		29,770		29,884		30,408
Selling commission expenses		27,851		25,294		28,295		30,485
Selling non-commission and marketing expenses		16,936		14,378		14,086		11,784
Bad debt expense		3,692		7,418		7,301		3,358
Finance costs		11,895		12,913		17,346		17,677
Profit (loss) for the period from continuing operations		326,049		275,299		(382,371)		(52,327)
Profit (loss) for the period from discontinued operations, net		–		–		(162)		4,788
Profit (loss) for the period		326,049		275,299		(382,533)		(47,539)
Base EBITDA from continuing operations		30,897		23,021		53,794		55,785


	Q2		Q1		Q4		Q3
	Fiscal 2021		Fiscal 2021		Fiscal 2020		Fiscal 2020
Sales¹	$	737,994	$	685,964	$	776,921	$	750,615
Cost of goods sold¹		517,283		416,827		489,411		538,646
Gross margin		220,711		269,137		287,510		211,969
Realized gain (loss) of derivative instruments and other		(82,438)		(132,858)		(107,089)		(69,485)
Base Gross Margin		138,273		136,279		180,421		142,484
Administrative expenses		43,957		38,142		46,051		39,616
Selling commission expenses		34,895		35,979		36,983		36,698
Selling non-commission and marketing expenses		13,017		10,981		16,584		14,572
Bad debt expense		11,662		11,940		13,197		19,996
Finance costs		29,744		21,853		26,770		28,178
Profit (loss) for the period from continuing operations		(50,156)		82,098		(138,210)		20,601
Profit (loss) for the period from discontinued operations, net		(1,210)		(2,948)		(2,721)		6,293
Profit (loss) for the period		(51,366)		79,150		(140,931)		26,894
Base EBITDA from continuing operations		32,774		40,479		74,632		37,950

¹ Sales amounts have been corrected from the statements previously presented to conform to the presentation of the current Interim Condensed Consolidated Financial Statements.

Just Energy’s results reflect seasonality, as electricity consumption is slightly greater in the first and second quarters (summer quarters) and gas consumption is significantly greater during the third and fourth quarters (winter quarters). Electricity and gas customers (RCEs) currently represent 77% and 23% of the commodity customer base, respectively. Since consumption for each commodity is influenced by weather, Just Energy believes the annual quarter over quarter comparisons are more relevant than sequential quarter comparisons.

14.

Segmented Base EBITDA¹

For the three months ended September 30.

(thousands of dollars)

Fiscal 2022

��

Corporate

Mass

and shared

Market

Commercial

services

Consolidated

Sales

401,491

303,278

–

704,769

Cost of goods sold

(339,323)

(283,975)

–

(623,298)

Gross margin

62,168

19,303

–

81,471

Non-cash adjustment to green obligations

(4,332)

(246)

–

(4,578)

Weather Event

(3,051)

–

(3,051)

Realized gain of derivative instruments and other

31,826

10,909

–

42,735

Base Gross Margin

86,611

29,966

–

116,577

Add (subtract):

Administrative expenses

(10,348)

(3,761)

(23,072)

(37,181)

Selling commission expenses

(13,646)

(14,205)

–

(27,851)

Selling non-commission and marketing expense

(15,520)

(1,416)

–

(16,936)

Bad debt expense

(3,585)

(107)

–

(3,692)

Amortization included in cost of goods sold

–

Other income

(43)

(14)

–

(57)

Loss attributable to non-controlling interest

(3)

–

(3)

Base EBITDA from continuing operations

43,506

10,463

(23,072)

30,897


	Fiscal 2021
					Corporate
	Mass				and shared
	Market		Commercial		services		Consolidated
Sales¹	$	419,340	$	318,654	$	–	$	737,994
Cost of goods sold¹		(265,848)		(251,435)		–		(517,283)
Gross margin		153,492		67,219		–		220,711
Realized loss of derivative instruments and other		(49,046)		(33,392)		–		(82,438)
Base Gross Margin		104,446		33,827		–		138,273
Add (subtract):
Administrative expenses		(9,892)		(4,153)		(29,912)		(43,957)
Selling commission expenses		(18,139)		(16,755)		–		(34,894)
Selling non-commission and marketing expense		(11,526)		(1,491)		–		(13,017)
Bad debt expense		(8,639)		(3,023)		–		(11,662)
Amortization included in cost of goods sold		45		–		–		45
Strategic Review costs		–		–		295		295
Other expense		(2,534)		109		–		(2,425)
Loss attributable to non-controlling interest		116		–		–		116
Base EBITDA from continuing operations	$	53,877	$	8,514	$	(29,617)	$	32,774

Mass Markets segment Base EBITDA decreased by 19% to $43.5 million for the three months ended September 30, 2021 compared to $53.9 million for the three months ended September 30, 2020. The decrease was driven by lower Base Gross Margin primarily due to a decline in margin from higher energy and ancillary costs and increased investment in digital marketing partially and sales agent costs, partially offset by a lower selling commission and bad debt expenses.

Commercial segment Base EBITDA increased by 24% to $10.5 million for the three months ended September 30, 2021 compared to $8.5 million for the three months ended September 30, 2020. The increase was driven by lower selling commission and bad debt expenses, partially offset by a decline in Base Gross Margin.

15.

primarily driven by higher professional fees and legal fees in the prior year, including a provision related to the Hurt and Hill class-action litigation.

Segmented Base EBITDA¹

For the six months ended September 30.

(thousands of dollars)

Fiscal 2022

Corporate

Mass

and shared

Market

Commercial

services

Consolidated

Sales

716,477

596,964

–

1,313,441

Cost of goods sold

(594,820)

(556,840)

–

(1,151,660)

Gross margin

121,657

40,124

–

161,781

Non-cash adjustment to green obligations

(4,332)

(246)

–

(4,578)

Weather Event

615

–

615

Realized gain of derivative instruments and other

43,646

14,730

–

58,376

Base Gross Margin

161,586

54,608

–

216,194

Add (subtract):

Administrative expenses

(19,501)

(7,100)

(40,350)

(66,951)

Selling commission expenses

(25,503)

(27,642)

–

(53,145)

Selling non-commission and marketing expense

(28,796)

(2,518)

–

(31,314)

Bad debt expense

(9,525)

(1,585)

–

(11,110)

Amortization included in cost of goods sold

–

Other income

–

103

Loss attributable to non-controlling interest

–

Base EBITDA from continuing operations

78,485

15,784

(40,350)

53,919


	Fiscal 2021
					Corporate
	Mass				and shared
	Market		Commercial		services		Consolidated
Sales¹	$	810,004	$	613,954	$	–	$	1,423,958
Cost of goods sold¹		(470,157)		(463,953)		–		(934,110)
Gross margin		339,847		150,001		–		489,848
Realized loss of derivative instruments and other		(124,375)		(90,921)		–		(215,296)
Base Gross Margin		215,472		59,080		–		274,552
Add (subtract):
Administrative expenses		(18,187)		(9,436)		(54,476)		(82,099)
Selling commission expenses		(36,589)		(34,284)		–		(70,873)
Selling non-commission and marketing expense		(20,633)		(3,365)		–		(23,998)
Bad debt expense		(17,087)		(6,515)		–		(23,602)
Amortization included in cost of goods sold		119		–		–		119
Strategic Review costs		–		–		2,098		2,098
Other expense		(3,166)		109		–		(3,057)
Loss attributable to non-controlling interest		113		–		–		113
Base EBITDA from continuing operations	$	120,042	$	5,589	$	(52,378)	$	73,253

¹ Sales amounts have been corrected from the statements previously presented to conform to the presentation of the current Interim Condensed Consolidated Financial Statements.

² The segment definitions are provided on page 3.

Consolidated Base EBITDA decreased by 26% to $53.9 million for the six months ended September 30, 2021 compared to $73.3 million for the six months ended September 30, 2020. The decrease was driven by lower Base Gross Margin and increased investment in digital marketing and sales agent costs, partially offset by lower selling commission, administrative and bad debt expenses.

Mass Markets segment Base EBITDA decreased by 35% to $78.5 million for the six months ended September 30, 2021 compared from $120.0 million for the six months ended September 30, 2020. The decrease was driven by a lower Base

16.

Gross Margin and increased investment in digital marketing and sales agent costs, partially offset by lower bad debt and selling commission expenses.

Commercial segment Base EBITDA increased by 182% to $15.8 million for the six months ended September 30, 2021 compared to $5.6 million for the six months ended September 30, 2020. The increase was driven by selling commission expenses and bad debt expenses, partially offset by lower Base Gross Margin from favoruable resettlements in the prior year and a decline in the customer base.

Corporate and shared services costs relate to management oversight of the business units, public reporting and filings, corporate governance and other shared services functions. The corporate expenses were $40.4 million for the six months ended September 30, 2021 compared to $52.4 million for the six months ended September 30, 2020. The decrease was primarily driven by higher professional and legal fees in the prior year, including a provision related to the Hurt and Hill class-action litigation. The Corporate expenses exclude Strategic Review costs in the six months ended September 30, 2020, because the costs are non-recurring and therefore excluded from Base EBITDA.

Acquisition Costs

The acquisition costs per customer for the trailing twelve months for Mass Market customers signed by sales agents including sales through digital channel and the Commercial customers signed by brokers were as follows:


	Fiscal 2022		Fiscal 2021
Mass Markets	$	235/RCE	$	241/RCE
Commercial	$	44/RCE	$	42/RCE

The Mass Markets average acquisition cost decreased by 2% to $235/RCE for the twelve months ended September 30, 2021 compared to $241/RCE reported for the twelve months ended September 30, 2020, primarily from lower exchange rate and a change in channel mix towards lower cost channels.

The Commercial average customer acquisition cost increased by 5% to $44/RCE for the twelve months ended September 30, 2021 compared to $42/RCE for the twelve months ended September 30, 2020.

Customer summary

CUSTOMER COUNT


	As at	As at
	September 30,	September 30,
	2021	2020	% decrease
Mass Markets	840,000	906,000	(7)	%
Commercial	96,000	108,000	(11)	%
Total customer count	936,000	1,014,000	(8)	%

The Mass Markets customer count decreased 7% to 840,000 compared to September 30, 2020. The decline in Mass Markets customers is due to regulatory restrictions in Ontario, New York and California; and selling constraints in direct in–person channels previously posed by the COVID–19 pandemic in prior periods.

The Commercial customer count decreased 11% to 96,000 compared to September 30, 2020. The decline in Commercial customers is due to competitive price pressures in the United States together with impacts related to the COVID–19 pandemic in prior periods and exiting the California electricity market.

17.

COMMODITY RCE SUMMARY


	July 1,			Failed to	September 30,	% increase
	2021	Additions	Attrition	renew	2021	(decrease)
Mass Markets
Gas	239,000	7,000	(6,000)	(2,000)	238,000	(0)	%
Electricity	901,000	79,000	(44,000)	(25,000)	911,000	1	%
Total Mass Markets RCEs	1,140,000	86,000	(50,000)	(27,000)	1,149,000	1	%
Commercial
Gas	403,000	15,000	(6,000)	(4,000)	408,000	1	%
Electricity	1,293,000	26,000	(27,000)	(39,000)	1,253,000	(3)	%
Total Commercial RCEs	1,696,000	41,000	(33,000)	(43,000)	1,661,000	(2)	%
Total RCEs	2,836,000	127,000	(83,000)	(70,000)	2,810,000	(1)	%

MASS MARKETS

Mass Markets RCE additions increased by 139% to 86,000 for the three months ended September 30, 2021 compared to 36,000 for the three months ended September 30, 2020. The increase is driven by investment in digital marketing and sales agent headcount, as well as continued improvement in direct face–to–face channels. The COVID–19 pandemic had substantial impacts in the three months ended September 30, 2020.

Mass Markets RCE attrition decreased by 7% to 50,000 for the three months ended September 30, 2021 compared to 54,000 for the three months ended September 30, 2020. The decrease in attrition is driven by lower customer base.

Mass Markets failed to renew RCEs decreased by 27% to 27,000 for the three months ended September 30, 2021 compared to 37,000 for the three months ended September 30, 2020, driven by improved renewal rates through improved retention offerings.

Mass Markets RCE Net Adds for the three months ended September 30, 2021 was a gain of 9,000 compared to a loss of 55,000 for the three months ended September 30, 2020. Excluding the one–time 29,000 loss related to the regulatory changes in New York coming into effect in April 2021, Mass Markets RCE Net Adds for the six months ended September 30, 2021 was a positive 32,000.

As at September 30, 2021, the U.S. and Canadian operations accounted for 86% and 14% of the Mass Markets RCE base, respectively.

COMMERCIAL

Commercial RCE additions decreased by 20% to 41,000 for the three months ended September 30, 2021 compared to 51,000 for the three months ended September 30, 2020. The decrease was driven by a very large customer added during the prior year. Excluding large customer additions, Commercial gross additions increased by 28% for the three months ended September 30, 2021 compared to the prior year.

Commercial RCE attrition decreased by 42% to 33,000 for the three months ended September 30, 2021 compared to 57,000 for the three months ended September 30, 2020. The company continues to see improved attrition on the Commercial segment in line with the general recovery in economic activity.

Commercial failed to renew RCEs increased by 19% to 43,000 RCEs for the six months ended September 30, 2021 compared to 36,000 RCEs for the six months ended September 30, 2020.

As at September 30, 2021, the U.S. and Canadian operations accounted for 65% and 35% of the Commercial RCE base, respectively.

TOTAL

Overall, as at September 30, 2021, the U.S. and Canadian operations accounted for 73% and 27% of the RCE base, respectively, compared to 75% and 25%, respectively, as at September 30, 2020.

18.

COMMODITY RCE ATTRITION


	Trailing 12 months	Trailing 12 months
	ended September 30, 2021	ended September 30, 2020
Mass Markets	18%	18%
Commercial	8%	13%

The Mass Markets attrition rate for the trailing 12 months ended September 30, 2021 remained consistent at 18% reflecting the benefits of focus sales to higher quality customers and increased focus on the customer experience.

The Commercial attrition rate for the trailing 12 months ended September 30, 2021 decreased five percentage points to 8%.


	Three months	Three months
	ended September 30,	ended September 30,
	2021	2020
Mass Markets	4%	4%
Commercial	2%	3%

The Mass Markets attrition rate for the three months ended September 30, 2021 remained consistent at 4%.

The Commercial attrition rate for the three months ended September 30, 2021 decreased by one percentage point to 2% from 3% compared to the three months ended September 30, 2020 reflecting improvement in customer retention following the reduction of restrictions due to the COVID–19 pandemic.

COMMODITY RCE RENEWALS


	Trailing 12 months	Trailing 12 months
	ended September 30, 2021	ended September 30, 2020
Mass Markets	77%	73%
Commercial	49%	52%

The Mass Markets renewal rate increased four percentage points to 77% for the trailing 12 months ended September 30, 2021. The increase in the Mass Markets renewal rate was driven by improved retention offerings and continued focus on the customer experience.

The Commercial renewal rate decreased by three percentage points to 49% as compared to the same period of fiscal 2021.


	Three months	Three months
	ended September 30,	ended September 30,
	2021	2020
Mass Markets	79%	75%
Commercial	48%	52%

The Mass Markets renewal rate for the three months ended September 30, 2021, increased to 79% from 75% for the three months ended September 30, 2020 driven by improved retention offerings and continued focus on the customer experience.

The Commercial renewal rate for the three months ended September 30, 2021 decreased to 48% from 52% for the three months ended September 30, 2020.The decline in the Commercial renewal rate reflects a competitive market for Commercial renewals.

AVERAGE GROSS MARGIN PER RCE

The table below depicts the annual design margins on new and renewed contracts signed during the three months ended September 30, 2021 compared to three months ended September 30, 2020 for standard commodities, which does not include non–recurring non–commodity fees.


	Q2 Fiscal		Number of	Q2 Fiscal		Number of
	2022		RCEs	2021		RCEs
Mass Markets added or renewed	$	266	178,000	$	309	118,000
Commercial added or renewed¹		88	86,000		88	73,000

¹Annual gross margin per RCE excludes margins from Interactive Energy Group and large Commercial and Industrial customers.

19.

For the three months ended September 30, 2021, the average gross margin per RCE for the customers added or renewed by the Mass Markets segment was $266, a decrease of 14% from $309 for the three months ended September 30, 2020 due to change in channel mix including lower cost of acquisition channels and overall margin pressure related to increasing commodity prices.

For the Commercial segment there was no change in average gross margin per RCE for the three months ended September 30, 2021 compared to the three months ended September 30, 2020.

Liquidity and capital resources from continuing operations

SUMMARY OF CASH FLOWS

For the six months ended September 30.

(thousands of dollars)


	Fiscal 2022		Fiscal 2021
Operating activities from continuing operations	$	22,376	$	22,798
Investing activities from continuing operations		(4,837)		(4,673)
Financing activities from continuing operations		(34,782)		37,426
Effect of foreign currency translation		1,206		(3,679)
Increase (decrease) in cash		(16,037)		51,872
Cash and cash equivalents – beginning of period		215,989		26,093
Cash and cash equivalents – end of period	$	199,952	$	77,965

OPERATING ACTIVITIES

Cash flow from operating activities was an inflow of $22.4 million for the six months ended September 30, 2021 compared to an inflow of $22.8 million for the six months ended September 30, 2020. September 30, 2021 cash flow from operating activities benefited from lower cash financing costs due to the September 2020 Recapitalization offset by higher payments to ERCOT associated with the Weather Event, partially offset by the non-payment of trade and other payables subject to compromise.

INVESTING ACTIVITIES

Cash flow from investing activities was an outflow of $4.8 million for the six months ended September 30, 2021 compared to an outflow of $4.7 million for the six months ended September 30, 2020.

FINANCING ACTIVITIES

Cash flow from financing activities was an outflow of $34.8 million for the six months ended September 30, 2021 compared to an inflow of $37.4 million for the six months ended September 30, 2020. The outflow is primarily driven by payments of $63.3 million under the Credit Facility to allow the issuance of Letters of Credit partially offset by proceeds from DIP Facility.

Free cash flow and unlevered free cash flow¹

For the six months ended September 30.

(thousands of dollars)


	Fiscal 2022		Fiscal 2021
Cash flows from operating activities	$	22,376	$	22,798
Subtract: Maintenance capital expenditures		(4,837)		(4,673)
Free cash flow		17,539		18,125
Finance costs, cash portion		20,492		35,021
Unlevered free cash flow	$	38,031	$	53,146

¹See “Non–IFRS financial measures” on page 6.

Unlevered free cash flow decreased by 28% to an inflow of $38.0 million for the quarter ended September 30, 2021 compared to an inflow of $53.2 million for the quarter ended September 30, 2020. The decrease is related to higher payments to ERCOT associated with the Weather Event, partially offset by the non–payment of trade and other payables.

20.

Selected Balance sheet data as at September 30, 2021, compared to March 31, 2021

The following table shows selected data from the Interim Condensed Consolidated Financial Statements as at the following periods:


	As at		As at
	September 30,		March 31,
	2021		2021
Assets:
Cash and cash equivalents	$	199,952	$	215,989
Trade and other receivables, net		401,633		340,201
Total fair value of derivative financial assets		577,505		35,626
Other current assets		155,855		163,405
Total assets		1,733,538		1,091,806

Liabilities:
Trade and other payables	$	1,024,383	$	921,595
Total fair value of derivative financial liabilities		30,957		75,146
Total debt		630,849		655,740
Total liabilities		1,720,962		1,686,628

Total cash and cash equivalents decreased to $200.0 million as at September 30, 2021 from $216.0 million as at March 31, 2021. The decrease in cash is primarily attributable to cash outflows from financing operations.

Trade and other receivables, net increased to $401.6 million as at September 30, 2021 from $340.2 million as at March 31, 2021. The changes are primarily due to increase in receivables from customers receivables in the normal seasonal course of business.

Other current assets decreased to $155.9 million as at September 30, 2021 from $163.4 million as at March 31, 2021 due to the retirement of green certificates.

Trade and other payables increased to $1,024.4 million as at September 30, 2021 from $921.6 million as at March 31, 2021 driven by the normal seasonal increase in commodity and supplier payables.

Fair value of derivative financial assets and fair value of financial liabilities relate entirely to the financial derivatives. The unrealized mark to market gains and losses can result in significant changes in profit and, accordingly, shareholders’ deficit from year to year due to commodity price volatility. As Just Energy has purchased this supply to cover future customer usage at fixed prices, management believes that these unrealized changes do not impact the long–term financial performance of Just Energy.

Total debt was $630.9 million as at September 30, 2021, down from $655.7 million as at March 31, 2021. The reduction in total debt is a result of the payments made under the Credit Facility to allow the issuance of letters of credit. As at September 30, 2021, $471.5 million of the debt is subject to compromise under the CCAA Proceedings.

Embedded gross margin¹

Management’s estimate of EGM is as follows:

(millions of dollars)


	As at		As at
	September 30,		September 30,		%
	2021		2020		decrease
Mass Markets embedded gross margin		1,047.2		1,130.0	(7)	%
Commercial embedded gross margin		336.4		390.8	(14)	%
Total embedded gross margin	$	1,383.6	$	1,520.8	(9)	%

¹See “Non–IFRS financial measures” on page 6

Management’s estimate of the Mass Markets EGM decreased by 7% to $1,047 million as at September 30, 2021 compared to $1,130 million as at September 30, 2020. The decline resulted from the lower customer base and the unfavourable foreign exchange.

21.

Management’s estimate of the Commercial EGM decreased by 14% to $336 million as at September 30, 2021 compared to $391 million as at September 30, 2020. The decline resulted from the decline in the customer base and the unfavourable foreign exchange.

Provision for (Recovery of) income and deferred tax

(thousands of dollars)


	For the three months ended September 30,				For the six months ended September 30,
	2021		2020		2021		2020
Current income tax expense (recovery)	$	(245)	$	493	$	(1,357)	$	1,366
Deferred income tax expense (recovery)		–		180		145		(59)
Provision for (recovery of) income tax	$	(245)	$	673	$	(1,212)	$	1,307

Just Energy recorded a current income tax recovery of $0.2 million for the three months ended September 30, 2021, compared to $0.5 million expense in the three months ended September 30, 2020. A current income tax recovery of $1.4 million for the six months ended September 30, 2021, compared to $1.4 million expense in the six months ended September 30, 2020. Just Energy continues to have a current tax expense from profitability in taxable jurisdictions however during the second quarter of fiscal 2022 a recovery was recognized due to the benefit of a current year loss carried back.

During the three months ended September 30, 2021, a deferred tax expense of nil was recorded as compared to a deferred tax expense of $0.2 million during the three months ended September 30, 2020.

OTHER OBLIGATIONS

In the opinion of management, Just Energy has no material pending actions, claims or proceedings that have not been included either in its accrued liabilities or in the Interim Condensed Consolidated Financial Statements. In the normal course of business, Just Energy could be subject to certain contingent obligations that become payable only if certain events were to occur. The inherent uncertainty surrounding the timing and financial impact of any events prevents any meaningful measurement, which is necessary to assess any material impact on future liquidity. Such obligations include potential judgments, settlements, fines and other penalties resulting from actions, claims or proceedings.

Transactions with related parties

Parties are considered to be related if one party has the ability to control the other party or exercise influence over the other party in making financial or operating decisions. The definition includes subsidiaries and other persons.

PIMCO through certain affiliates became a 28.9% shareholder of the Company as part of the September 2020 Recapitalization. On March 9, 2021, certain PIMCO affiliates entered into the DIP Facility with the Company as discussed in the Interim Condensed Consolidated Financial Statements.

Off balance sheet items

The Company has issued letters of credit in accordance with its credit facility totaling $160.5 million as at September 30, 2021 to various counterparties, primarily utilities in the markets it operates in, as well as suppliers.

Pursuant to separate arrangements with multiple insurance and surety bond providers. Just Energy has issued surety bonds to various counterparties including States, regulatory bodies, utilities and various other surety bond holders in return for a fee and/or meeting certain collateral posting requirements. Such surety bond postings are required in order to operate in certain states or markets. Total surety bonds issued as at September 30, 2021 was $46.3 million and are backed by letters of credit or cash collateral.

Critical accounting estimates and judgments

The Interim Condensed Consolidated Financial Statements of Just Energy have been prepared in accordance with IFRS. Certain accounting policies require management to make estimates and judgments that affect the reported amounts of assets, liabilities, sales, cost of goods sold, administrative expenses, selling and marketing expenses, and other operating expenses. Estimates are based on historical experience, current information and various other assumptions that are believed to be reasonable under the circumstances. The emergence of new information and changed circumstances may result in actual results or changes to estimated amounts that differ materially from current estimates.

22.

The following assessment of critical accounting estimates is not meant to be exhaustive. Just Energy might realize different results from the application of new accounting standards promulgated, from time to time, by various rule–making bodies.

COVID–19 IMPACT

As a result of the continued coronavirus disease (“COVID–19”) pandemic, we have reviewed the estimates, judgments and assumptions used in the preparation of the Interim Condensed Consolidated Financial Statements and determined that no significant revisions to such estimates, judgments or assumptions were required for the three months ended September 30, 2021.

FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT

Just Energy has entered into a variety of derivative financial instruments as part of the business of purchasing and selling gas, electricity and JustGreen supply and as part of the risk management practice. In addition, Just Energy uses derivative financial instruments to manage foreign exchange, interest rate and other risks.

Just Energy enters into contracts with customers to provide electricity and gas at fixed prices and provide comfort to certain customers that a specified amount of energy will be derived from green generation or carbon destruction. These customer contracts expose Just Energy to changes in market prices to supply these commodities. To reduce its exposure to commodity market price changes, Just Energy uses derivative financial and physical contracts to secure fixed–price commodity supply to cover its estimated fixed–price delivery or green commitment. Certain derivative contracts were purchased to manage ERCOT collateral requirements.

Just Energy’s objective is to minimize commodity risk, other than consumption changes, usually attributable to weather. Accordingly, it is Just Energy’s policy to hedge the estimated fixed–price requirements of its customers with offsetting hedges of natural gas and electricity at fixed prices for terms equal to those of the customer contracts. The cash flow from these supply contracts is expected to be effective in offsetting Just Energy’s price exposure and serves to fix acquisition costs of gas and electricity to be delivered under the fixed–price or price–protected customer contracts; however, hedge accounting under IFRS 9 is not applied. Just Energy’s policy is not to use derivative instruments for speculative purposes.

Just Energy’s U.S. operations introduce foreign exchange–related risks. Just Energy enters into foreign exchange forwards in order to hedge its exposure to fluctuations in cross border cash flows, however, hedge accounting under IFRS 9 is not applied.

The Interim Financial Statements are in compliance with IAS 32, “Financial Instruments: Presentation”; IFRS 9; and IFRS 7, “Financial Instruments: Disclosure”. Due to commodity volatility and to the size of Just Energy, the swings in mark to market on these positions will increase the volatility in Just Energy’s earnings.

The Company’s financial instruments are valued based on the following fair value hierarchy:

Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities;

Level 2 – Inputs other than quoted prices that are observable for the asset or liability either directly or indirectly; and

Level 3 – Inputs that are not based on observable market data.

The main cause of changes in the fair value of derivative instruments is changes in the forward curve prices used for the fair value calculations. For a sensitivity analysis of these forward curves, see Note 6 of the Interim Condensed Consolidated Financial Statements. Other inputs, including volatility and correlations, are driven off historical settlements.

23.

RECEIVABLES AND LIFETIME EXPECTED CREDIT LOSSES

The lifetime expected credit loss reflects Just Energy’s best estimate of losses on the accounts receivable and unbilled revenue balances. Just Energy determines the lifetime expected credit loss by using historical loss rates and forward–looking factors if applicable. Just Energy is exposed to customer credit risk on its continuing operations in Alberta, Texas, Illinois (gas), California (gas) and Ohio (electricity) and for certain Commercial customers in dual-billing markets including Illinois (power), Pennsylvania (power), Massachusetts (power), New York and New Jersey. Credit review processes have been implemented to perform credit evaluations of customers and manage customer default. In addition, the Company may from time to time change the criteria that it uses to determine the creditworthiness of its customers, including RCEs, and such changes could result in decreased creditworthiness of its customers and/or result in increased customer defaults. If a significant number of customers were to default on their payments, including as a result of any changes to the Company’s credit criteria, it could have a material adverse effect on the operations and cash flows of Just Energy. Management factors default from credit risk in its margin expectations for all of the above markets, See Note 4 of the Interim Condensed Consolidated Financial Statements.

Revenues related to the sale of energy are recorded when energy is delivered to customers. The determination of energy sales to individual customers is based on systematic readings of customer meters generally on a monthly basis. At the end of each month, amounts of energy delivered to customers since the date of the last meter reading are estimated, and corresponding unbilled revenue is recorded. The measurement of unbilled revenue is affected by the following factors: daily customer usage, losses of energy during delivery to customers and applicable customer rates.

Increases in volumes delivered to the utilities’ customers and favourable rate mix due to changes in usage patterns in the period could be significant to the calculation of unbilled revenue. Changes in the timing of meter reading schedules and the number and type of customers scheduled for each meter reading date would also have an effect on the measurement of unbilled revenue; however, total operating revenues would remain materially unchanged.

The measurement of the expected credit loss allowance for accounts receivable requires the use of management judgment in estimation techniques, building models, selecting key inputs and making significant assumptions about future economic conditions and credit behaviour of the customers, including the likelihood of customers defaulting and the resulting losses. The Company’s current significant estimates include the historical collection rates as a percentage of revenue and the use of the Company’s historical rates of recovery across aging buckets. Both of these inputs are sensitive to the number of months or years of history included in the analysis, which is a key input and judgment made by management.

Just Energy common shares

Just Energy is authorized to issue an unlimited number of common shares with no par value and up to 50,000,000 preferred shares. Shares outstanding have no preferences, rights or restrictions attached to them.

As at September 30, 2021, there were 48,078,637 Common Shares and no preferred shares of Just Energy outstanding.

Legal proceedings

Just Energy’s subsidiaries are party to a number of legal proceedings. Other than as set out below, Just Energy believes that each proceeding constitutes legal matters that are incidental to the business conducted by Just Energy and that the ultimate disposition of the proceedings will not have a material adverse effect on its consolidated earnings, cash flows or financial position.

On March 9, 2021, Just Energy filed for and received creditor protection pursuant to the Court Order under the CCAA and similar protection under Chapter 15 of the Bankruptcy Code in the United States in connection with the Weather Event. On September 15, 2021, the Ontario Court approved the Company’s request to establish a claims process to identify and determine claims against the Company and its subsidiaries that are subject to the ongoing CCAA Proceedings. As a result of the establishment of the claims process, additional claims may be made against the Company and ultimately determined that are not currently reflected in the Interim Condensed Financial Statements.

In May 2015, Kia Kordestani, a former door–to–door independent contractor sales representative for Just Energy Corp., filed a lawsuit against Just Energy Corp., Just Energy Ontario L.P. and the Company (collectively referred to as “Just Energy”) in the Superior Court of Justice, Ontario, claiming status as an employee and seeking benefits and protections of the Employment Standards Act, 2000, such as minimum wage, overtime pay, and vacation and public holiday pay on his own behalf and similarly situated door–to–door sales representatives who sold in Ontario. On Just Energy’s request, Mr. Kordestani was removed as a plaintiff but replaced with Haidar Omarali, also a former door–to–door sales representative. On July 27, 2016, the Court granted Omarali’s request for certification, but refused to certify Omarali’s

24.

request for damages on an aggregate basis and refused to certify Omarali’s request for punitive damages. Omarali’s motion for summary judgment was dismissed in its entirety on June 21, 2019. The matter was set for trial in November 2021. However, pursuant to the CCAA Proceedings, these proceedings have been stayed. Just Energy denies the allegations and will vigorously defend against these claims, if they proceed.

On July 23, 2019, Just Energy announced that, as part of its Strategic Review process, management identified customer enrolment and non–payment issues, primarily in Texas. In response to this announcement, and in some cases in response to this and other subsequent related announcements, putative class action lawsuits were filed in the United States District Court for the Southern District of New York, in the United States District Court for the Southern District of Texas and in the Ontario Court, on behalf of investors that purchased Just Energy Group Inc. securities during various periods, ranging from November 9, 2017 through August 19, 2019.The U.S. lawsuits have been consolidated in the United States District Court for the Southern District of Texas with one lead plaintiff and the Ontario lawsuits have been consolidated with one lead plaintiff. The U.S. lawsuit seeks damages allegedly arising from violations of the United States Securities Exchange Act. The Ontario lawsuit seeks damages allegedly arising from violations of Canadian securities legislation and of common law. The Ontario lawsuit was subsequently amended to, among other things, extend the period to July 7, 2020. On September 2, 2020, pursuant to Just Energy’s plan of arrangement, the Superior Court of Justice (Ontario) ordered that all existing equity class action claimants shall be irrevocably and forever limited solely to recovery from the proceeds of the insurance policies payable on behalf of Just Energy or its directors and officers in respect of any such existing equity class action claims, and such existing equity class action claimants shall have no right to, and shall not, directly or indirectly, make any claim or seek any recoveries from any of the released parties or any of their respective current or former officers and directors in respect of any existing equity class action claims, other than enforcing their rights to be paid by the applicable insurer(s) from the proceeds of the applicable insurance policies. Pursuant to the CCAA Proceedings, these proceedings have been stayed. Just Energy denies the allegations and will vigorously defend against these claims if they proceed.

Controls and procedures

DISCLOSURE CONTROLS AND PROCEDURES

Both the chief executive officer (“CEO”) and chief financial officer (“CFO”) have designed, or caused to be designed under their supervision, the Company’s disclosure controls and procedures which provide reasonable assurance that: (i) material information relating to the Company is made known to management by others, particularly during the period in which the annual and interim filings are being prepared; and (ii) information required to be disclosed by the Company in its annual and interim filings or other reports filed or submitted under securities legislation is recorded, processed, summarized and reported within the time period specified in securities legislation. The CEO and CFO are assisted in this responsibility by a Disclosure Committee composed of senior management. The Disclosure Committee has established procedures so that it becomes aware of any material information affecting Just Energy to evaluate and communicate this information to management, including the CEO and CFO as appropriate, and determine the appropriateness and timing of any required disclosure. Based on the foregoing evaluation, conducted by or under the supervision of the CEO and CFO of the Company’s Internal Control over Financial Reporting (“ICFR”) in connection with the Company’s financial year–end, it was concluded that because of the material weakness described below, the Company’s disclosure controls and procedures were not effective.

INTERNAL CONTROL OVER FINANCIAL REPORTING

Management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”) in Internal Control – Integrated Framework (2013) to evaluate the effectiveness of its ICFR as at March 31, 2021. The COSO framework summarizes each of the components of a company’s internal control system, including the: (i) control environment; (ii) control activities (process–level controls); (iii) risk assessment; (iv) information and communication; and (v) monitoring activities. The COSO framework defines a material weakness as a deficiency, or combination of deficiencies, that results in a reasonable possibility that a material misstatement of the annual or Interim Condensed Consolidated Financial Statements will not be prevented or detected on a timely basis.

Identification and ongoing remediation of material weakness within financial statement close process

Management’s evaluation of ICFR identified an ongoing material weakness resulting from the failure to operate several controls within the financial statement close process that allowed errors to manifest, and, the failure to detect them for an extended period of time, as follows:

25.

Previous Identification of control activities material weakness within financial statement close process

The Company did not design or maintain effective control activities to prevent or detect misstatements during the operation of the financial statement close process, including from finalization of the trial balance to the preparation of financial statements.

Ongoing remediation of previously identified control activities material weakness associated with financial statement close process

Management remains committed to the planning and implementation of remediation efforts to address the material weaknesses, as well as to foster improvement in the Company’s internal controls. These remediation efforts continue and are intended to address this identified material weakness and enhance the overall financial control environment. During the year ended March 31, 2021, management further increased the amount of personnel to perform the financial statement close process, including the hiring of a CFO and a controller, both with significant financial reporting and retail energy industry experience, promoting individuals within the team and training those individuals to perform their enhanced roles, and strengthening the managerial review process of the financial statement preparation. Management will continue to enhance the control environment and assess if the Company requires additional control and accounting individuals to operate the controls as designed, and provide additional training as required. These enhancements remain ongoing, and management continues strengthening the design and operational effectiveness of the financial statement preparation process; however, not enough time has elapsed to complete remediation efforts of this material weakness.

No assurance can be provided at this time that the actions and remediation efforts the Company has taken or will implement will effectively remediate the material weaknesses described above or prevent the incidence of other significant deficiencies or material weaknesses in the Company’s internal controls over financial reporting in the future. The design of any system of controls is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving the stated goals under all potential future conditions.

Other changes in internal control over financial reporting

Other than as described above, there were no changes in ICFR during the last fiscal quarter that materially affected, or are reasonably likely to materially affect, ICFR.

INHERENT LIMITATIONS

A control system, no matter how well conceived and operated, can only provide reasonable, not absolute, assurance that its objectives are met. Due to these inherent limitations in such systems, no evaluation of controls can provide absolute assurance that all control issues within any company have been detected. Accordingly, Just Energy’s disclosure controls and procedures are designed to provide reasonable, not absolute, assurance that the Company’s disclosure control and procedure objectives are met.

Corporate governance

Just Energy is committed to maintaining transparency in its operations and ensuring its approach to governance meets all recommended standards. Full disclosure of Just Energy’s compliance with existing corporate governance rules is available at investors.justenergy.com https://investors.justenergy.com/and is included in Just Energy’s Management Proxy Circular. Just Energy actively monitors the corporate governance and disclosure environment to ensure timely compliance with current and future requirements.

26.

Just Energy (JENGQ) 6-KInterim Condensed Consolidated Statements of Financial Position