UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10

 

GENERAL FORM FOR REGISTRATION OF SECURITIES
Pursuant to Section 12(b) or (g) of the Securities Exchange Act of 1934

 

PETROTEQ ENERGY, INC.

(Exact name of registrant as specified in its charter)

 

Ontario   None

(State or other jurisdiction of

incorporation or organization)

 

(I.R.S. Employer

Identification No.)

 

15165 Ventura Blvd., #200 Sherman Oaks, California   91403
(Address of principal executive offices)   (Zip Code)

 

Registrant’s telephone number, including area code: (866) 571-9613

 

Copies to:

 

Leslie Marlow, Esq.

Hank Gracin, Esq.

Gracin & Marlow, LLP

The Chrysler Building

405 Lexington Avenue, 26th Floor

New York, New York 10174

 

Securities to be registered pursuant to Section 12(b) of the Act: None

 

Title of each class to be so registered   Name of each exchange on which each class is to be registered

 

Securities to be registered pursuant to Section 12(g) of the Act:

 

Common Shares, without par value

 

(Title of class)

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” “smaller reporting company” and an “emerging growth company” as defined in Rule 12b-2 of the Exchange Act.

 

Large accelerated filer Accelerated filer
Non-accelerated filer Smaller reporting company
    Emerging growth company

 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act ☒

 

 

 

 

 

  

INFORMATION REQUIRED IN REGISTRATION STATEMENT

Table of Contents

 

    Page No.
     
Item 1. Business.   1
     
Item 1A. Risk Factors.   13
     
Item 2. Financial Information.   27
     
Item 3. Properties.   36
     
Item 4. Security Ownership of Certain Beneficial Owners and Management.   38
     
Item 5. Directors and Executive Officers.   39
     
Item 6. Executive Compensation.   41
     
Item 7. Certain Relationships and Related Transactions, and Director Independence.   45
     
Item 8. Legal Proceedings.   46
     
Item 9. Market Price of and Dividends on the Registrant’s Common Equity and Related Stockholder Matters.   46
     
Item 10. Recent Sales of Unregistered Securities.   48
     
Item 11. Description of Registrant’s Securities to be Registered.   52
     
Item 12. Indemnification of Directors and Officers.    56
     
Item 13. Financial Statements and Supplementary Data.    56
     
Item 14. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.    56
     
Item 15. Financial Statements and Exhibits.    56

  

i

 

 

ITEM 1. BUSINESS.

  

BUSINESS OVERVIEW

 

We are a Canadian-registered holding company that is engaged in various aspects of the oil and gas industry. Our primary focus is on the development and implementation of our proprietary oil sands mining and processing technology to recover oil from surface mined bitumen deposits. Our wholly owned subsidiary, Petroteq Energy CA, Inc., a California corporation (PQE), conducts our oil sands extraction business through its two wholly owned active subsidiary companies, Petroteq Oil Sands Recovery, LLC, a Utah limited liability company (“PQE Oil”), and TMC Capital, LLC, a Utah limited liability company (“TMC”). Our newly formed indirect subsidiary, Petrobloq, LLC, a California limited liability company  (“Petrobloq”), also wholly owned by PQE, is developing a blockchain-powered supply chain management platform for the oil and gas industry. In addition, we own a 44.7% interest in Accord GR Energy, Inc., a Delaware corporation (“Accord”), which uses two oil enhanced recovery technologies that it licenses from one of its affiliated entities to conduct its exploration work. We also own a 25% interest in Recruiter.com Oil and Gas Group LLC, a Delaware limited liability company (“Recruiter. OGG”), a recruitment venture that provides a website focused on careers in the oil and gas industry.

 

 

OIL SANDS MINING

 

PQE, through its wholly owned subsidiaries PQE Oil and TMC, is in the business of oil sands mining and processing. Historically, all of PQE’s oil sands mining has occurred on a leased property in Asphalt Ridge, Utah where it mines surfaced bitumen deposits. Once mined, the bitumen deposits are processed at a facility owned by PQE using PQE’s proprietary extraction technology. In 2016, PQE Oil’s mining operations were temporarily suspended due to the relocation of its plant to the location of the TMC mineral lease described below where the mining activities occur to improve logistical and processing efficiencies and increase production capacity. PQE recommenced its oil sands mining activities at the end of May 2018 and production at full capacity is expected in the last quarter of fiscal 2019.

 

Oil Sands Exploration and Processing Plant 

 

In June 2011, PQE commenced the development of an oil sands extraction facility at Maeser, Utah and entered into construction and equipment fabrication contracts for the purpose of applying its proprietary extraction technology (the “Extraction Technology”) described below to the oil extracted from the bitumen mined on the leased property described below. By January 2014 the initial facility was fully permitted and construction was completed by October 1, 2014. This was a pilot plant with the production capacity of up to 250 barrels per day. The Extraction Technology has been tested at full capacity. During 2015, the plant produced 10,000 barrels of oil from the local oil sands ore in Asphalt Ridge including PQE’s own Temple Mountain oil sands deposit. Most of the produced oil was sold to an oil and gas distributor for resale to their refinery customers. The initial processing plant was flexible in that it had the ability to produce both high quality heavy crude oil as well as the lighter oil if needed.

 

1

 

  

In 2015, with the sharp decline in oil prices, PQE determined that the transportation costs of hauling the ore from the mining site to the processing facility was having a detrimental effect on the economics of the extraction operation and in 2016 temporarily suspended operations. In 2017, the plant was disassembled and moved from the Maeser, Utah mining site to the Temple Mountain mining site and has been rebuilt at that location. During the reassembly of the facility, additional equipment has been installed to increase the capacity of the plant from 250 barrels per day to 1,000 barrels per day. In May 2018, the mining operations at the Temple Mountain oil sands deposits recommenced and the new processing plant commenced a test production phase of heavy crude oil from the Temple Mountain oil sands deposits, production at full capacity is not anticipated until the last quarter of fiscal 2019. Management’s current estimate of the total cost of the facility, including the expansion of the production capacity of the facility in order to meet the existing requirements of the TMC Mineral Lease, exclusive of capitalized borrowing costs and lease costs, is between $28 million and $30 million.

 

Resources and Mining Operations

 

Through its acquisition of TMC on June 1, 2015, PQE indirectly acquired certain mineral rights under a Mining and Mineral Lease Agreement, dated as of July 1, 2013, between Asphalt Ridge, Inc., as lessor, and TMC, as lessee, covering lands consisting of approximately 1,229.82 acres near Temple Mountain area in Asphalt Ridge, Utah (the “TMC Mineral Lease”). More recently, PQE Oil acquired mineral rights under two mineral leases entitled “Utah State Mineral Lease for Bituminous-Asphaltic Sands”, each dated and made effective on June 1, 2018, entered into between the State of Utah’s School and Institutional Trust Land Administration (“SITLA”), as lessor, and PQE Oil, as lessee, covering lands in Asphalt Ridge that largely adjoin the lands held under the TMC Mineral Lease (collectively, the “SITLA Mineral Leases”). At this time, PQE (through its subsidiaries) holds mineral leases encompassing a total of 2,541.76 acres in the Asphalt Ridge areas, consisting of 1229.82 acres currently held under the TMC Mineral Lease, and an additional 833.03 acres and 478.91 acres, respectively, held under the SITLA Mineral Leases.

 

The following table sets forth the gross and net developed and undeveloped acreage held under the TMC Mineral Lease.

  

TMC Mineral Lease

Developed/Undeveloped Acreage (Gross/Net)

Total Acreage  
Gross Acres (Working Interests & Royalty) 1229.82 acres
Net Acres (100% Working Interests, less Royalty) 1111.76 acres
Developed Acreage  
TME AR Mine #1/Permit Boundaries  
Gross Acres (Working Interests & Royalty) 174.00 acres
Net Acres (100% Working Interests, less Royalty) 157.30 acres
Undeveloped Acreage  
Acreage Outside TME AR Mine #1/Permit Boundaries  
Gross Acres (Working Interests & Royalty) 1055.82 acres
Net Acres (100% Working Interests, less Royalty) 954.46 acres

 

The TMC Mineral Lease and the lands covered thereby are in the Asphalt Ridge area of northeastern Utah. Asphalt Ridge is located along the northern edge of the Uintah Basin and contains a number of oil sands deposits located on the margins of the basin. Most of the oil-impregnated reservoirs or deposits in the Asphalt Ridge area are found in the Rimrock Sandstone (Mesaverde Group Formations) and in the (Tertiary) Duchense River Formation. Substantial bitumen deposits in the Rimrock and Duchense River Formations extend from the northwest in a southeasterly direction through a substantial part (almost all) of the lands included in the TMC Mineral Lease, particularly the acreage located in T5S-R21E (Section 25) and T5S-R22E (Section 31) where the TME AR Mine #1 is located. Bitumen-saturated pay thicknesses existing within the lands covered by the TMC Mineral Lease generally range from 50-200 feet, with some areas of the deposits approaching 300 feet in pay thickness. PQE expects that oil sands (bitumen) deposits may be mined economically at depths up to 250-300 feet below the surface.

 

The following table sets forth the total gross and total net undeveloped acreage of the SITLA Leases.

 

SITLA Leases
Developed/Undeveloped Acreage (Gross/Net)
SITLA Mineral Lease #53806  
Total Gross Acres (Working Interests & Royalty) 833.03 acres
Total Net Acres (100% Working Interests less royalty) 766.39 acres
   
SITLA Mineral Lease #53807  
Total Gross Acres (Working Interests & Royalty) 478.91 acres
Total Net Acres (100% of Working Interests less royalty) 440.60 acres
   
All Acreage is Currently Undeveloped  

 

The TMC Mineral Lease

 

Under the TMC Mineral Lease, TMC has the exclusive right to explore for, mine and produce oil and other minerals associated with oil sands, subject to certain depth limits. The TMC Mineral Lease was amended on October 1, 2015 and further amended on March 1, 2016, on February 21, 2018, and most recently on November 21, 2018. The primary term (the “Primary Term”) of the TMC Mineral Lease, as amended, commenced July 1, 2013 and continues for six years, plus an extension period. The term “extension period” is defined as a period of time measured from March 1, 2018 to the earlier of (i) March 1, 2019, or (ii) the date on which TMC delivers to the lessor a written financial commitment for the construction of PQE’s second proposed facility (or an expansion to the existing processing facility located on the Lease).

 

2

 

  

During the Primary Term, if TMC fails to satisfy the requirements of “continuous operations”, the TMC Primary Lease will terminate unless the parties agree in writing to continue the Lease. If TMC, at the end of the Primary Term, has satisfied the requirements of continuous operations, the TMC Mineral Lease will continue in effect beyond the Primary Term as long as TMC continues to comply with any applicable requirements of continuous operations. Under the Lease, the term “continuous operations” consists of the following two requirements:

 

Processing Capacity. TMC must construct or operate one or more facilities (or any expansion to an existing facility) having the capacity to produce an average daily quantity (“ADQ”) of oil other hydrocarbon products from oil sands mined or extracted from the Lease that, in the aggregate will achieve (or exceed) the following:

 

By 07-01-2019, at 80% of an ADQ of 1,000 barrels/day;

By 07-01-2020, at 80% of an ADQ of 2,000 barrels/day; and

By 07-01-2021 (and for the remaining term of the Lease), at 80% of an ADQ of 3,000 barrels/day.

  

Minimum Operations. From and after July 1, 2019, TMC must achieve oil sands processing operations that equal (or exceed) the applicable ADQ requirements specified above either (i) during at least 180 days in each lease year, or (ii) during at least 600 days in any three consecutive lease years.

 

The TMC Mineral Lease is also subject to termination under the circumstances described below:

 

  (i) Termination will be automatic if there is a lack of a written financial commitment to fund PQE’s proposed second 1,000 barrels per day processing facility or expansion of its current facility to an additional 1,000 barrels per day prior to July 1, 2019 or a lack of a written financial commitment to fund a proposed third 1,000 barrels per day processing facility or expansion of its current facility to an additional 1,000 barrels per day prior to July 1, 2020.  We further expect the cost of constructing each of these two proposed facilities or expansion of our current facility will range between $10 million and $12 million, which we intend to fund from revenue derived from operations, which to date have been minimal and/ or third party funding sources for which we have no commitment to date.  See Risk Factors- “Our operations are dependent upon us maintaining our mineral lease for the Asphalt Ridge Property”).

 

  (ii) Cessation of operations or inadequate production due to increased operating costs or decreased marketability and production is not restored to 80% of capacity within three months of any such cessation will cause a termination.

 

  (iii) Cessation of operations for longer than 180 days during any lease year or 600 days in any three consecutive years will cause a termination.

 

  (iv)

A failure of PQE’s proposed expansion or alternatively, three 1,000 barrels per day plants, to produce a minimum of 80% of their rated capacity for at least 180 calendar days during the lease year commencing July 1, 2021 plus any extension periods will cause a termination.

 

  (v) PQE may surrender the lease with 30 days written notice.

 

  (vi) In the event of a breach of the material terms of the lease, the lessor will inform the lessee in writing and PQE will have 30 days to cure financial breaches and 150 days to cure any other non-monetary breach.

  

In addition, PQE is required to make certain advance royalty payments to the lessor as described below. Future advance royalties required are:

 

  (i) From July 1, 2018 to June 30, 2020, minimum payments of $100,000 per quarter.

 

  (ii) From July 1, 2020, minimum payments of $150,000 per quarter.

 

  (iii) Minimum payments commencing on July 1, 2020 will be adjusted for CPI inflation.

 

Production royalties payable under the TMC Mineral Lease, as amended, are eight percent (8%) of the gross sales revenue, subject to certain adjustments up until June 30, 2020. After that date, royalties will be calculated on a sliding scale based on crude oil prices ranging from 8% to 16% of gross sales revenues, subject to certain adjustments.

 

We are currently in full compliance with the terms of the TMC Mineral Lease. As of November 30, , 2018, we have paid advance royalties of $1,990,336 (August 31, 2018 - $1,890,336) to the lessor, of which a total of $1,125,000 have been used to pay royalties as they have come due under the terms of the TMC Mineral Lease. During the three months ended November 30, 2018 and the year ended August 31, 2018, $100,000 and $534,296 in advance royalties were paid and $33,750 and $272,333, respectively, have been used to pay royalties which have come due. The royalties expensed have been recognized in cost of goods sold on the consolidated statement of loss and comprehensive loss.

 

3

 

  

Minimum expenditures to be incurred on the leased property are $2,000,000 per year commencing July 1, 2021 if a minimum daily production of 3,000 barrels per day during a 180 day period is not achieved.

 

During the three months ended November 30, 2018 and the fiscal years ended August 31, 2018, August 31, 2017 and 2016 we did not have any sales from production related to the TMC Mineral Lease as we temporarily suspended operations while we relocated our oil sands extraction facility and commenced an expansion of the production facility. Our average sales from production and average costs of production related to the TMC Mineral Lease during the fiscal year ended August 31, 2015 were as follows:

 

i) Average sales price for fiscal year 2015

 

Month 

Average

Sales Price

   Net Barrels1 
August  $30.39    1,277.00 
September  $32.97    1,926.53 
October  $33.79    1,866.99 
November  $30.42    898.21 
December  $24.83    1,808.60 
Total        7,777.33 

  

1The calculation of the “Net Barrels” produced is based on the exclusion of any applicable state severance (production), ad valorem or sale taxes, royalty interests, and third-party non-operating working interests under the TMC Mineral Lease.

 

ii) Average production costs for fiscal year 2015

 

Month 

Average

Production

Cost

 
August  $28.38 
September  $29.75 
October  $29.26 
November  $26.25 
December  $22.15 

  

The costs involved in PQE’s Extraction Technology process include: the costs for oil sands ore, natural gas liquids, aromatic solvent, operator labor, electricity, propane, nitrogen, water, diesel fuel and rental equipment.  The primary costs are the costs of the oil sand ore, natural gas liquid, aromatic solvent, and labor costs.  Other than the aromatic solvent, the solvents used in the Extraction Technology process are produced by PQE by processing natural gas liquids through the distillation column.  The aromatic solvent is added to the distillate. The fixed costs per barrel based upon current pricing is as follows: operator labor ($3.77 per barrel), electricity ($0.63 per barrel), propane ($0.94 per barrel), nitrogen ($0.25 per barrel), water ($0.31 per barrel), diesel fuel ($0.31 per barrel) and rental equipment ($0.93 per barrel) the fixed costs remain the same regardless of the API as does the cost for the oil sands ore (two tons of oil sands ore are required per barrel regardless of the API being produced).  The cost of the solvent increases per barrel based upon the desired API, the higher the API the higher the cost (ranging from $2.62 per barrel for an API of 15.7 to $16.27 for an API of 42, all based on current prices). We further do not expect our operating costs to materially change as the depth of the open pit at Asphalt Ridge increases over time, and further anticipate various economies of scale, such as bulk purchases, could reduce average production costs per barrel as operating capacities are increased.

 

The API gravity for the raw heavy oil or bitumen extracted from oil sands ores initially treated at the Asphalt Ridge plant average approximately 10 degrees. Through the application of our Extraction Technology at the plant, a new or distinct crude oil is produced having a range of API gravity of between 20 degrees and 35 degrees. Through the use of our solvent formulation and the select distillation capabilities, the plant is able to draft a final crude oil product to meet the specifications of a range of customers (and pipeline).

 

We initially sold our finished crude oil product directly to a refinery customer at a price representing a discount to West Texas Intermediate Crude benchmark market price. The purchaser took delivery of the finished crude oil product at or near the plant and transported it to a refinery in Nevada. The specifications of the finished crude oil produced at the plant were effectively tailored to meet customer (pipeline and refinery) specifications.

 

4

 

  

The SITLA Leases

 

The SITLA Leases have a primary term of ten (10) years, and will remain in effect thereafter for as long as (a) bituminous sands are produced in paying quantities, or (b) PQE is otherwise engaged in diligent operations, exploration or development activity and certain other conditions are satisfied. Generally, the SITLA Leases will not continue in effect after the 20th anniversary of their effective dates except by production of leased substances in paying quantities. An annual minimum royalty of $10 an acre must be paid during the first ten years of the SITLA Leases; from and after the 11th year of the leases, the annual minimum royalty may be adjusted by the lessor based on certain “readjustment” provisions in the SITLA Leases. Annual minimum royalty paid in any lease year may be credited against production royalties accruing in the same year.

 

The SITLA Leases provide that PQE must pay: (i) an annual rent equal to the greater of $1 an acre or a fixed sum of $500 (without regard to acreage); and (ii) a production royalty of 8% of the market price received by it for products produced from the leases at the point of first sale, less reasonable actual costs of transportation to the point of first sale (with the royalty rate subject to increase on or after the 10th anniversary of the lease, subject to a 12.5% cap during the term thereof, and a proviso that production royalties under the leases shall never be less than $3.00/bbl during the term of the leases). As the sole lessee under the SITLA Leases, PQE owns 100% of the working interests under the leases, subject to payment of annual rentals, advance annual minimum royalty, and production royalties.

 

Permits and Taxes

  

On September 15, 2008, a large mining permit was granted to TME Asphalt Ridge, LLC by the State of Utah Division of Oil, Gas, and Mining (“UDOGM”) for the mining and development of the TME AR Mine #1, an open pit mine located on TMC Mineral Lease.

 

On or about July 9, 2015, UDOGM approved an application filed by TMC to transfer the “Notice of Intention to Commence Large Mining Operations” for the TME AR Mine #1 (Permit # M/047/0089) from TME Asphalt Ridge LLC to TMC. On October 27, 2017, UDOGM granted final approval to TMC’s “Amended Notice of Intention to Commence Large Mining Operations” and issued final Permit # M/047/0089 authorizing TMC to conduct operations at TME AR Mine #1. On or about August 6, 2018, PQE Oil filed an amended “Notice of Intention to Commence Large Mining Operations” at the TME AR Mine #1, primarily for the purpose of notifying UDOGM that PQE Oil will be the operator under the TMC Minerals Lease and to provide an update on the mining and oil sands processing plan developed by PQE Oil for the TME AR Mine #1. The August 2018 Notice of Intention to Commence Large Mining Operations is currently pending with UDOGM and we anticipate its approval in early 2019.

 

Mining operations, including the initial development of the mine at the property and removal of the overburden soil layer has already been performed. In addition to the mining permits, all environmental, construction, utility and other local permits necessary for the construction of the plant and the processing of the oil sands have been granted to PQE.

 

Specifically, a Groundwater Discharge Permit was issued by the Utah Department of Environmental Quality (Division of Water Quality, Water Quality Board), on July 26, 2016 (expiration on July 27, 2021), covering disposal of tailings from ore sands produced from the land area encompassed by the TME AR Mine #1. This permit was required by Utah law even though our processing facility does not use a water-based process and authorizes a return of residual sand tailings to the mine for backfill and capping. A Small Source Registration air permit was issued by the Utah Department of Environmental Quality by a letter dated November 2, 2018. The letter confirms that our processing facility at Asphalt Ridge is exempt from any requirement of additional air quality permits since the facility produces less emissions than the level that would require a special air permit. A Conditional Use Permit (CUP) was issued by the Uintah County (Utah) Commission to us on January 29, 2018, for the operation of our current processing facility. The CUP is a right/interest in land under Utah law and will continue in effect in perpetuity. A local business license was issued to PQE Oil by the County Commission of Uintah County, Utah on November 19, 2018. The business license must be renewed annually on payment of a license renewal fee.

 

5

 

  

The oil and gas properties (including plants, equipment etc.) included in or under the TMC Mineral Lease are subject to the State of Utah’s property (ad valorem) tax. The actual tax rate is established by each county in the State (and therefore may vary) and is generally assessed against the “fair market value” of the property. Under Utah Code § 59-2-1103, the oil and gas properties included in the SITLA Leases are exempt from the State’s property (ad valorem) tax (although this exemption does not apply to improvements on state lands).

 

Under Utah Code § 59-5-120, beginning January 1, 2006 and ending June 30, 2026, no severance (production) tax will be imposed on oil and gas produced from oil sands (tar sands). Accordingly, severance tax will not be owed to the State of Utah on the production of oil and hydrocarbon substances from the TMC Mineral Lease or the SITLA Leases until after June 30, 2026.

 

Extraction Technology

 

PQE intends to continue to develop its operations by processing purchased native oil sands ore, as well as native oil sands ore produced through the mining operations of its subsidiary (TMC) using its patented closed loop, continuous flow, scalable and environmentally safe Extraction Technology. The Extraction Technology process allows the extraction of hydrocarbons from a wide range of both “water- wet” and/or “oil-wet” oil sands deposits and other hydrocarbon sediment types. PQE’s oil extraction process takes place in a completely closed loop system that continuously re-circulates and recycles the solvent after it has completely separated the asphalting and heavy oils from the oil sands. The closed loop system is capable of recovering over 99% of the all hydrocarbons from the oil sands, making this technology very environmentally friendly. The only two end products of the process are high quality heavy oil and clean sand.

 

The Extraction Technology, which has been modified since 2015 and unlike the technology utilized in 2015, utilizes no water in the process, is anticipated to produce no greenhouse gases, requires no high temperature and/or pressure for the extraction process, and expects to extract up to 99% of all hydrocarbon content and recycle up to 99% of the solvents. The proprietary solvent composition consists of hydrophobic, hydrophilic and polycyclic hydrocarbons. It is expected to dissolve up to 99% of heavy bitumen/asphalt and other lighter hydrocarbons from the oil sands, and prevent their precipitation during the extraction process. Solvents used in this composition form an azeotropic mixture which has a low boiling point of 70 – 75 C degrees and it is expected to allow recycling of over 99% of the solvent. These features, in the event they produce as anticipated by PQE, make it possible to perform hydrocarbon extraction from oil sands at mild temperatures of 50 – 60 degrees C, with no vacuum or/and pressure applied that would lead to high energy and economic efficiency of the extraction of oil from the overall oil sands extraction process.

  

In the oil extraction process, depending upon the customer’s request for an API level (the extracted bitumen starts from the ground at an average API gravity of 10 degrees), through the use of a distillation process and a solvent which we develop ourselves from natural gas condensate, ordinary chemicals and recycled solvent (the solvent can be used at least four times), the hydro-carbons in the extracted bitumen are manipulated. The higher the temperature, the higher the resultant API, more hydrocarbons are removed and more solvent is used. The crude oil produced and sold to the customer is not bitumen and not solvent, it is not a “blend” of separate products and does not include diluent. It is a hydro-carbon, a distinct product having its own specifications.

 

As such, in the refining process no diluents or blending agents are used to increase the viscosity of the heavy oil extracted from bitumen saturated ores. Instead, varying amounts of solvent is introduced into a mixing tank with a raw bitumen-saturated stream generated from the initial treatment of mined or extracted oil sands ores and sands (via crushing etc.). The solvent is designed to release crude oil from bitumen-saturated sandstones during processing. This process yields an unfinished crude oil containing the solvent on the one hand, and a second residual consisting of clean sand (containing little to no hydrocarbons).

 

The oil extraction process has a reboiler, distillation column at the top of the reboiler, heat exchangers, air fin condenser, and a utility boiler plus propane tank as the energy source. Reboiler and distillation column are used to recycle the solvent. The hydrocarbon stream containing the solvent is then subjected to a distillation process where the solvent is recovered and recycled for reuse in future process streams. The oil-solvent mixture is heated up at the reboiler to the solvent’s boiling temperatures, overheated vapors travel through the distillation column and solvents are condensed back into the liquid in the air fin cooler and returned back into the process.

 

During the recovery of the solvent through reboiling and distillation, the plant’s engineering and technical personnel are able to select the hydrocarbon chains in the condensate/solvent that are to be flashed off and recovered for recycled reuse in the plant, which in turn produces a crafted finished crude oil. In other words, by selectively stripping or flashing off different hydrocarbon chains from the condensate in the solvent (whether it the heavier hydrocarbons such as the C5 pentanes/pentenes or C6 hexanes, or the lighter hydrocarbons such as methane (C1), ethane (C2), propane (C3) and the butanes (C4), plant personnel are able, by design, to use the condensate component of the solvent as a feedstock to produce a relatively sweet heavy to medium crude oil (with an API gravity in the 20-30 degree range) or a sweet lighter crude oil (with an API gravity in the 30-40 degree range).

 

6

 

  

As part of a hydrocarbon refining process utilizing basic chemistry, the natural gas condensate used in the solvent serves dual functions of (1) a solvent that effectively causes a release of heavy oil from the bitumen-saturated stream, and (2) a feedstock that, during distillation or reboiling with a second feedstock consisting of the heavy crude oil stream extracted from bitumen, produces a finished crude oil product. The solvent that is not recovered in the refining process effectively acts as a feed stock to produce the crude oil.

 

While the initial tests of the Extraction Technology in 2015 did not include recycling of the solvents, PQE’s revised Extraction Technology process is expected to be able to recycle over 99% of the solvent, based, among other things, on the results of third party tests of the different batches of the heavy oil that have been produced.

 

Another key element of the PQE Extraction Technology process is applying its own extractor, based on a proprietary/patented “liquid fluidized bed” solvent extraction system for bitumen/oil from oil sands extraction. A “liquid fluidized bed” style reactor is anticipated to provide continuous mixing of the (liquid) solvent and the solid ore particles. It is intended to allow a continuous flow process with optimal material/mass/energy balances. PQE’s solvent based technology uses only a fraction of the energy needed to produce a barrel of oil from the water-based technologies used in Canada. PQE’s process also employs multiple energy saving technologies to reduce energy consumption even further. This has resulted in a high level of energy efficiency during the oil extraction process. PQE’s patented design also includes exceptionally efficient heat exchange and distillation/rectification systems. This energy efficiency makes extraction facilities economical to operate.

 

PQE has obtained issued patents in the United States, Canada and Russia that protect its proprietary Extraction Technology. See “Intellectual Property” below.

 

On March 27, 2013, PQE entered into an intellectual property license agreement in a private arm’s length transaction with a Canadian company, TS Energy Ltd., which has agreed to act as the sole and exclusive licensee of the Extraction Technology within Canada and the Republic of Trinidad and Tobago.

  

INTELLECTUAL PROPERTY

 

We rely upon patents to protect our intellectual property. We have obtained issued patents in the United States, Canada and Russia that protect our proprietary Extraction Technology. The following sets forth details of our issued patents.

 

DOCKET   TITLE   COUNTRY  

DATE FILED

SERIAL NO.

 

DATE ISSUED

PATENT NO./STATUS

1492.2  

Oil From Oil Sands

Extraction Process

  USA  

09/26/12

13/627,518

-----------------------

10/07/11

61/545,034

 

02/06/18

9,884,997

Expires: 10/07/31

 

Summary: A system for extracting bitumen from oil sands includes an extractor tank which incorporates a plurality of jet injectors. Operationally, the jet injectors provide jet streams of an extractant in the extractor tank that creates a fluidized bed of the extractant. A reaction between crushed oil sands and the fluidized bed then separates bitumen from the oil sands.

 

Corresponding Foreign Patent Properties

 

11492.2a   Oil Extraction Process   Canada  

09/30/11

2,754,355

  Received Notice of Allowance; patent payment submitted to Commission of Patents
                 
11492.2d  

Oil From Oil Sands

Extraction Process

  Russia  

04/28/14

2014117162

 

12/20/15

2571827

Expires: 09/27/2032

 

THE OIL SANDS MARKET

  

As an unconventional hydrocarbon resource, oil sands hold hundreds of billions of barrels of oil on a worldwide basis. Although Canada is the only country that is currently extracting large quantities of oil from its oil sands deposits, the United States also has large oil sands resources that can be developed. In a 2007 Report entitled “A Technical, Economic, and Legal Assessment of North American Oil Shale, Oil Sands, and Heavy Oil Resources In Response to Energy Policy Act of 2005 Section 369(p)” (September 2007), prepared by the Utah Heavy Oil Program, Institute For Clean and Secure Energy and The University of Utah for the U.S. Department of Energy (the “2007 Report”), the authors reported the following:

 

  The United States has an estimated 76 billion barrels of oil-in-place (OIP)1 from bitumen and heavy oil contained in oil sands resources, consisting of proven or measured OIP (22.5 billion barrels) and speculative OIP (53.6 billion barrels);

  

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  In the United States, Utah is known to have the largest oil sands deposits, with total resource estimates ranging from 23 to 32 billion barrels of OIP from bitumen and heavy oil contained in oil sands formations and deposits. This total resource estimate range may be subdivided into proven or measured OIP (11.6 to 22.5 billion barrels) and speculative OIP (20.7 to 53.6 billion barrels); and

 

 

Within the state of Utah, the region that has experienced the most oil sands development, both in terms of existing oil production and supporting infrastructure, is the Asphalt Ridge area located on the northern edge of the Uintah Basin in eastern Utah. In the 2007 Report, it is estimated that about one (1) billion barrels of OIP exist in the form of bitumen and heavy oil contained in oil sands formations and deposits in the Asphalt Ridge area. This estimate of total oil sand resources consists of proven or measured OIP (435 million barrels); probable OIP (438 million barrels); and possible OIP (175 million barrels).

  

From our own investigation of the oil sands deposits in the Asphalt Ridge area, we believe that a substantial part of the oil sands deposits in this area are accessible through outcroppings or in shallow depths with limited or no overburden. In our view, the location and accessibility of oil sands deposits in Asphalt Ridge create an opportunity for commercial development, supported by positive economics, using surface mining techniques and our extraction technology.

  

The worldwide growing demand for heavy crude oil and the recent decline in heavy crude oil production in countries such as Venezuela, makes the high quality, low sulfur, heavy oil found in oil sands deposits in the United States a valuable resource that has been underdeveloped to date. The development of “tight shale” oil plays in the United States has produced significant quantities of light, sweet crude oil reserves, but heavy oil development in the United States has lagged. The development of oil sands domestically has the potential to turn the United States into a major supplier of heavy oil to world markets. To date, oil sands development has been limited by the absence of a viable technology that can extract the heavy oil from the oil sands deposits in an economical and environmentally responsible manner. To that end, PQE has developed, and patented an extraction technology that aims to develop oil sands reserves in an economical and environmentally responsible manner. PQE is currently expanding its commercial oil sands extraction operations in Asphalt Ridge, Utah utilizing a process that is economical, environmentally friendly and produces high quality heavy oil.

  

1.OIP are not estimates of reserves or recoverable resources. Moreover, OIP estimates indicated as “probable”, “speculative” or “possible” carry greater risks of uncertainty than resources that are “proven” or “measured”.

  

We have tested our Extraction Technology both in Asphalt Ridge and with oil sands sourced from different parts of the world and having different hydrocarbon chemical compositions. To date, we have conducted tests with oil sands from Russia, China, Indonesia and the Middle East. Our tests with Russian oil sands, conducted in Ufa, Bashkorkostan (Russia) using a multi-ton pilot plant, used a local oil sands ore with oil saturation in a range of 7-10%, resulted in the industrial quantities of heavy oil. Other tests, consisting of oil sands samples from China, Indonesia and Jordan, were conducted at PQE’s laboratory in San Diego using lab bench testing with our own solvent blend. By introducing the solvent mixture to crushed and treated ore containing bitumen oil, the oil was separated by recycling the solvent with a laboratory-scale rotor vacuum evaporator. Sand tailings were separated by centrifugation and dried under the vacuum.

 

Through our testing of oil sands sourced from different countries, we found that the efficiency and consistency of PQE’s extraction technology are not affected by differences in the chemical composition of the oil/bitumen in the oil sands. Despite relatively significant differences in oil/bitumen chemistry, both the efficiency and consistency of our extraction technology remained intact, resulting in an oil recovery efficiency that in each test exceeded 99%. We believe that this testing demonstrates that PQE’s extraction process is universal in its application and does not depend on the material source or the hydrocarbon content or fingerprint.

 

ACCORD ACQUISITION

 

Since July 4, 2016, when we acquired a 57.3% interest in Accord, which has subsequently been diluted down to 44.7% by third party equity investments into Accord, we have also been engaged in the recovery of heavy oil. Accord has been utilizing two technologies licensed to it from certain of its affiliated entities. The licenses allow Accord to utilize the technologies on any oil field it acquires. The first technology, known as SWEPT, is designed to recover hydrocarbons from wells and structures with low pressure or no energy drive mechanism, from residual or partially depleted properties in mature fields, and from structures having complex geophysical matrices or that contain tight oil, in each case by improving rock and fluid properties through the introduction of directed energy waves. The second technology, known as S-BRPT, is designed to recover solid and liquid hydrocarbons through conversion to gaseous forms followed by well-based recovery at greater depths, combining both specially designed on-site well production and recovery methodologies. Accord is currently utilizing these licensed technologies on parts of the 7,000 acres under mineral leases that it acquired in 2016 located in southwest Texas, which include 81 shallow oil wells that historically had limited production. To date, Accord has drilled three new wells on these properties and the fields treated with the technology licensed by Accord is expected to increase oil production, although commercial production has not commenced as yet.

 

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PETROBLOQ, LLC

  

In November 2017, through our wholly owned subsidiary, PQE, we formed a subsidiary Petrobloq. Petrobloq has entered into an agreement with First Bitcoin Capital Corp. (“FBCC”), a global developer of blockchain-based applications, to design and develop a blockchain-powered supply chain management platform for the oil and gas industry. The platform is being designed to be a “one-stop shop” that will provide both small and large oil and gas producers and operators with the ability to customize their own distributed ledger modules that will permit each company, in a secure “closed” environment, to document, track, and account for the supply of equipment, materials and services in project, field, and lease development. The agreement with FBCC requires that Petroteq pay FBCC $500,000 for the services to be provided, of which an initial $100,000 has been paid to FBCC to commence its research and development activities and an additional $152,500 has been paid to FBCC to continue its research and development activities.

 

The supply chain management platform is currently in the v1 Beta early stage of development and we are in the process of continuing research and development activities. The current development plans are that the platform will be blockchain agnostic and able to run on any blockchain that is commercially available. The Company’s business does not entail and it is not anticipated that it will entail, the creation, issuance, or use of any digital assets.

 

In February 2018, Petrobloq leased an 1,800 square foot office in Calabasas, California to serve as its headquarters. The office is staffed with four contract employees hired by FBCC serving as Project Manager; Director of Operations, Solutions Architect and Senior Database Developer, respectively.

 

On August 17, 2018, we entered into a development agreements with MehzOhanian, a software engineering firm based in Austin, Texas, to develop blockchain applications for Petrobloq. MetzOhanian specializes in blockchain engineering, supply chain management software development, and digital security consulting. MetzOhanian will be working with Petrobloq to develop blockchain applications aimed at increasing supply chain transparency and efficiency in the oil and gas sector.

 

Recruiter.com

 

In November 2016, we entered into a joint venture with Recruiter.com, Inc. and OilPrice.com and formed a Delaware limited liability company, Recruiter.com Oil and Gas Group LLC (“Recruiter. OGG”), which is owned 25% by us, 25% by Recruiter.com, Inc., 45% by OilPrice.com and 5% by two individuals. Net profits are split in accordance with ownership interests. In consideration of our 25% equity interest, we issued Recruiter.com, Inc. 83,333 shares of our stock. Recuiter. OGG is a recruitment venture providing a website based for careers in the oil and gas industry.

  

REGULATION

 

Exploration and production operations are subject to various types of regulation at the federal, state and local levels. This regulation includes requiring permits to drill wells, maintaining bonding requirements to drill or operate wells, and regulating the location of wells, the method of drilling and casing wells, the surface use and restoration of properties on which wells are drilled, and the plugging and abandoning of wells. Full mining permits have been granted to PQE from the State of Utah Division of Oil, Gas, and Mining for the mining and development of the Temple Mountain site in Asphalt Ridge, Utah. In addition to the mining permits, all environmental, construction, utility and other local permits necessary for the construction of the plant and the processing of the oil sands have been granted to PQE. Our operations are also subject to various conservation laws and regulations.

 

Typically, oil enhancements such as hydraulic fracturing operations are overseen by state regulators as part of their oil and gas regulatory programs; however, the EPA has asserted federal regulatory authority over certain hydraulic fracturing activities involving diesel under the Safe Drinking Water Act and has released draft permitting guidance for hydraulic fracturing activities that use diesel in fracturing fluids in those states where EPA is the permitting authority. As a result, we may be subject to additional permitting requirements for our operations. These permitting requirements and restrictions could result in delays in operations at well sites as well as increased costs to make wells productive. In addition, legislation introduced in Congress provides for federal regulation of hydraulic fracturing under the Safe Drinking Water Act and require the public disclosure of certain information regarding the chemical makeup of hydraulic fracturing fluids. Moreover, on November 23, 2011, the EPA announced that it was granting in part a petition to initiate a rulemaking under the Toxic Substances Control Act, relating to chemical substances and mixtures used in oil and gas exploration and production. Further, on May 4, 2012, the Department of the Interior’s Bureau of Land Management (“BLM”) issued a proposed rule to regulate hydraulic fracturing on public and Indian land.

 

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On August 16, 2012, the EPA published final rules that establish new air emission control requirements for natural gas and NGL production, processing and transportation activities, including New Source Performance Standards to address emissions of sulfur dioxide and volatile organic compounds, and National Emission Standards for Hazardous Air Pollutants (NESHAPS) to address hazardous air pollutants frequently associated with gas production and processing activities. Among other things, these final rules require the reduction of volatile organic compound emissions from natural gas wells through the use of reduced emission completions or “green completions” on all hydraulically fractured wells constructed or refractured after January 1, 2015. In addition, gas wells are required to use completion combustion device equipment (e.g., flaring) by October 15, 2012 if emissions cannot be directed to a gathering line. Further, the final rules under NESHAPS include maximum achievable control technology (MACT) standards for “small” glycol dehydrators that are located at major sources of hazardous air pollutants and modifications to the leak detection standards for valves. Compliance with these requirements, especially the imposition of these green completion requirements, may require modifications to certain of our operations, including the installation of new equipment to control emissions at the well site that could result in significant costs, including increased capital expenditures and operating costs, and could adversely impact our business.

 

In addition to these federal legislative and regulatory proposals, some states such as Pennsylvania, West Virginia, Texas, Kansas, Louisiana and Montana, and certain local governments have adopted, and others are considering adopting, regulations that could restrict hydraulic fracturing in certain circumstances, including requirements regarding chemical disclosure, casing and cementing of wells, withdrawal of water for use in high-volume hydraulic fracturing of horizontal wells, baseline testing of nearby water wells, and restrictions on the type of additives that may be used in hydraulic fracturing operations. For example, the Railroad Commission of Texas adopted rules in December 2011 requiring disclosure of certain information regarding the components used in the hydraulic fracturing process. In addition, Pennsylvania’s Act 13 of 2012 became law on February 14, 2012 and amended the state’s Oil and Gas Act to impose an impact fee for drilling, increase setbacks from certain water sources, require water management plans, increase civil penalties, strengthen the Pennsylvania Department of Environmental Protection’s (PaDEP) authority over the issuance of drilling permits, and require the disclosure of chemical information regarding the components in hydraulic fracturing fluids.

 

We believe that the technologies we use are cleaner and environmentally friendlier than the known fracking or tar sand technologies. Regulatory and social resistance sometimes prohibits fracking recovery methods in some states and we intend to consider entering in those states with our technologies offering to the regulators and the public solutions that we believe would help to lift the bans and ease resistance to oil and gas field development.

  

OSHA and Other Laws and Regulations.

 

We are subject to the requirements of the federal Occupational Safety and Health Act (OSHA), and comparable state laws. The OSHA hazard communication standard, the EPA community right-to-know regulations under the Title III of CERCLA and similar state laws require that we organize and/or disclose information about hazardous materials used or produced in our operations. Also, pursuant to OSHA, the Occupational Safety and Health Administration has established a variety of standards related to workplace exposure to hazardous substances and employee health and safety.

 

Oil Pollution Act.

 

The Federal Oil Pollution Act of 1990 (OPA) and resulting regulations impose a variety of obligations on responsible parties related to the prevention of oil spills and liability for damages resulting from such spills in waters of the United States. The term “waters of the United States” has been broadly defined to include inland water bodies, including wetlands and intermittent streams. The OPA assigns joint and several strict liability to each responsible party for oil removal costs and a variety of public and private damages. We believe that we substantially comply with the Oil Pollution Act and related federal regulations.

 

Clean Water Act.

 

The Federal Water Pollution Control Act (Clean Water Act) and resulting regulations, which are primarily implemented through a system of permits, also govern the discharge of certain contaminants into waters of the United States. Sanctions for failure to comply strictly with the Clean Water Act are generally resolved by payment of fines and correction of any identified deficiencies. However, regulatory agencies could require us to cease construction or operation of certain facilities or to cease hauling wastewaters to facilities owned by others that are the source of water discharges. We believe that we substantially comply with the Clean Water Act and related federal and state regulations.

 

COMPETITION

 

Competition in the oil industry is intense. We compete with other companies seeking to acquire sub economic oil fields, many with substantial financial and other resources. We will also compete with technologies such as gas injection, polymer flooding, microbial injection and thermal methods. As a new technology, we also compete with many of the other technologies that have been proven to be economically successful in enhancing oil production in the United States. As a result of this competition, we may be unable to attract the necessary funding or qualified personnel. If we are unable to successfully compete for funding or for qualified personnel, our activities may be slowed, suspended or terminated, any of which would have a material adverse effect on our ability to continue operations. However due to the innovative nature of our technology and the ecological benefit it provides, while remaining economically efficient, we believe that Competition will not be a significant impediment to our operations or expansion.

 

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IMPLICATIONS OF BEING AN EMERGING GROWTH COMPANY

 

We are an “emerging growth company,” as defined in the Jumpstart Our Business Startups Act of 2012 (the “JOBS Act”), and therefore we intend to take advantage of certain exemptions from various public company reporting requirements, including not being required to have our internal controls over financial reporting audited by our independent registered public accounting firm pursuant to Section 404 of the Sarbanes-Oxley Act of 2002 (the “Sarbanes-Oxley Act”), reduced disclosure obligations regarding executive compensation in our periodic reports and proxy statements and exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and any golden parachute payments. We may take advantage of these exemptions until we are no longer an “emerging growth company.” In addition, the JOBS Act provides that an “emerging growth company” can delay adopting new or revised accounting standards until such time as those standards apply to private companies. We have elected to use the extended transition period for complying with new or revised accounting standards under the JOBS Act. This election allows us to delay the adoption of new or revised accounting standards that have different effective dates for public and private companies until those standards apply to private companies. As a result of this election, our financial statements may not be comparable to companies that comply with public company effective dates. We will remain an “emerging growth company” until the earlier of (1) the last day of the fiscal year: (a) following the fifth anniversary of the date of the first sale of our common shares pursuant to an effective registration statement filed under the Securities Act; (b) in which we have total annual gross revenue of at least $1.07 billion; or (c) in which we are deemed to be a large accelerated filer, which means the market value of our common shares that is held by non-affiliates exceeded $700.0 million as of the prior June 30th, and (2) the date on which we have issued more than $1.0 billion in non-convertible debt during the prior three-year period. References herein to “emerging growth company” have the meaning associated with that term in the JOBS Act.

 

ENFORCEABILITY OF CIVIL LIABILITIES

 

We are a company incorporated in Ontario, Canada. Certain of our directors and officers named in this registration statement reside outside the U.S. In addition, some of our assets and the assets of our directors and officers are located outside of the United States. As a result, it may be difficult for investors who reside in the United States to effect service of process upon these persons in the United States. You may also have difficulty enforcing, both in and outside the United States, judgments you may obtain in U.S. courts against us or these persons in any action, including actions based upon the civil liability provisions of U.S. federal or state securities laws.

 

Furthermore, there is substantial doubt whether an action could be brought in Canada in the first instance predicated solely upon U.S. federal securities laws. Canadian courts may refuse to hear a claim based on an alleged violation of U.S. securities laws against us or these persons on the grounds that Canada is not the most appropriate forum in which to bring such a claim. Even if a Canadian court agrees to hear a claim, it may determine that Canadian law and not U.S. law is applicable to the claim. If U.S. law is found to be applicable, the content of applicable U.S. law must be proved as a fact, which can be a time-consuming and costly process. Certain matters of procedure will also be governed by Canadian law.

 

OUR CORPORATE HEADQUARTERS AND OTHER LOCATIONS

 

Our registered office address in Canada is Suite 6000, 1 First Canadian Place, 100 King Street West, Toronto, Ontario M5X 1E2, Canada. Our principal executive offices are located at 15165 Ventura Blvd, #200, Sherman Oaks, California 91403. The monthly base rent is $6,500 for the approximately 1,800 square foot premises and the lease term is five years.

 

Petrobloq’s headquarters are located at 4768 Park Granada, Calabasas, California 91302. The monthly base rent is $3,870 for the 1,800 square foot premises and the lease is for a three-year term.

 

TMC holds a mining and mineral leases, as amended, on the Asphalt Ridge property which is approximately 2,541.76 acres located in Uintah County, Utah of which 1229.82 acres are currently held under the TMC Mineral Lease and an additional 833.03 and 478.91 acres, respectively are held under the SITLA Mineral Leases. We are completing construction of a 20,000 square foot extraction facility based on this leased property that is anticipated to be approximately three acres.

  

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History and Development of the Company

  

We were incorporated as “AXEA Capital Corp.” on January 4, 2008 pursuant to the Business Corporations Act (British Columbia). On October 15, 2012, MCW Energy Group Limited (“MCW NB”), a corporation incorporated in the Province of New Brunswick, completed a reverse acquisition of AXEA Capital Corp. (the “RTO”) and as a result MCW NB became a wholly owned subsidiary of AXEA Capital Corp. which also changed its name from “AXEA Capital Corp.” to “MCW Enterprises Ltd.” Pursuant to articles of continuance filed on December 7, 2012, MCW NB changed its jurisdiction of governance by continuing from the Province of New Brunswick into the Province of Ontario. Pursuant to articles of continuance filed on December 12, 2012, MCW Enterprises Ltd. changed its jurisdiction of governance by continuing from the Province of British Columbia into the Province of Ontario and changed its name to MCW Enterprises Continuance Ltd. Pursuant to a certificate of amalgamation dated December 12, 2012, MCW Enterprises Continuance Ltd. and MCW NB amalgamated in the Province of Ontario and continued under the name “MCW Energy Group Limited”.

 

We are governed by the Business Corporations Act (Ontario) and our registered office is located at Suite 6000, 1 First Canadian Place, PO Box 367, 100 King Street West, Toronto, Ontario M5X 1E2, Canada and our principal place of business is located at 15165 Ventura Blvd., #200, Sherman Oaks, California 91403. Our telephone number is (866) 571-9613.

 

Our common shares are publicly traded on the TSX Venture Exchange (the “TSXV”) under the trading symbol “PQE”, the Frankfurt Exchange under the trading symbol PQCF.F and on the OTC Pink under the trading symbol “PQEFF”.

 

On July 4, 2016, we acquired a controlling interest of 57.3% of Accord GR Energy, Inc., however, we currently hold a 44.7% interest in Accord.

 

Pursuant to articles of amendment filed on May 5, 2017, we changed our name from “MCW Energy Group Limited” to “Petroteq Energy Inc.” and we changed our TSXV trading symbol from MCW to PQE. On June 2, 2017, our OTCQX trading symbol was changed from MCW to PQEFF. Since March 15, 2018, our stock has traded on the OTC Pink market when it no longer traded on the OTCQX International Market.

 

On May 5, 2017, we effected a share consolidation (reverse stock split) on a 1-for-30 basis. Unless otherwise included, all shares amounts and per share amounts in this registration statement have been prepared on a pro forma basis to reflect the 1-for-30 reverse stock split of our outstanding shares of common shares that we effected May 5, 2017. On November 23, 2018, our shareholders approved a resolution authorizing our Board of Directors to consolidate our shares on a basis of up to ten for one. No consolidation has been effected to date.

 

Recently through our wholly owned subsidiary PQE, we formed a new subsidiary Petrobloq. We have also acquired a 25% investment in a recruitment venture with three other parties providing a website based for careers in the oil and gas industry.

 

Additional information related to our company may be found on our website at www.petroteq.energy. Information contained in our website does not form part of the registration statement and is intended for informational purposes only.

  

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ITEM 1A. RISK FACTORS.

 

The following risks relate specifically to our business and should be considered carefully. Our business, financial condition and results of operations could be harmed by any of the following risks. As a result, the trading price of our common shares could decline and the holders could lose part or all of their investment.

  

We have a limited operating history, and may not be successful in developing profitable business operations.

 

Our oil extraction segment has a limited operating history. Our business operations must be considered in light of the risks, expenses and difficulties frequently encountered in establishing a business in the oil extraction business.  In May 2018 we recommenced our oil extraction activities, which is expected to be a significant source of our revenue. From 2015 until 2018, we temporarily ceased our oil extraction operations while we relocated our processing plant. For a limited period, we made sales of hydrocarbon products to customers produced at the oil extraction plant we had completed on September 1, 2015. Due to the volatility in the oil markets production ceased as we were not able to operate profitably at low volumes of output. The losses from continuing operations over the past four fiscal years are largely due to us relocating our oil extraction plant to the TMC mineral lease site. As of the date of this registration statement, we have generated limited revenue from these activities and do not anticipate generating any significant revenue from these activities until the new facility is fully operational for at least a few months, which is not expected until the last quarter of fiscal 2019.  We have an insufficient history at this time on which to base an assumption that our oil extraction business operations will prove to be successful in the long-term.  Our future operating results will depend on many factors, including:

 

  our ability to raise adequate working capital;

  the success of our development and exploration;

  the demand for oil;

  the level of our competition;

  our ability to attract and maintain key management and employees; and

  our ability to efficiently explore, develop, produce or acquire sufficient quantities of marketable gas or oil in a highly competitive and speculative environment while maintaining quality and controlling costs.

 

To achieve profitable operations in the future, we must, alone or with others, successfully manage the factors stated above, as well as continue to develop ways to enhance our processing efforts, when commenced.  Despite our best efforts, we may not be successful in our exploration or development efforts, or obtain required regulatory approvals.  

 

We have suffered operating losses since inception and we may not be able to achieve profitability.

 

At November 30, 2018, August 31, 2018 and August 31, 2017, we had an accumulated deficit of ($68,240,978), ($61,968,522) and ($46,856,367), respectively and we expect to continue to incur increasing expenses in the foreseeable future as we develop our oil extraction business. We incurred a net loss of ($6,272,456 and (3,645,712) as of the three months ended November 30, 2018 and November 30, 2017, respectively and ($15,112,155 and ($7,939,643), as of the years ended August 31, 2018 and August 31, 2017, respectively.  As a result, we are sustaining substantial operating and net losses, and it is possible that we will never be able to sustain or develop the revenue levels necessary to attain profitability.

 

Our ability to be profitable will depend in part upon our ability to manage our operating costs and to generate revenue from our extraction operations. Operating costs could be impacted by inflationary pressures on labor, volatile pricing for natural gas used as an energy source in transportation of fuel and in oil sands processes, and planned and unplanned maintenance.

 

The failure to comply with the terms of our secured notes could result in a default under the terms of the note and, if uncured, it could potentially result in action against the pledged assets.

 

As of November 30, 2018, we had issued and outstanding notes in the principal amount of $1,637,396 and convertible notes in the principal amount of $3,448,974 to certain private investor which mature between January 1, 2019 and August 31, 2020 and are secured by a pledge of all of our assets.  If we fail to comply with the terms of the notes, the note holder could declare a default under the notes and if the default were to remain uncured, as secured creditors they would have the right to proceed against the collateral secured by the loans. Any action by secured creditors to proceed against our assets would likely have a serious disruptive effect on our operations.

 

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We have limited capital and will need to raise additional capital in the future.

 

We do not currently have sufficient capital to fund both our continuing operations and our planned growth.  We will require additional capital to meet the terms of the TMC Mineral Lease and to continue to grow our business via acquisitions and to further expand our exploration and development programs.  We may be unable to obtain additional capital when required.  Future acquisitions and future exploration, development, processing and marketing activities, as well as our administrative requirements (such as salaries, insurance expenses and general overhead expenses, as well as legal compliance costs and accounting expenses) will require a substantial amount of additional capital and cash flow.

 

We may pursue sources of additional capital through various financing transactions or arrangements, including joint venturing of projects, debt financing, equity financing or other means.  We may not be successful in identifying suitable financing transactions in the time period required or at all, and we may not obtain the capital we require by other means.  If we do not succeed in raising additional capital, our resources may not be sufficient to fund our planned operations and may force us to curtail operations or cancel planned projects.

 

Our ability to obtain financing, if and when necessary, may be impaired by such factors as the capital markets (both generally and in the oil and gas industry in particular), our limited operating history, the location of our oil and gas properties and prices of oil and gas on the commodities markets (which will impact the amount of asset-based financing available to us, if any) and the departure of key employees.  Further, if oil or gas prices on the commodities markets decline, our future revenues, if any, will likely decrease and such decreased revenues may increase our requirements for capital.  If the amount of capital we are able to raise from financing activities, together with our revenues from operations, is not sufficient to satisfy our capital needs (even to the extent that we reduce our operations), we may be required to cease our operations, divest our assets at unattractive prices or obtain financing on unattractive terms.

  

Any additional capital raised through the sale of equity may dilute the ownership percentage of our shareholders.  Raising any such capital could also result in a decrease in the fair market value of our equity securities because our assets would be owned by a larger pool of outstanding equity.  The terms of securities we issue in future capital transactions may be more favorable to our new investors, and may include preferences, superior voting rights and the issuance of other derivative securities, and issuances of incentive awards under equity employee incentive plans, which may have a further dilutive effect.

 

Any additional debt financing may include conditions that would restrict our freedom to operate our business, such as conditions that:

 

  increase our vulnerability to general adverse economic and industry conditions;
  require us to dedicate a portion of our cash flow from operations to payments on our debt, thereby reducing the availability of our cash flow to fund capital expenditures, working capital, growth and other general corporate purposes; and
  limit our flexibility in planning for, or reacting to, changes in our business and our industry.

 

The incurrence of additional indebtedness could require acceptance of covenants that, if violated, could further restrict our operations or lead to acceleration of the indebtedness that would necessitate winding up or liquidation of our company. In addition to the foregoing, our ability to obtain additional debt financing may be limited and there can be no assurance that we will be able to obtain any additional financing on terms that are acceptable, or at all.

 

We may incur substantial costs in pursuing future capital financing, including investment banking fees, legal fees, accounting fees, securities law compliance fees, printing and distribution expenses and other costs.  We may also be required to recognize non-cash expenses in connection with certain securities we may issue, which may adversely impact our financial condition.

 

There is substantial doubt about our ability to continue as a going concern.

 

At November 30, 2018, we had not yet achieved profitable operations, had accumulated losses of ($68, 240,978) since our inception and a working capital deficit of ($5,829,414), and expect to incur further losses in the development of our business, all of which casts substantial doubt about our ability to continue as a going concern. We have incurred net losses for the past four years. As at August 31, 2018 and August 31, 2017, we had an accumulated deficit of ($61,968,522) and ($46,856,367), respectively and a working capital deficit of ($374,567) and ($4,250,552), respectively. The opinion of our independent registered accounting firm on our audited financial statements for the years ended August 31, 2018 and 2017 draws attention to our notes to the financial statements which describes certain material uncertainties regarding our ability to continue as a going concern. Our ability to continue as a going concern is dependent upon our ability to generate future profitable operations and/or to obtain the necessary financing to meet our obligations and repay our liabilities arising from normal business operations when they come due. Management’s plan to address our ability to continue as a going concern includes: (1) obtaining debt or equity funding from private placement or institutional sources; (2) obtaining loans from financial institutions, where possible; or (3) participating in joint venture transactions with third parties. Although management believes that it will be able to obtain the necessary funding to allow us to remain a going concern through the methods discussed above, there can be no assurances that such methods will prove successful. The accompanying financial statements do not include any adjustments that might result from the outcome of this uncertainty.

 

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Strategic relationships upon which we may rely are subject to change, which may diminish our ability to conduct our operations.

 

Our ability to successfully acquire oil and gas interests, to establish reserves, and to identify and enter into commercial arrangements with customers will depend on developing and maintaining close working relationships with industry participants and our ability to select and evaluate suitable properties and to consummate transactions in a highly competitive environment.  These realities are subject to change and our inability to maintain close working relationships with industry participants or continue to acquire suitable property may impair our ability to execute our business plan.

 

To continue to develop our business, we will endeavor to use the business relationships of our management to enter into strategic relationships, which may take the form of joint ventures with other private parties and contractual arrangements with other oil and gas companies, including those that supply equipment and other resources that we will use in our business. We may not be able to establish these strategic relationships, or if established, we may not be able to maintain them.  In addition, the dynamics of our relationships with strategic partners may require us to incur expenses or undertake activities we would not otherwise be inclined to in order to fulfill our obligations to these partners or maintain our relationships.  If our strategic relationships are not established or maintained, our business prospects may be limited, which could diminish our ability to conduct our operations.

  

We may not be able to successfully manage our growth, which could lead to our inability to implement our business plan.

 

Our growth is expected to place a significant strain on our managerial, operational and financial resources, especially considering that we currently only have a small number of executive officers, employees and advisors. Further, as we enter into additional contracts, we will be required to manage multiple relationships with various consultants, businesses and other third parties. In addition, once we commence operations at our oil extraction facility, our strain on management will further increase. These requirements will be exacerbated in the event of our further growth or in the event that the number of our drilling and/or extraction operations increases. There can be no assurance that our systems, procedures and/or controls will be adequate to support our operations or that our management will be able to achieve the rapid execution necessary to successfully implement our business plan. If we are unable to manage our growth effectively, our business, results of operations and financial condition will be adversely affected, which could lead to us being forced to abandon or curtail our business plan and operations

 

Our operations are dependent upon us maintaining our mineral lease for the Asphalt Ridge Property.

 

TMC, our subsidiary holds a mining and mineral lease, granted by Asphalt Ridge, Inc., on the Asphalt Ridge property located in Uintah County, Utah (the “TMC Mineral Lease”). We recently moved our processing facility to the TMC Mineral Lease site. The TMC Mineral Lease is subject to termination under various circumstances, including our non-payment of certain royalty fees as well as us not meeting certain minimum production requirements and receiving funding commitments for expanding or building additional production facilities. We currently intend to fund the expansion/ additional facilities through revenue generated from the processing facility at the TMC Mineral Lease, which to date has been minimal, and/ or third party funding sources for which we currently have no commitments. If the TMC Mineral Lease were to be terminated our operations would be significantly impacted until such time that we were able to enter into a substitute lease. Any substitute lease would require extensive construction work and new regulatory permits price to becoming operational. There can be no assurance that we could enter into a substitute lease upon favorable terms if at all or that such lease would not require us to relocate our extraction facility.

 

The loss of key personnel would directly affect our efficiency and profitability.

 

Our future success is dependent, in a large part, on retaining the services of our current management team. Our executive officers possess a unique and comprehensive knowledge of our industry, our technology and related matters that are vital to our success within the industry.  The knowledge, leadership and technical expertise of these individuals would be difficult to replace.  The loss of one or more of our officers could have a material adverse effect on our operating and financial performance, including our ability to develop and execute our long term business strategy.  We do not maintain key-man life insurance with respect to any employees. We do not have employment agreements with any of our executive officers other than our Chief Executive Officer.  There can be no assurance that any of our officers will continue to be employed by us.

 

In the future, we may incur significant increased costs as a result of operating as a U.S reporting company, and our management may be required to devote substantial time to new compliance initiatives.

 

In the future, we may incur significant legal, accounting and other expenses as a result of operating as a public company. The Sarbanes-Oxley Act of 2002 (the “Sarbanes-Oxley Act”), as well as new rules subsequently implemented by the U.S. Securities and Exchange Commission (the “SEC”), have imposed various requirements on public companies, including requiring changes in corporate governance practices. Our management and other personnel will need to devote a substantial amount of time to these new compliance initiatives. Moreover, these rules and regulations will increase our legal and financial compliance costs and will make some activities more time-consuming and costly. For example, we expect these new rules and regulations to make it more difficult and more expensive for us to obtain director and officer liability insurance, and we may be required to incur substantial costs to maintain the same or similar coverage.

 

Our operations are currently geographically concentrated and therefore subject to regional economic, regulatory and capacity risks.

 

All of our production is anticipated to be derived from our properties in the Asphalt Ridge As a result of this geographic concentration, we may be disproportionately exposed to the effect of regional supply and demand factors, delays or interruptions of production from ore sands in this area caused by governmental regulation, processing or transportation capacity constraints, market limitations, weather events or interruption of the processing or transportation of crude oil or natural gas. Additionally, we may be exposed to additional risks, such as changes in field-wide rules and regulations that could cause us to permanently cease mining operations at Asphalt Ridge.

 

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In addition, the Sarbanes-Oxley Act requires, among other things, that we maintain effective internal controls for financial reporting and disclosure controls and procedures. In particular, we are required to perform system and process evaluation and testing on the effectiveness of our internal controls over financial reporting, as required by Section 404 of the Sarbanes-Oxley Act. Our testing may reveal deficiencies in our internal controls over financial reporting that are deemed to be material weaknesses. Our compliance with Section 404 will require that we incur substantial accounting expense and expend significant management efforts. We currently do not have an internal audit group, and we will need to hire additional accounting and financial staff with appropriate public company experience and technical accounting knowledge. Moreover, if we are not able to comply with the requirements of Section 404 in a timely manner, or if we or our independent registered public accounting firm identifies deficiencies in our internal controls over financial reporting that are deemed to be material weaknesses, the market price of our stock could decline, and we could be subject to sanctions or investigations by the SEC or other regulatory authorities, which would require additional financial and management resources.

 

Licenses and permits are required for our company to operate in some jurisdictions, and the loss of or failure to renew any or all of these licenses and permits or failure to comply with applicable laws and regulations could prevent us from either completing current projects or obtaining future projects, and, thus, materially adversely affect our business.

 

Our operations will require licenses, permits and in some cases renewals of licenses and permits from various governmental authorities.  Our ability to obtain, sustain or renew such licenses and permits on acceptable terms is subject to change in regulations and policies and to the discretion of the applicable governments, among other factors.  Our inability to obtain, or our loss of or denial of extension of, any of these licenses or permits could hamper our ability to produce revenues from our operations.

  

We may be required to make significant capital expenditures to comply with laws and the applicable regulations and standards of governmental authorities and organizations.

 

We are subject to various national, state, and local laws and regulations in the various countries in which we operate, including those relating to the renewable energy industry in general, and may be required to make significant capital expenditures to comply with laws and the applicable regulations and standards of governmental authorities and organizations. Moreover, the cost of compliance could be higher than anticipated. On the effective date hereof, our operations will become subject to compliance with the U.S. Foreign Corrupt Practices Act in addition to certain international conventions and the laws, regulations and standards of other foreign countries in which we operate. 

 

In addition, many aspects of our operations are subject to laws and regulations that relate, directly or indirectly, to the renewable industry. Existing and proposed new governmental conventions, laws, regulations and standards, including those related to climate and emissions of “greenhouse gases,” may in the future add significantly to our operating costs or limit our activities or the activities and levels of capital spending by our customers. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and even criminal penalties, the imposition of remedial obligations, and the issuance of injunctions that may limit or prohibit our operations. The application of these requirements, the modification of existing laws or regulations or the adoption of new laws or regulations which impose substantial new regulatory requirements on our oil extraction operations could also harm our business, results of operations, financial condition and prospects. 

 

We could be subject to litigation that could have an adverse effect on our business and operating results.

 

We are, from time to time, involved in litigation. The numerous operating hazards inherent in our business increase our exposure to litigation, which may involve, among other things, contract disputes, personal injury, environmental, employment, warranty and product liability claims, tax and securities litigation, patent infringement and other intellectual property claims and litigation that arises in the ordinary course of business. Our management cannot predict with certainty the outcome or effect of any claim or other litigation matter. Litigation may have an adverse effect on us because of potential negative outcomes such as monetary damages or restrictions on future operations, the costs associated with defending the lawsuits, the diversion of management’s resources and other factors.

 

Global political, economic and market conditions could negatively impact our business.

 

Our company’s operations are affected by global political, economic and market conditions. The recent economic downturn has generally reduced the availability of liquidity and credit to fund business operations worldwide and has adversely affected our customers, suppliers and lenders. Our limited capital resources have negatively impacted our activity levels and, in turn, our financial condition and results of operations. A sustained or deeper recession in regions in which we operate could limit overall demand for our renewable energy solutions and could further constrain our ability to generate revenues and margins in those markets and to grow overall.

 

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War, terrorism, geopolitical uncertainties, public health issues, and other business interruptions have caused and could cause damage or disruption to international commerce and the global economy, and thus could have a material adverse effect on us, our suppliers, logistics providers and customers. Our business operations are subject to interruption by, among others, natural disasters (including, without limitation, earthquakes), fire, power shortages, nuclear power plant accidents, terrorist attacks and other hostile acts, labor disputes, public health issues, and other events beyond our control. Such events could decrease demand for our services and products, make it difficult or impossible for us to make and deliver crude oil and hydrocarbon products to our buyers and customers, or to receive necessary supplies from our suppliers, and create delays and inefficiencies in our supply chain. Should major public health issues, including pandemics, arise, we could be adversely affected by more stringent employee travel restrictions, additional limitations in freight services, governmental actions limiting the movement of products between regions, delays in production ramps of new products, and disruptions in the operations of our customers and suppliers. The majority of our business operations, our corporate headquarters, and other critical business operations, including suppliers and customers, are in locations that could be affected by natural disasters. In the event of a natural disaster, we could incur significant losses, require substantial recovery time and experience significant expenditures in order to resume operations.

 

We do not carry business interruption insurance, and any unexpected business interruptions could adversely affect our business.

 

Our operations are vulnerable to interruption by earthquake, fire, power failure and power shortages, hardware and software failure, floods, computer viruses, and other events beyond our control.  In addition, we do not carry business interruption insurance to compensate us for losses that may occur as a result of these kinds of events, and any such losses or damages incurred by us could disrupt our projects and our other operations without reimbursement. Because of our limited financial resources, such an event could threaten our viability to continue as a going concern and lead to dramatic losses in the value of our common shares.

  

Certain Factors Related to Oil Sands Exploration

 

The Nature of Oil Sands Exploration and Development involves many risks.

 

Oil sands exploration and development are very competitive and involve many risks that even a combination of experience, knowledge and careful evaluation may not be able to overcome. As with any exploration property, there can be no assurance that commercial deposits of bitumen will be produced from oil sands exploration licenses and our permit lands in Utah.

 

The Extraction Technology has never been implemented on a large commercial basis as an oil and gas recovery technology before and our assumptions and expectations may not be accurate causing actual results of the implementation of the Extraction Technology to be significantly different form our current expectations. As a result, our operations may not generate any significant revenues from the development of the bitumen resources. In addition, there is no assurance that reserve engineers or lenders will determine that the production resulting from the application of the Extraction Technology can be used to establish reserves.

 

Furthermore, the marketability of any resource will be affected by numerous factors beyond our control. These factors include, but are not limited to, market fluctuations of prices, proximity and capacity of pipelines and processing equipment, equipment and labor availability and government regulations (including, without limitation, regulations relating to prices, taxes, royalties, land tenure, allowable production, importing and exporting of oil and gas, land use and environmental protection). The extent of these factors cannot be accurately predicted, but the combination of these factors may result in us not receiving an adequate return on invested capital.

 

Supply risk is a function of the unavailability of third party bitumen, poor ore grade quality or density, unplanned mine equipment and extraction plant maintenance, storage costs and in situ reservoir and equipment performance could impact production targets. Our oil extraction activities will be dependent upon our supply of bitumen.

 

The viability of our business plan, business operations, and future operating results and financial condition are and will be exposed to fluctuating prices for oil, gas, oil products and chemicals.

 

Prices of oil, gas, oil products and chemicals are affected by supply and demand, which can fluctuate significantly. Factors that influence supply and demand include operational issues, natural disasters, weather, political instability, or conflicts, economic conditions and actions by major oil-exporting countries. Price fluctuations can have a material effect on our ability to raise capital and fund our exploration activities, our potential future earnings, and our financial condition. For example, in a low oil and gas price environment oil sands exploration and development may not be financially viable or profitable. Prolonged periods of low oil and gas prices, or rising costs, could result in our exploration projects being delayed or cancelled, as well as the impairment of certain assets.

 

Environmental and regulatory compliance may impose substantial costs on us.

 

Our operations are or will be subject to stringent federal, provincial and local laws and regulations relating to improving or maintaining environmental quality. Environmental laws often require parties to pay for remedial action or to pay damages regardless of fault. Environmental laws also often impose liability with respect to divested or terminated operations, even if the operations were terminated or divested many years ago.

 

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Our exploration activities and drilling programs are or will be subject to extensive laws and regulations governing prospecting, development, production, exports, taxes, labor standards, occupational health, waste disposal, land use, protection and remediation of the environment, protection of endangered and protected species, operational safety, toxic substances and other matters. Exploration and drilling is also subject to risks and liabilities associated with pollution of the environment and disposal of waste products. Compliance with these laws and regulations will impose substantial costs on us and will subject us to significant potential liabilities. In addition, should there be changes to existing laws or regulations, our competitive position within the oil sands industry may be adversely affected, as many industry players have greater resources than we do. 

 

We are required to obtain various regulatory permits and approvals in order to explore and develop our properties. There is no assurance that regulatory approvals for exploration and development of our properties will be obtained at all or with terms and conditions acceptable to us.

 

We may be exposed to third party liability and environmental liability in the operation of our business.

 

Our operations could result in liability for personal injuries, property damage, oil spills, discharge of hazardous materials, remediation and clean-up costs and other environmental damage. We could be liable for environmental damages caused by previous owners. As a result, substantial liabilities to third parties or governmental entities may be incurred, and the payment of such liabilities could have a material adverse effect on our financial condition and results of operations. The release of harmful substances in the environment or other environmental damages caused by our activities could result in us losing our operating and environmental permits or inhibit us from obtaining new permits or renewing existing permits. We currently have a limited amount of insurance and, at such time as we commence additional operations, we expect to be able to obtain and maintain additional insurance coverage for our operations, including limited coverage for sudden environmental damages, but we do not believe that insurance coverage for environmental damage that occurs over time is available at a reasonable cost. Moreover, we do not believe that insurance coverage for the full potential liability that could be caused by environmental damage is available at a reasonable cost. Accordingly, we may be subject to liability or may lose substantial portions of our properties in the event of certain environmental damage. We could incur substantial costs to comply with environmental laws and regulations which could affect our ability to operate as planned.

  

American climate change legislation could negatively affect markets for crude and synthetic crude oil

 

Environmental legislation regulating carbon fuel standards in jurisdictions that import crude and synthetic crude oil in the United States could result in increased costs and/or reduced revenue. For example, both California and the United States federal governments have passed legislation which, in some circumstances, considers the lifecycle greenhouse gas emissions of purchased fuel and which may negatively affect our business, or require the purchase of emissions credits, which may not be economically feasible.

 

Because of the speculative nature of oil exploration, there is risk that we will not find commercially exploitable oil and gas and that our business will fail.

 

The search for commercial quantities of oil and gas as a business is extremely risky. We cannot provide investors with any assurance that any properties in which we obtain a mineral interest will contain commercially exploitable quantities of bitumen, oil and/or gas.  The exploration expenditures to be made by us may not result in the discovery of commercial quantities of oil and/or gas.  Problems such as unusual or unexpected formations or pressures, premature declines of reservoirs, invasion of water into producing formations and other conditions involved in oil and gas exploration often result in unsuccessful exploration efforts. If we are unable to find commercially exploitable quantities of oil and gas, and/or we are unable to commercially extract such quantities, we may be forced to abandon or curtail our business plan, and as a result, any investment in us may become worthless.

 

The price of oil and gas has historically been volatile.  If it were to decrease substantially, our projections, budgets and revenues would be adversely affected, potentially forcing us to make changes in our operations.

 

Our future financial condition, results of operations and the carrying value of any oil and gas interests we acquire will depend primarily upon the prices paid for oil and gas production. Oil and gas prices historically have been volatile and likely will continue to be volatile in the future, especially given current world geopolitical conditions. Our cash flows from operations are highly dependent on the prices that we receive for oil and gas. This price volatility also affects the amount of our cash flows available for capital expenditures and our ability to borrow money or raise additional capital. The prices for oil and gas are subject to a variety of additional factors that are beyond our control. These factors include:

 

  the level of consumer demand for oil and gas;

  the domestic and foreign supply of oil and gas;

  the ability of the members of the Organization of Petroleum Exporting Countries (“OPEC”) to agree to and maintain oil price and production controls;

 

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  the price of foreign oil and gas;

  domestic governmental regulations and taxes;

  the price and availability of alternative fuel sources;

  weather conditions;

  market uncertainty due to political conditions in oil and gas producing regions, including the Middle East; and

  worldwide economic conditions.

 

These factors as well as the volatility of the energy markets generally make it extremely difficult to predict future oil and gas price movements with any certainty. Declines in oil and gas prices affect our revenues and accordingly, such declines could have a material adverse effect on our financial condition, results of operations, our future oil and gas reserves and the carrying values of our oil and gas properties. If the oil and gas industry experiences significant price declines, we may be unable to make planned expenditures, among other things. If this were to happen, we may be forced to abandon or curtail our business operations, which would cause the value of an investment in us to decline in value or become worthless.

  

Because of the inherent dangers involved in oil and gas operations, there is a risk that we may incur liability or damages as we conduct our business operations, which could force us to expend a substantial amount of money in connection with litigation and/or a settlement.

 

The oil and gas business involves a variety of operating hazards and risks such as well blowouts, pipe failures, casing collapse, explosions, uncontrollable flows of oil, gas or well fluids, fires, spills, pollution, releases of toxic gas and other environmental hazards and risks. These hazards and risks could result in substantial losses to us from, among other things, injury or loss of life, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage, cleanup responsibilities, regulatory investigation and penalties and suspension of operations. In addition, we may be liable for environmental damages caused by previous owners of property purchased and leased by us. As a result, substantial liabilities to third parties or governmental entities may be incurred, the payment of which could reduce or eliminate the funds available for exploration, development or acquisitions or result in the loss of our properties and/or force us to expend substantial monies in connection with litigation or settlements. There can be no assurance that any insurance we may have in place will be adequate to cover any losses or liabilities. The occurrence of a significant event not fully insured or indemnified against could materially and adversely affect our financial condition and operations. In addition, pollution and environmental risks generally are not fully insurable. The occurrence of an event not fully covered by insurance could have a material adverse effect on our financial condition and results of operations, which could lead to any investment in us becoming worthless.

 

The market for oil and gas is intensely competitive, and competitive pressures could force us to abandon or curtail our business plan.

 

The market for oil and gas exploration services is highly competitive, and we only expect competition to intensify in the future. Numerous well-established companies are focusing significant resources on exploration and are currently competing with us for oil and gas opportunities.  Other oil and gas companies may seek to acquire oil and gas leases and properties that we have targeted.  Additionally, other companies engaged in our line of business may compete with us from time to time in obtaining capital from investors.  Competitors include larger companies which, in particular, may have access to greater resources, may be more successful in the recruitment and retention of qualified employees and may conduct their own refining and petroleum marketing operations, which may give them a competitive advantage.  Actual or potential competitors may be strengthened through the acquisition of additional assets and interests.  Additionally, there are numerous companies focusing their resources on creating fuels and/or materials which serve the same purpose as oil and gas but are manufactured from renewable resources. As a result, there can be no assurance that we will be able to compete successfully or that competitive pressures will not adversely affect our business, results of operations and financial condition. If we are not able to successfully compete in the marketplace, we could be forced to curtail or even abandon our current business plan, which could cause any investment in us to become worthless.

 

Our estimates of the volume of recoverable resources could have flaws, or such resources could turn out not to be commercially extractable. Further, we may not be able to establish any reserves. As a result, our future revenues and projections could be incorrect.

 

Estimates of recoverable resources and of future net revenues prepared by different petroleum engineers may vary substantially depending, in part, on the assumptions made and may be subject to adjustment either up or down in the future. To date we have not established any reserves. Our actual amounts of production, revenue, taxes, development expenditures, operating expenses, and future quantities of recoverable oil and gas reserves may vary substantially from the estimates. There are numerous uncertainties inherent in estimating quantities of bitumen resources and recoverable reserves, including many factors beyond our control and no assurance can be given that the recovery of bitumen will be realized. In general, estimates of resources and reserves are based upon a number of factors and assumptions made as of the date on which the resources and reserve estimates were determined, such as geological and engineering estimates which have inherent uncertainties, the assumed effects of regulation by governmental agencies and estimates of future commodity prices and operating costs, all of which may vary considerably from estimated results. Oil and gas reserve estimates are necessarily inexact and involve matters of subjective engineering judgment. In addition, any estimates of our future net revenues and the present value thereof are based on assumptions derived in part from historical price and cost information, which may not reflect current and future values, and/or other assumptions made by us that only represent our best estimates. For these reasons, estimates of reserves and resources, the classification of such resources and reserves based on risk of recovery, prepared by different engineers or by the same engineers at different times, may vary substantially. Investors are cautioned not to assume that all or any part of a resource is economically or legally extractable. Additionally, if declines in and instability of oil and gas prices occur, then write downs in the capitalized costs associated with any oil and gas assets we obtain may be required. Because of the nature of the estimates of our recoverable resources and future reserves and estimates in general, we can provide no assurance that our estimated bitumen resources or future reserves will be present and/or commercially extractable. If our recoverable bitumen resource estimates are incorrect, the value of our common shares could decrease and we may be forced to write down the capitalized costs of our oil and gas properties.

 

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Decommissioning costs are unknown and may be substantial.  Unplanned costs could divert resources from other projects.

 

In the future, we may become responsible for costs associated with abandoning and reclaiming wells, facilities and pipelines which we use for processing of oil and gas reserves.  Abandonment and reclamation of these facilities and the costs associated therewith is often referred to as “decommissioning.”  We accrue a liability for decommissioning costs associated with our extraction plant and wells but have not established any cash reserve account for these potential costs in respect of any of our properties.  If decommissioning is required before economic depletion of our properties or if our estimates of the costs of decommissioning exceed the value of the reserves remaining at any particular time to cover such decommissioning costs, we may have to draw on funds from other sources to satisfy such costs.  The use of other funds to satisfy such decommissioning costs could impair our ability to focus capital investment in other areas of our business.

  

We may have difficulty distributing the oil we produce, which could harm our financial condition. 

 

In order to sell the oil and gas that we are able to produce, if any, the operators of the open mining operations and wells we obtain interests in may have to make arrangements for storage and distribution to the market.  We will rely on local infrastructure and the availability of transportation for storage and shipment of our products, but infrastructure development and storage and transportation facilities may be insufficient for our needs at commercially acceptable terms in the localities in which we operate.  This situation could be particularly problematic to the extent that our operations are conducted in remote areas that are difficult to access, such as areas that are distant from shipping and/or pipeline facilities.  These factors may affect our and potential partners’ ability to explore and develop properties and to store and transport oil and gas production, increasing our expenses.

 

Furthermore, weather conditions or natural disasters, actions by companies doing business in one or more of the areas in which we will operate, or labor disputes may impair the distribution of oil and/or gas and in turn diminish our financial condition or ability to maintain our operations.

 

Challenges to our properties may impact our financial condition.

 

Title to oil and gas interests is often not capable of conclusive determination without incurring substantial expense.  While we intend to make appropriate inquiries into the title of properties and other development rights we acquire, title defects may exist.  In addition, we may be unable to obtain adequate insurance for title defects, on a commercially reasonable basis or at all.  If title defects do exist, it is possible that we may lose all or a portion of our right, title and interests in and to the properties to which the title defects relate. If our property rights are reduced, our ability to conduct our exploration, development and processing activities may be impaired.  To mitigate title problems, common industry practice is to obtain a title opinion from a qualified oil and gas attorney prior to the excavation activities undertaken or the drilling operations of a well.

 

We rely on technology to conduct our business, and our technology could become ineffective or obsolete.

 

We rely on technology, including geographic and seismic analysis techniques and economic models, to develop our reserve estimates and to guide our exploration, development and processing activities.  We and our operator partners will be required to continually enhance and update our technology to maintain its efficacy and to avoid obsolescence.  Our oil extraction business is dependent upon the Extraction Technology that we have developed but which has not yet been used on a large commercial scale. As such, the project carries with it a greater degree of technological risk than other projects that employ commercially proven technologies and the Extraction Technology may not perform as anticipated. If major process design changes are required, the costs of doing so may be substantial and may be higher than the costs that we anticipate for technology maintenance and development.  If we are unable to maintain the efficacy of our technology, our ability to manage our business and to compete may be impaired.  Further, even if we are able to maintain technical effectiveness, our technology may not be the most efficient means of reaching our objectives, in which case we may incur higher operating costs than we would were our technology more efficient.

 

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Our failure to protect our proprietary information and any successful intellectual property challenges or infringement proceedings against us could materially and adversely affect our competitive position.

 

We rely on a variety of intellectual property rights that we use in our services and products. We rely upon intellectual property rights and other contractual or proprietary rights, including copyright, trademark, trade secrets, confidentiality provisions, contractual provisions, licenses and patents. We may not be able to successfully preserve these intellectual property rights in the future, and these rights could be invalidated, circumvented, or challenged. In addition, the laws of some foreign countries in which our services and products may be sold do not protect intellectual property rights to the same extent as the laws of the United States. Our failure to protect our proprietary information and any successful intellectual property challenges or infringement proceedings against us could materially and adversely affect our competitive position. Without patent and other similar protection, other companies could use substantially identical technology to offer products for sale without incurring the sizable development costs we have incurred. Even if we spend the necessary time and money, a patent may not be issued or it may insufficiently protect the technology it was intended to protect. If our pending patent applications are not approved for any reason, the degree of future protection for our proprietary technology will remain uncertain. If we have to engage in litigation to protect our patents and other intellectual property rights, the litigation could be time consuming and expensive, regardless of whether we are successful. Despite our efforts, our intellectual property rights, particularly existing or future patents, may be invalidated, circumvented, challenged, infringed or required to be licensed to others. We cannot be assured that any steps we may take to protect our intellectual property rights and other rights to such proprietary technologies that are central to our operations will prevent misappropriation or infringement of the right to use or license others to use the Extraction Technology and accordingly may conduct an oil sands extraction operation similar to ours.

  

Certain Factors Related to Our Common Shares

 

There presently is a limited market for our common shares, and the price of our common shares may continue to be volatile.

 

Our common shares are currently quoted on the TSXV, the Frankfurt Exchange and the OTC Pink.  Our common shares, however, are very thinly traded, and we have a very limited trading history.  There could continue to be volatility in the volume and market price of our common shares moving forward.  This volatility may be caused by a variety of factors, including the lack of readily available quotations, the absence of consistent administrative supervision of “bid” and “ask” quotations and generally lower trading volume. In addition, factors such as quarterly variations in our operating results, changes in financial estimates by securities analysts or our failure to meet our or their projected financial and operating results, litigation involving us, factors relating to the oil and gas industry, actions by governmental agencies, national economic and stock market considerations as well as other events and circumstances beyond our control could have a significant impact on the future market price of our common shares and the relative volatility of such market price.

 

Offers or availability for sale of a substantial number of shares of our common shares may cause the price of our common shares to decline.

 

Our shareholders could sell substantial amounts of common shares in the public market, including shares sold upon the filing of a registration statement that registers such shares and/or upon the expiration of any statutory holding period under Rule 144 of the Securities Act of 1933 (the “Securities Act”), if available, or upon trading limitation periods.  Such volume could create a circumstance commonly referred to as an “overhang” and in anticipation of which the market price of our common shares could fall. The existence of an overhang, whether or not sales have occurred or are occurring, also could make it more difficult for us to secure additional financing through the sale of equity or equity-related securities in the future at a time and price that we deem reasonable or appropriate.

 

We do not anticipate paying any cash dividends.

 

We do not anticipate paying cash dividends on our common shares for the foreseeable future.  The payment of dividends, if any, would be contingent upon our revenues and earnings, if any, capital requirements, and general financial condition.  The payment of any dividends will be within the discretion of our Board of Directors.  We presently intend to retain all earnings, if any, to implement our business strategy; accordingly, we do not anticipate the declaration of any dividends in the foreseeable future.

 

The market price and trading volume of our common shares may continue to be volatile and may be affected by variability in our performance from period to period and economic conditions beyond management’s control.

 

The market price of our common shares may continue to be highly volatile and could be subject to wide fluctuations. This means that our shareholders could experience a decrease in the value of their common shares regardless of our operating performance or prospects. The market prices of securities of companies operating in the oil and gas sector have often experienced fluctuations that have been unrelated or disproportionate to the operating results of these companies. In addition, the trading volume of our common shares may fluctuate and cause significant price variations to occur. If the market price of our common shares declines significantly, our shareholders may be unable to resell our common shares at or above their purchase price, if at all. There can be no assurance that the market price of our common shares will not fluctuate or significantly decline in the future.

 

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Some specific factors that could negatively affect the price of our common shares or result in fluctuations in their price and trading volume include:

 

  actual or expected fluctuations in our operating results;
  actual or expected changes in our growth rates or our competitors’ growth rates;
  our inability to raise additional capital, limiting our ability to continue as a going concern;
  changes in market prices for our product or for our raw materials;
  changes in market valuations of similar companies;
  changes in key personnel for us or our competitors;
  speculation in the press or investment community;
  changes or proposed changes in laws and regulations affecting the renewable energy industry as a whole;
  conditions in the renewable energy industry generally; and
  conditions in the financial markets in general or changes in general economic conditions.

  

In the past, following periods of volatility in the market price of the securities of other companies, shareholders have often instituted securities class action litigation against such companies. If we were involved in a class action suit, it could divert the attention of senior management and, if adversely determined, could have a material adverse effect on our results of operations and financial condition.

 

We may be classified as a foreign investment company for U.S. federal income tax purposes, which could subject U.S. investors in our common shares to significant adverse U.S. income tax consequences.

 

Depending upon the value of our common shares and the nature of our assets and income over time, we could be classified as a “passive foreign investment company”, or “PFIC”, for U.S. federal income tax purposes. Based upon our current income and assets and projections as to the value of our common shares, we do not presently expect to be a PFIC for the current taxable year or the foreseeable future. While we do not expect to become a PFIC, if among other matters, our market capitalization is less than anticipated or subsequently declines, we may be a PFIC for the current or future taxable years. The determination of whether we are or will be a PFIC will also depend, in part, on the composition of our income and assets, which will be affected by how, and how quickly, we use our liquid assets. Because PFIC status is a factual determination made annually after the close of each taxable year, including ascertaining the fair market value of our assets on a quarterly basis and the character of each item of income we earn, we can provide no assurance that we will not be a PFIC for the current taxable year or any future taxable year.

 

If we were to be classified as a PFIC in any taxable year, a U.S. holder would be subject to special rules generally intended to reduce or eliminate any benefits from the deferral of U.S. federal income tax that a U.S. holder could derive from investing in a non-U.S. corporation that does not distribute all of its earnings on a current basis. Further, if we are classified as a PFIC for any year during which a U.S. holder holds our common shares, we generally will continue to be treated as a PFIC for all succeeding years during which such U.S. holder holds our common shares.

 

We are exposed to credit risk through our cash and cash equivalents held at financial institutions.

 

Credit risk is the risk of unexpected loss if a customer or third party to a financial instrument fails to meet contractual obligations. We are exposed to credit risk through our cash and cash equivalents held at financial institutions. We have cash balances at four financial institutions. We have not experienced any loss on these accounts, although balances in the accounts may exceed the insurable limits.

 

Some of our officers and directors have conflicts of interest and cannot devote a substantial amount of time to our company.

 

Certain of our current directors and officers are, and may continue to be, involved in other industries through their direct and indirect participation in corporations, partnerships or joint ventures which may be potential competitors of ours. Several of our officers work for us on a part time basis. These officers have discretion as to what time they devote to our activities, which may result in lack of availability when needed due to responsibilities at other jobs. In addition, situations may arise in connection with potential acquisitions or opportunities where the other interests of these directors and officers may conflict with our interests. Directors and officers with conflicts of interest will be subject to and follow the procedures set out in applicable corporate and securities legislation, regulation, rules and policies. Certain of our directors and officers will only devote a portion of their time to our business and affairs and some of them are or will be engaged in other projects or businesses.

 

Our ability to issue an unlimited number of common shares and preferred shares may have anti-takeover effects that could discourage, delay or prevent a change of control and may result in dilution to our investors.

 

Our charter documents currently authorize the issuance of an unlimited number of common shares without nominal or par value and an unlimited number of preferred shares without nominal or par value in one or more series without the requirement that we obtain any shareholder approval. The Board could authorize the issuance of additional preferred shares that would grant holders rights to our assets upon liquidation, special voting rights, redemption rights. That could impair the rights of holders of common shares and discourage a takeover attempt. In addition, in an effort to discourage a takeover attempt, our Board could issue an unlimited number of additional common shares. There are currently no preferred shares outstanding. If we issue any additional shares or enter into private placements to raise financing through the sale of equity securities, investors’ interests in our company will be diluted and investors may suffer substantial dilution in their net book value per share depending on market conditions and the price at which such securities are sold. If we issue any such additional shares, such issuances also will cause a reduction in the proportionate ownership and voting power of all other shareholders.

 

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Issuances of common shares upon exercise or conversion of convertible securities, including pursuant to our equity incentive plans and outstanding warrants and convertible notes could result in additional dilution of the percentage ownership of our stockholders and could cause our stock price to fall.

 

We currently have warrants to purchase 20,714,715 common shares outstanding at exercise prices ranging from US 0.48 to $21.66 (CDN$28.35) and options to purchase 9,858,333 common shares with a weighted average exercise price of CDN $1.22 and notes convertible into 8,610,416 common shares based on conversion prices ranging from $0.40 to $1.00 per share. The issuance of the common shares underlying the warrants, options and convertible notes will have a dilutive effect on the percentage ownership held by holders of our common shares.

 

We have applied to list our common shares on the NASDAQ Capital Market (“NASDAQ”); however, there can be no assurance that our common shares will be approved for listing on NASDAQ or if approved that we will meet the continued listing requirements.

 

We have applied to list our common shares on NASDAQ; however, we currently do not meet the initial listing requirements of NASDAQ. In particular, we do not meet the stock price requirement and may be required to effect another reverse stock split in order to meet such requirement.

  

If after listing we fail to satisfy the continued listing requirements of NASDAQ such as the corporate governance requirements, the stockholder’s equity requirement or the minimum closing bid price requirement, NASDAQ may take steps to de-list our common shares. Such a de-listing or even notification of failure to comply with such requirements would likely have a negative effect on the price of our common shares and would impair your ability to sell or purchase our common shares when you wish to do so. In the event of a de-listing, we would take actions to restore our compliance with the NASDAQ’s listing requirements, but we can provide no assurance that any such action taken by us would allow our common shares to become listed again, stabilize the market price or improve the liquidity of our common shares, prevent our common shares from dropping below the NASDAQ minimum bid price requirement or prevent future non-compliance with the NASDAQ’s listing requirements.

 

The National Securities Markets Improvement Act of 1996, which is a federal statute, prevents or preempts the states from regulating the sale of certain securities, which are referred to as “covered securities.” Because we expect that our common shares will be listed on NASDAQ, our common shares will be covered securities. Although the states are preempted from regulating the sale of covered securities, the federal statute does allow the states to investigate companies if there is a suspicion of fraud, and, if there is a finding of fraudulent activity, then the states can regulate or bar the sale of covered securities in a particular case. Further, if we were to be delisted from NASDAQ, our common shares would cease to be recognized as covered securities and we would be subject to regulation in each state in which we offer our securities.

 

In order to meet the initial listing requirements of NASDAQ, we may need to effect a reverse stock split.

 

In order to meet the initial listing requirements of NASDAQ. We will likely need to effect a reverse stock split. There are risks associated with a reverse split, including that a reverse split may not result in a sustained increase in the per share price of our common shares. There is no assurance that:

 

  the market price per share of our common shares after a reverse split will rise in proportion to the reduction in the number of shares of our common shares outstanding before the reverse split;
  a reverse split will result in a per share price that will attract brokers and investors who do not trade in lower priced stocks;
  a reverse split will result in a per share price that will increase our ability to attract and retain employees and other service providers; and
  the market price per share will either exceed or remain in excess of the minimum bid price as required by NASDAQ Capital Market, or that we will otherwise meet the requirements of NASDAQ Capital Market for initial listing for trading on NASDAQ.

 

Even if the market price of our common shares does rise following a reverse split, we cannot assure you that the market price of our common shares immediately after a reverse split will be maintained for any period of time. Even if an increased per-share price can be maintained, a reverse split may not achieve the desired results that have been outlined above. Moreover, because some investors may view a reverse split negatively, we cannot assure you that a reverse split will not adversely impact the market price of our common shares.

 

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The risks associated with penny stock classification could affect the marketability of our common shares and shareholders could find it difficult to sell their shares.

 

Our common shares are currently subject to “penny stock” rules as promulgated under the Securities and Exchange Act of 1934, as amended. The SEC adopted rules that regulate broker-dealer practices in connection with transactions in penny stocks. Transaction costs associated with purchases and sales of penny stocks are likely to be higher than those for other securities. Penny stocks generally are equity securities with a price of less than $5.00 (other than securities listed on certain national securities exchanges, provided that current price and volume information with respect to transactions in such securities is provided by the exchange).

 

The penny stock rules require a broker-dealer, prior to a transaction in a penny stock not otherwise exempt from the rules, to deliver a standardized risk disclosure document that provides information about penny stocks and the nature and level of risks in the penny stock market. The broker-dealer also must provide the customer with current bid and offer quotations for the penny stock, the compensation of the broker-dealer and its salesperson in the transaction, and monthly account statements showing the market value of each penny stock held in the customer’s account. The bid and offer quotations, and the broker-dealer and salesperson compensation information, must be given to the customer orally or in writing prior to effecting the transaction and must be given to the customer in writing before or with the customer’s confirmation.

 

In addition, the penny stock rules require that prior to a transaction in a penny stock not otherwise exempt from such rules, the broker- dealer must make a special written determination that the penny stock is a suitable investment for the purchaser and receive the purchaser’s written agreement to the transaction. These disclosure requirements may have the effect of reducing the level of trading activity in the secondary market for our common shares in the United States and shareholders may find it more difficult to sell their shares.

  

The rights of our shareholders may differ from the rights typically offered to shareholders of a U.S. corporation.

 

We are incorporated under the Business Corporations Act (Ontario). The rights of holders of our common shares are governed by the laws of the Province of Ontario, including the Business Corporations Act (Ontario), by the applicable laws of Canada, and by our Articles, as amended (the “Articles”), and our bylaws (the “bylaws”). These rights differ in certain respects from the rights of shareholders in typical U.S. corporations. The principal differences include without limitation the following:

 

Under the Business Corporations Act (Ontario), we have a lien on any common share registered in the name of a shareholder or the shareholder’s legal representative for any debt owed by the shareholder to us. Under U.S. state law, corporations generally are not entitled to any such statutory liens in respect of debts owed by shareholders. Our bylaws also provide that at least 25% of our Board of Directors must be resident Canadians.

 

With regard to certain matters, we must obtain approval of our shareholders by way of at least 66 2/3% of the votes cast at a meeting of shareholders duly called for such purpose being cast in favor of the proposed matter. Such matters include without limitation: (a) the sale, lease or exchange of all or substantially all of our assets out of the ordinary course of our business; and (b) any amendments to our Articles including, but not limited to, amendments affecting our capital structure such as the creation of new classes of shares, changing any rights, privileges, restrictions or conditions in respect of our shares, or changing the number of issued or authorized shares, as well as amendments changing the minimum or maximum number of directors set forth in the Articles. Under many U.S. state laws, the sale, lease, exchange or other disposition of all or substantially all of the assets of a corporation generally requires approval by a majority of the outstanding shares, although in some cases approval by a higher percentage of the outstanding shares may be required. In addition, under U.S. state law the vote of a majority of the shares is generally sufficient to amend a company’s certificate of incorporation, including amendments affecting capital structure or the number of directors.

 

Pursuant to our bylaws, two persons holding 5% of the shares entitled to vote at the meeting present in person or represented by proxy and each entitled to vote thereat shall constitute a quorum for the transaction of business at any meeting of shareholders. Under U.S. state law, a quorum generally requires the presence in person or by proxy of a specified percentage of the shares entitled to vote at a meeting, and such percentage is generally not less than one-third of the number of shares entitled to vote.

 

Under rules of the Ontario Securities Commission, a meeting of shareholders must be called for consideration and approval of certain transactions between a corporation and any “related party” (as defined in such rules). A “related party” is defined to include, among other parties, directors and senior officers of a corporation, holders of more than 10% of the voting securities of a corporation, persons owning a block of securities that is otherwise sufficient to affect materially the control of the corporation, and other persons that manage or direct, to a substantial degree, the affairs or operations of the corporation. At such shareholders’ meeting, votes cast by any related party who holds common shares and has an interest in the transaction may not be counted for the purposes of determining whether the minimum number of required votes have been cast in favor of the transaction. Under U.S. state law, a transaction between a corporation and one or more of its officers or directors can generally be approved either by the shareholders or a by majority of the directors who do not have an interest in the transaction.

 

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Neither Canadian law nor our Articles or bylaws limit the right of a non-resident to hold or vote our common shares, other than as provided in the Investment Canada Act (the “Investment Act”), as amended by the World Trade Organization Agreement Implementation Act (the “WTOA Act”). The Investment Act generally prohibits implementation of a direct reviewable investment by an individual, government or agency thereof, corporation, partnership, trust or joint venture that is not a “Canadian,” as defined in the Investment Act (a “non-Canadian”), unless, after review, the minister responsible for the Investment Act is satisfied that the investment is likely to be of net benefit to Canada. An investment in our common shares by a non-Canadian (other than a “WTO Investor,” as defined below) would be reviewable under the Investment Act if it were an investment to acquire our direct control, and the value of our assets were CDN$5.0 million or more (provided that immediately prior to the implementation of the investment in our company was not controlled by WTO Investors). An investment in our common shares by a WTO Investor (or by a non- Canadian other than a WTO Investor if, immediately prior to the implementation of the investment our company was controlled by WTO Investors) would be reviewable under the Investment Act if it were an investment to acquire our direct control and the value of our assets equaled or exceeded certain threshold amounts determined on an annual basis.

 

The threshold for a pre-closing net benefit review depends on whether the purchaser is: (a) controlled by a person or entity from a member of the WTO; (b) a state-owned enterprise (SOE); or (c) from a country considered a “Trade Agreement Investor” under the Investment Act. A different threshold also applies if the Canadian business carries on a cultural business.

 

The 2018 threshold for WTO investors that are SOEs will be CDN$398 million based on the book value of the Canadian business’ assets, up from CDN$379 million in 2017.

 

The 2018 thresholds for review for direct acquisitions of control of Canadian businesses by private sector investor WTO investors (CDN$1 billion) and private sector trade-agreement investors (CDN$1.5 billion) remain the same and are both based on the “enterprise value” of the Canadian business being acquired.

 

A non-Canadian, whether a WTO Investor or otherwise, would be deemed to acquire control of our company for purposes of the Investment Act if he or she acquired a majority of our common shares. The acquisition of less than a majority, but at least one-third of the shares, would be presumed to be an acquisition of control of our company, unless it could be established that we are not controlled in fact by the acquirer through the ownership of the shares. In general, an individual is a WTO Investor if he or she is a “national” of a country (other than Canada) that is a member of the WTO (“WTO Member”) or has a right of permanent residence in a WTO Member. A corporation or other entity will be a “WTO Investor” if it is a “WTO Investor-controlled entity,” pursuant to detailed rules set out in the Investment Act. The U.S. is a WTO Member. Certain transactions involving our common shares would be exempt from the Investment Act, including:

 

  an acquisition of our common shares if the acquisition were made in connection with the person’s business as a trader or dealer in securities;
  an acquisition of control of our company in connection with the realization of a security interest granted for a loan or other financial assistance and not for any purpose related to the provisions of the Investment Act; and
  an acquisition of control of our company by reason of an amalgamation, merger, consolidation or corporate reorganization, following which the ultimate direct or indirect control of our company, through the ownership of voting interests, remains unchanged. Under U.S. law, except in limited circumstances, restrictions generally are not imposed on the ability of non- residents to hold a controlling interest in a U.S. corporation.

   

Upon effectiveness of this registration statement on Form 10, we will be required to comply with the Exchange Act’s domestic reporting regime and cause us to incur significant legal, accounting and other expenses.

 

Upon effectiveness of this registration statement on Form 10, we will be required to comply with all of the periodic disclosure and current reporting requirements of the Exchange Act applicable to U.S. domestic issuers, which are more detailed and extensive than the requirements for foreign private issuers. We may also be required to make changes in our corporate governance practices in accordance with various SEC and NASDAQ rules. As a result, we expect that compliance would increase our legal and financial compliance costs and is likely to make some activities highly time consuming and costly. We also expect that if we were required to comply with the rules and regulations applicable to U.S. domestic issuers, it would make it more difficult and expensive for us to obtain director and officer liability insurance, and we may be required to accept reduced coverage or incur substantially higher costs to obtain coverage. These rules and regulations could also make it more difficult for us to attract and retain qualified members of our Board of Directors.

 

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We are an emerging growth company within the meaning of the Securities Act and intend to take advantage of certain reduced reporting requirements.

 

We are an “emerging growth company,” or EGC, as defined in the Jumpstart Our Business Start-ups Act of 2012, or the JOBS Act. For as long as we continue to be an EGC, we may take advantage of exemptions from various reporting requirements that are applicable to other public companies that are not emerging growth companies, including not being required to comply with the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act, or Section 404, exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and shareholder approval of any golden parachute payments not previously approved. As an EGC, we are required to report only two years of financial results and selected financial data compared to three and five years, respectively, for comparable data reported by other public companies. We may take advantage of these exemptions until we are no longer an EGC. We could be an EGC for up to five years, although circumstances could cause us to lose that status earlier, including if the aggregate market value of our common shares held by non- affiliates exceeds $700 million as of any February 28 (the end of our second fiscal quarter) before that time, in which case we would no longer be an EGC as of the following August 31 (our fiscal year-end). We cannot predict if investors will find our common shares less attractive because we may rely on these exemptions. If some investors find our common shares less attractive as a result, there may be a less active trading market for our common shares and the price of our common shares may be more volatile in the event that we decide to make an offering of our common shares following this direct listing.

 

Claims of U.S. civil liabilities may not be enforceable against us.

 

We are incorporated under Canadian law. Certain members of our Board of Directors and senior management are non- residents of the United States, and many of our assets and the assets of such persons are located outside the United States. As a result, it may not be possible to serve process on such persons or us in the United States or to enforce judgments obtained in U.S. courts against them or us based on civil liability provisions of the securities laws of the United States. As a result, it may not be possible for investors to effect service of process within the United States upon such persons or to enforce judgments obtained in U.S. courts against them or us, including judgments predicated upon the civil liability provisions of the U.S. federal securities laws.

 

The United States and Canada do not currently have a treaty providing for recognition and enforcement of judgments (other than arbitration awards) in civil and commercial matters. Consequently, a final judgment for payment given by a court in the United States, whether or not predicated solely upon U.S. securities laws, would not automatically be recognized or enforceable in Canada. In addition, uncertainty exists as to whether Canadian courts would entertain original actions brought in the United States against us or our directors or senior management predicated upon the securities laws of the United States or any state in the United States. Any final and conclusive monetary judgment for a definite sum obtained against us in U.S. courts would be treated by the courts of Canada as a cause of action in itself and sued upon as a debt at common law so that no retrial of the issues would be necessary, provided that certain requirements are met. Whether these requirements are met in respect of a judgment based upon the civil liability provisions of the U.S. securities laws, including whether the award of monetary damages under such laws would constitute a penalty, is an issue for the court making such decision. If a Canadian court gives judgment for the sum payable under a U.S. judgment, the Canadian judgment will be enforceable by methods generally available for this purpose. These methods generally permit the Canadian court discretion to prescribe the manner of enforcement.

 

As a result, U.S. investors may not be able to enforce against us or our senior management, Board of Directors or certain experts named herein who are residents of Canada or countries other than the United States any judgments obtained in U.S. courts in civil and commercial matters, including judgments under the U.S. federal securities laws.

 

Our ability to use our net operating losses and certain other tax attributes may be limited.

 

As of August 31, 2018, we had accumulated net operating losses (NOLs), of approximately CDN $31.0 million. Varying jurisdictional tax codes have restrictions on the use of NOLs, if a corporation undergoes an “ownership change,” the corporation’s ability to use its pre-change NOLs, R&D credits and other pre-change tax attributes to offset its post-change income may be limited. An ownership change is generally defined as a greater than 50% change in equity ownership. Based upon an analysis of our equity ownership, we do not believe that we have experienced such ownership changes and therefore our annual utilization of our NOLs is not limited. However, should we experience additional ownership changes, our NOL carry forwards may be limited.

 

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ITEM 2. FINANCIAL INFORMATION.

 

Cautionary Note Regarding Forward-Looking Information

 

The following discussion of our financial condition and results of operations should be read in conjunction with the consolidated historical financial statements and the related notes appearing elsewhere in this registration statement. The following discussion should also be read in conjunction with the other information relating to our business contained in this registration statement on Form 10, including Item 1A “Risk Factors.”

 

The Historical Financial Information has been prepared in accordance with IFRS as issued by the International Accounting Standards Board. All dollar figures in this management discussion and analysis (“MD&A”) are presented in United States dollars unless otherwise indicated.

 

Cautionary Note Regarding Forward-Looking Information

 

This MD&A contains certain forward-looking information and forward-looking statements, as defined in applicable securities laws (collectively referred to herein as “forward-looking statements”). These statements relate to future events or our future performance. All statements other than statements of historical fact are forward-looking statements. Often, but not always, forward-looking statements can be identified by the use of words such as “plans”, “expects”, “is expected”, “budget”, “scheduled”, “estimates”, “continues”, “forecasts”, “projects”, “predicts”, “intends”, “anticipates” or “believes”, or variations of, or the negatives of, such words and phrases, or state that certain actions, events or results “may”, “could”, “would”, “should”, “might” or “will” be taken, occur or be achieved.

 

Forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause actual results to differ materially from those anticipated in such forward-looking statements. The forward- looking statements in this MD&A speak only as of the date of this MD&A or as of the date specified in such statement. Specifically, this MD&A includes, but is not limited to, forward-looking statements regarding: the validation of and commercial viability of PQE’s Extraction Technology (defined below); the ability of the Extraction Technology to commence commercial production; the environmental friendliness of the Extraction Technology; the bbl/d capacity of the Extraction Technology; the schedule for certain events to occur and production to commence; capital efficacy and economics of the Extraction Technology; completion of certain acquisitions; potential of PQE’s properties to contain reserves; PQE’s ability to meet its working capital needs; the plans, costs, timing and capital for future exploration and development of PQE’s property interests, including the costs and potential impact of complying with existing and proposed laws and regulations; management’s outlook regarding future trends; sensitivity analysis on financial instruments, which may vary from amounts disclosed; prices and price volatility for oil and gas; and general business and economic conditions.

 

Inherent in forward-looking statements are risks, uncertainties and other factors beyond our ability to predict or control. These risks, uncertainties and other factors include, but are not limited to, oil and gas reserves, price volatility, changes in debt and equity markets, timing and availability of external financing on acceptable terms, the uncertainties involved in interpreting geological data and confirming title to properties, the possibility that future exploration results or the validation of technology will not be consistent with our expectations, increases in costs, environmental compliance and changes in environmental and other local legislation and regulation, interest rate and exchange rate fluctuations, changes in economic and political conditions and other risks involved in the oil and gas industry, as well as those risk factors listed in the “Risk Factors” in Item 3D. Readers are cautioned that the foregoing list of factors is not exhaustive of the factors that may affect the forward-looking statements. Actual results and developments are likely to differ, and may differ materially, from those expressed or implied by the forward-looking statements contained in this MD&A. Such statements are based on a number of assumptions that may prove to be incorrect, including, but not limited to, assumptions about the following: the availability of financing for PQE’s exploration and development activities; operating and exploration costs; PQE’s ability to retain and attract skilled staff; timing of the receipt of regulatory and governmental approvals for exploration and production projects and other operations; market competition; and general business and economic conditions.

 

Forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause our actual results, performance or achievements to be materially different from any of its future results, performance or achievements expressed or implied by forward-looking statements. All forward-looking statements herein are qualified by this cautionary statement. Accordingly, readers should not place undue reliance on forward-looking statements. We undertake no obligation to update publicly or otherwise revise any forward-looking statements, whether as a result of new information or future events or otherwise, except as may be required by law. If we do update one or more forward-looking statements, no inference should be drawn that it will make additional updates with respect to those or other forward-looking statements, unless required by law.

 

Overview

 

Since our corporate reorganization and agreement to dispose of our interest in MCW Fuels, LLC (“MCW Fuels”), which was effective May 13, 2015 and for which regulatory approval was received on June 19, 2015, we have had one wholly owned subsidiary, PQE, which has three wholly owned active subsidiary companies, PQE Oil, TMC and Petrobloq. We are now primarily focused on developing our oil sands extraction business and related mining interests.

 

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Through our wholly owned subsidiary PQE, and its two subsidiaries PQE Oil and TMC, we are in the business of oil sands mining on property that TMC leases and processing the mined bitumen deposits using proprietary Extraction Technology to recover oil from surface mined bitumen deposits. PQE Oil is based in Uintah, Utah. The proprietary Extraction Process is conducted in a plant that was recently relocated to the TMC mining site to improve logistical and processing efficiencies of the oil sands recovery process. We once again commenced mining operations at the end of May 2018 and expect to complete our expansion project to increase production to at least 1,000 barrels per day by the last quarter of fiscal 2019. Until our expansion project is completed and we are at full production levels our revenue will suffer. In addition, once we are operating at full production levels, we anticipate that we will need to hire additional staff. We expect that we will require additional capital to continue our operations and planned growth. There can be no assurance that funding will be available if needed or that the terms will be acceptable.

 

PQE owns the intellectual property rights to the patented Extraction Technology which it has used at the plant to extract oil from oil sands utilizing a closed-loop solvent based extraction system, as more completely described below.

 

On July 4, 2016, PQE acquired a controlling interest of 57.3% in Accord. Accord’s assets include a limited license for two enhanced oil recovery (EOR) technologies for use on Accord’s southwest Texas oil opportunities and can also be used on PQE’s 2,200 acre oil sands property in Temple Mountain, Utah. It also includes equitable title pursuant to a purchase agreement to 7,000 acres in southwest Texas, with 88 drilled and completed wells. The oil is categorized as “medium crude” and the deposits are in the light gravity range of heavy oil at 18-22 API gravity.

 

Due to additional cash injections and share subscriptions in Accord by the outside shareholders, PQE has relinquished control of Accord and has deconsolidated the results of Accord from the financial statements and now accounts for the investment in Accord on the equity basis of accounting. The effective holding in Accord as of August 31, 2017 is 44.7%.

 

Our indirect subsidiary, Petrobloq, which was formed in November 2017, is developing a blockchain-powered supply chain management platform for the oil and gas industry. We also own a 25% interest in Recruiter OGG, a recruitment venture that provides a website focused on careers in the oil and gas industry.

 

On June 1, 2018 we finalized the acquisition at auction of a 100% interest in two leases for 1,312 acres of land within the Asphalt Ridge, Utah area. We hold a 100% working interest in 2,541.73 acre oil sands leases covering oil sands within the Asphalt Ridge area, Utah. The lease grants an interest to all crude bitumen containing contingent resources of 87.495 MMbbl (C2 best estimate) on the 2,541.73 acres of leased lands and we have identified that the significant portion of the contingent resource has favorable characteristics for surface mining. The leased land contains oil sands deposits which we believe will increase the available resource utilized by our oil extraction plant.

 

Management’s Discussion and Analysis of Financial Condition and Results of Operation

 

Results of Operations for the Three Months Ended November 30, 2018 and November 30, 2017

 

The tables below present our selected consolidated financial data for the three months ended September 30, 2018 and 2017, which are derived from our unaudited condensed consolidated financial statements. The selected historical consolidated financial data set forth below should be read in conjunction with our consolidated financial statements and related notes included in this registration statement. The following selected financial information, for the three month periods set forth below as shown in the table, was prepared in accordance with IFRS:

   

  Year ended 

November 30,
2018

($)

  

November 30,
2017

($)

 
  Total revenues from continuing operations   Nil    Nil 
  Cost of Goods Sold   33,750    111,250 
  Gross Loss   33,750    111,250 
  Operating Expenses   6,000,323    3,489,467 
  Net loss   6,034,073    3,600,717 
  Loss on Settlement of Liabilities   108,973    Nil 
  Loss on Settlement of Convertible Debt   79,410    Nil 
  Equity Loss from investment of Accord GR Energy, net of tax   50,000    44,995 
  Basic and diluted loss per share*   0.07    0.07 

 

* Adjusted for 30 for 1 share consolidation on May 5, 2017.

 

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Comparison of results of Operations for the three months ended November 30, 2018 and November 30, 2017

 

Net Revenue, Cost of Goods Sold and Gross Loss

 

During the three months ended November 30, 2018, we continued conducting test runs of the 1,000 barrel per day plant and continued with our expansion project to increase production capacity by an additional 3,000 barrels per day. Revenue generation is expected to commence during the second quarter of fiscal 2019. Prior to August 31, 2018, due to the volatility in oil markets and the limited production capacity at the plant, no production took place during the year ended August 31, 2018, resulting in no revenue generation. During the year ended August 31, 2018, we relocated our production plant to the Asphalt Ridge mineral site and expanded production capacity to approximately 1,000 barrels per day with a further expansion to 3,000 barrels per day underway.

 

The cost of goods sold during the three months ended November 30, 2018 and 2017 consists of advance royalty payments which expire at the end of the calendar year, two years after the payment has been made. These expired royalties have been expensed.

  

Operating Expenses

 

Operating expenses from continuing operations were $6,000,323 for the three months ended November 30, 2018, compared to $3,489,467 for the three months ended November 30, 2017. The increase in operating expenses is primarily due to:

 

a.An increase in general and administrative expenses of $163,728 or 575% from $28,478 in fiscal 2018 to $192,206 in fiscal 2019. The increase is primarily due to an increase in administrative activity related to the relocation of the plant and the increase in head count to administer the capital expenditure and the plant operations;
b.An increase in capital raising fees of $1,276,980 or 100% from $0 for the three months ended November 30, 2017 to $1,276,980 for the three months ended November 30, 2018. The fee represents stock based compensation paid for the $9,500,000 letter of credit facility provided by Bay Private Equity during September 2018;
c.An increase in interest expense of $97,195 or 80% from $121,484 for the three months ended November 30, 2017 to $218,679 for the three months ended November 30, 2018, due to the convertible notes issued during the three months ended November 30, 2018 to fund the plant expansion of an additional 3,000, barrels per day;

  d. An increase in legal fees of $648,740 or 1,989% from $32,625 for the three months ended November 30, 2017 to $681,365 for the three months ended November 30, 2018. The increase is primarily due to the expansion of the plant and the various fund raising initiatives undertaken by us during the for the three months ended November 30, 2018;

  e. An increase in professional fees of $1,267,492 or 524% for the three months ended November 30, 2018 as compared to the three months ended November 30, 2017, primarily due to professional fees paid to various vendors related to the expansion of the plant and management advisory board services;

  f. An increase in research and development costs of $112,625 of 100%, from $nil for the three months ended November 30, 2017 to $112,625 for the three months ended November 30, 2018, related to expenditure incurred on the development of the Petrobloq blockchain project;

  g. An increase in travel and promotion, and investor relations expense of $1,148,650 or 1,439% from $79,814 for the three months ended November 30, 2017 to $1,228,464 for the three months ended November 30, 2018, primarily related to marketing, public relations and travel costs;

  h. Offset by a reduction in share based compensation expense of $1,951,322 or 78% from $2,505,647 for the three months ended November 30, 2017 to $554,325 for the three months ended November 30, 2018. The prior period charge represents the value of fully vested options issued in November 2017 to certain board members and officers, the current period charge represents the charge for options issued to directors, officer and certain consultants during June 2018, with four year vesting terms.

 

Loss on settlement of liabilities

 

The loss on settlement of liabilities increased by $108,973 or 100% from $nil for the three months ended November 30, 2017 to $108,973 for the three months ended November 30, 2018. The current period loss was realized on the settlement of $545,194 of debt by the issue of 681,151 common shares at a discount to market prices.

 

Loss on settlement of convertible debt

 

The loss on settlement of convertible debt increased by $79,410 or 100% from $nil for the three months ended November 30, 2017 to $79,410 for the three months ended November 30, 2018. The current period loss was realized on the conversion of $255,078 of convertible debt by the issue of 316,223 common shares at a discount to market prices.

 

Equity loss from investment of Accord GR Energy

 

The loss from investment in Accord GR Energy increased by $5,005 or 11% from $44,995 for the three months ended November 30, 2017 to $50,000 for the three months ended November 30, 2018.

 

29

 

 

The following selected financial information, for the three month periods set forth below as shown in the table, was prepared in accordance with IFRS:

  

  3 months ended 

November 30,

2018

($)

  

August 31,

2018

($)

  

May 31,

2018

($)

  

February 28,
2018

($)

 
  Total revenues   -    -    -    - 
  Net loss   6,272,456    6,555,072    3,178,839    1,732,532 
  Basic and diluted loss per share   0.07    0.09    0.05    0.03 

  

  3 months ended 

November 30,

2017

($)

  

August 31,

2017

($)

  

May 31,

2017

($)

  

February 28,
2017

($)

 
  Total revenues   -    -    -    - 
  Net loss   3,645,712    3,101,430    3,581,788    514,637 
  Basic and diluted loss per share*   0.07    0.12    0.46    0.08 

 

* Adjusted for 30 for 1 share consolidation on May 5, 2017.

 

The net loss for the three months ended November 30, 2018 includes:

(i)33,750 of cost of sales due to the expiration of advanced royalty payments paid to the mineral lease lessor;

  (ii) capital raising fees of $1,276,980 related to the letter of credit facility provided to us by Bay Capital Private Equity;

(iii)legal fees of $681,365 related to the expansion of the plant and the various fund raising initiatives undertaken during the current fiscal period;
(iv)professional fees of $1,509,153 related to the expansion of the plant;
(v)Share based compensation of $554,325 related to options issued to directors and officers in June 2018; and
(vi)Travel and promotional expenses of $1,228,464, primarily related to marketing, public relations and travel costs.

 

The net loss for the three months ended August 31, 2018, includes:

(i)$38,213 of cost of sales, due to the expiration of advanced royalty payments paid to the lessor;
(ii)$527,872 of travel and promotional, and investor relation expenses due to advisory board fees and marketing activities undertaken to market our company and our production processes and technology;
(iii)$1,867,229 of professional fees predominantly composed of advisory board fees and fees paid to management and financial consultants; and
(iv)$2,832,523 of share based compensation due to the issue of 8,350,000 options to directors, officers and consultants during the quarter.

 

The net loss for the three months ended May 31, 2018, includes;

(i)marketing and public relations activity of approximately $1,560,000;
(ii)professional fees of $890,000, being primarily composed of advisory fees on developing the business strategy; and
(iii)Salaries and wages also increased significantly to $252,000 as the Company completed its expansion project and employed skilled people to assist with the project.

 

The net loss for the three months ended February 28, 2018, has no significant and abnormal expenditures. General and administrative expenses have increased as we prepare for the completion of the expansion project, in addition marketing expenditure has increased as we undertake to increase awareness of the impending completion of the expansion project.

 

The net loss for the three months ended November 30, 2017 includes:

(i)stock based compensation of $2,505,647 related to the grant of 1,425,000 stock options to certain of our directors; and
(ii)an increase in public relations expenditure of $202,844 to renew interest in our oil sands recovery business.

 

The net loss for the three months ended August 31, 2017 includes:

(i)a loss on conversion of equity of $1,459,172 related primarily to an agreement entered into whereby debt due to the Chairman of the Board totaling $3,000,000, including interest thereon was converted to equity at a loss of $1,545,821.

 

30

 

 

The net loss for the three months ended May 31, 2017 includes:

(i)a loss on conversion of equity of $2,253,385 related primarily to agreements entered into whereby debt totaling $12,189,956 was converted into 31,083,281 common shares on May 19, 2017, these shares were issued subsequent to the quarter end.

 

The net loss for the three months ended February 28, 2017 includes:

(i)a gain on settlement of liabilities of $875,369 related primarily to the issuance of shares on the conversion of $2,300,000 of debt to a third party;
(ii)offset by the reversal of a gain previously recognized of $499,894 which gain has been deferred until such time as regulatory approval has been obtained.

   

Results of Operations for the Fiscal Years Ended August 31, 2018 and August 31, 2017

 

The tables below present our selected consolidated financial data for the years ended August 31, 2018 and 2017, which are derived from our audited consolidated financial statements. Our audited consolidated financial statements have been audited by Hay & Watson, an independent registered public accounting firm. The selected historical consolidated financial data set forth below should be read in conjunction with the section titled “Management’s Discussion and Analysis of Financial Condition and Results of Operations” for such periods and our consolidated financial statements and related notes. The following selected financial information, for the annual periods as shown in the table, was prepared in accordance with IFRS:

 

  Year ended 

August 31,
2018

($)

  

August 31,
2017

($)

 
  Revenues   -    - 
  Advance Royalty Payments   272,333    426,641 
  Gross loss   272,333    426,641 
  Operating Expenses   14,643,653    4,948,381 
  Net Operating Loss   14,915,986    5,375,022 
Loss on Settlement of liabilities   92,275    2,366,587 
  Other income   (56,532)   - 
  Equity loss in investment of Accord Gr Energy   160,426    198,034 
  Net loss   15,112,155    7,939,643 
  Basic and diluted loss per share*   0.24    0.66 

   

*Adjusted for the 30 for 1 share consolidation which took place on May 5, 2017.

 

Our Oil Extraction pilot plant was completed on September 1, 2015. For a limited period thereafter, we made minimal sales of hydrocarbon products to customers. Due to the volatility in the oil markets production ceased as we were not able to operate the pilot plant profitably at low volumes of output.

 

The losses from operations over the past two fiscal years are due to us relocating the pilot plant to our TMC mineral lease site to increase production and logistical efficiencies and complete our ongoing construction of our 1,000 barrels per day Oil Extraction plant near Vernal, Utah and continued evaluation of our mineral lease interests.

 

The net loss for the year ended August 31, 2017 included $2,366,587, arising primarily on the conversion of interest bearing debt and convertible debt to equity during the current year, an interest expense of $1,106,808, a decrease from the prior year, due to the conversion of substantial debt to equity during the current year and depreciation and amortization expense of $1,165,830 due to the completion of the oil extraction facility in September 2015.

 

31

 

 

The net loss for the year ended August 31, 2018 included $127,757 of travel and promotional expenses, marketing expenditure to market the plant and the technology and to communicate our progress on the plant and construction efforts amounted to $2,532,029; stock based compensation of $5,356,004 related to 9,775,000 options issued to directors, officers and certain consultants during the year; professional fees of $3,582,986 primarily due to legal fees incurred, advisory board fees and consulting fees for financial services provided and; a loss of $92,275 on the conversion of debt to equity during the current year.

 

Total assets increased between fiscal 2017 and 2018 from $28,950,175 to $39,104,403 is primarily due to; i) the increase in property, plant and equipment of $6,281,942, offset by depreciation of $51,181. The increased capital expenditure began with the relocation of the 500 barrel per day plant to the TMC mining site and the current expansion project to increase production capacity to 3,000 barrels per day with increased efficiencies due to the proximity of the site to the mining operation; and ii) an increase in cash balances of $2,584,581 due to capital raised predominantly through private placements of equity and debt during the current fiscal year to fund the expansion project.

 

Non-current financial liabilities decreased from $1,967,996 in fiscal 2017 to $1,602,646 in fiscal 2018 primarily due to the reduction in convertible debentures due to the conversion of the prior year convertible debentures into equity during the current fiscal year and the issue of a new convertible debenture during the current fiscal year.

 

Comparison of results of Operations from Continuing Operations for the years ended August 31, 2018 and August 31, 2017

 

Net Revenue, Cost of Goods Sold and Gross Loss

 

Due to the volatility in oil markets and the limited production capacity at the plant, no production took place during the years ended August 31, 2018 and August 31, 2017, resulting in no revenue generation. During the year ended August 31, 2018, we relocated our production plant to the Asphalt Ridge mineral site and have expanded production capacity to approximately 1,000 barrels per day with a further expansion to 3,000 barrels per day underway. Management expects to generate revenue from the plant in fiscal 2019. The cost of goods sold during fiscal 2018 consists of advance royalty payments which expire at the end of the calendar year two years after the payment has been made that have been expensed.

 

Operating Expenses

 

Operating expenses from continuing operations were $14,423,202 for the year ended August 31, 2018, compared to $4,948,381 for the year ended August 31, 2017. The increase in operating expenses is primarily due to:

 

  a. An increase in general and administrative expenses of $273,936 or 79% from $348,487 in fiscal 2017 to $622,423 in fiscal 2018. The increase is primarily due to an increase in administrative activity related to the relocation of the pant and the increase in head count to administer the capital expenditure and the plant operations;

 

  b. An increase in travel and promotion, and investor relations expense of $2,198,709 or 528% from $416,007 for fiscal 2017 to $2,614,786 in fiscal 2018, primarily due to marketing efforts undertaken to inform the oil markets of the existence of the plant and the technology and investor relations efforts undertaken;

 

  c. An increase in professional fees of $2,965,371 or 480% from $617,615 in fiscal 2017 to $3,582,986 in fiscal 2018, the increase was due to legal fees incurred, advisory board member fees and financial consulting fees incurred and all related to the relocation and expansion of the production plant;

 

  d. A decrease in plant relocation costs of $437,800 or 100% from $437,800 in fiscal 2017. The plant was relocated to the Asphalt Ridge site during the last quarter of 2017;

 

  e. A decrease in salaries and wages expense of $191,522 or 27% from $702,782 in fiscal 2017 to $511,260 in fiscal 2018 due to reduction of salary expenses paid to certain management personnel;

 

  f. An increase in stock based compensation of $5,340,011 from $15,993 in fiscal 2017 to $5,356,004 in fiscal 2018 due to the valuation of 9,775,000 options issued to directors, officers and management during the 2018 fiscal year;

 

  g. Interest expense decreased by $741,368 from $1,106,808 in fiscal 2017 to $365,440 in fiscal 2018, the decrease is due to the conversion of substantial interest bearing debt into equity during the 2017 and 2018 fiscal year and an increase in funds raised through equity issues during the current fiscal year.

 

32

 

 

Loss on settlement of liabilities

 

The loss on settlement of liabilities decreased by $2,274,312 or 96.1% from $2,366,587 in fiscal 2017 to $92,275 in fiscal 2018. In the prior fiscal year we converted $18,008,990 of long and short term debt and convertible debt to equity. In the current fiscal period we converted $283,671 of long and short term debt and $1,953,013 of payables owed to service providers, to equity. A further $1,175,424 of advances made by the Chairman of the Board was converted to equity as well.

 

Equity loss from investment of Accord GR Energy

 

The loss from investment in Accord GR Energy decreased by $37,608 or 19% from $198,034 in fiscal 2017 to $160,426 in fiscal 2018.

 

Summary of Quarter Results

 

The following selected financial information for the previous eight quarters, as shown in the following table, was prepared in accordance with IFRS.

 

3 months ended  August 31,
2018
($)
  

May 31,
2018
($)

   February 28,
2018
($)
   November 30,
2017
($)
 
Total revenues   -    -    -    - 
Net loss   6,555,072    3,178,839    1,732,532    3,645,712 
Basic and diluted loss per share   0.09    0.05    0.03    0.07 

   

3 months ended  August 31,
2017
($)
  

May 31,
2017
($)

   February 28,
2017
($)
   November 30,
2016
($)
 
Total revenues   -    -    -    - 
Net loss   3,101,430    3,581,788    514,637    741,788 
Basic and diluted loss per share*   0.12    0.46    0.08    0.11 

 

* Adjusted for 30 for 1 share consolidation on May 5, 2017.

 

The net loss for the three months ended August 31, 2018, includes;

 

(i)$38,213 of cost of sales, due to the expiration of advanced royalty payments paid to the lessor;

 

(ii) $527,872 of travel and promotional, and investor relation expenses due to advisory board fees and marketing activities undertaken to market our company and our production processes and technology;

 

33

 

 

(iii) $1,867,229 of professional fees predominantly composed of advisory board fees and fees paid to management and financial consultants; and

 

(iv)$ 2,832,523 of share based compensation due to the issue of 8,350,000 options to directors, officers and consultants during the quarter.

 

The net loss for the three months ended May 31, 2018, includes;

 

(i)marketing and public relations activity of approximately $1,560,000;

 

(ii)professional fees of $890,000, being primarily composed of advisory fees on developing the business strategy; and

 

(iii)Salaries and wages also increased significantly to $252,000 as we completed our expansion project and employed skilled people to assist with the project.

 

The net loss for the three months ended February 28, 2018, has no significant and abnormal expenditures. General and administrative expenses have increased as we prepared for the completion of the expansion project, in addition marketing expenditure has increased as we undertook to increase awareness of the impending completion of the expansion project.

 

The net loss for the three months ended November 30, 2017 includes;

 

(i)stock based compensation of $2,505,647 related to the grant of 1,425,000 stock options to certain of our directors; and

 

(ii)an increase in public relations expenditure of $202,844 to renew interest in its oil sands recovery business.

 

The net loss for the three months ended August 31, 2017 includes;

 

(i)a loss on conversion of equity of $1,459,172 related primarily to an agreement entered into whereby debt due to the Chairman of the Board totaling $3,000,000, including interest thereon was converted to equity at a loss of $1,545,821.

 

The net loss for the three months ended May 31, 2017 includes;

 

(i)a loss on conversion of equity of $2,253,385 related primarily to agreements entered into whereby debt totaling $12,189,956 was converted into 31,083,281 common shares on May 19, 2017, these shares were issued subsequent to the quarter end.

 

The net loss for the three months ended February 28, 2017 includes;

 

(i)a gain on settlement of liabilities of $875,369 related primarily to the issuance of shares on the conversion of $2,300,000 of debt to a third party;

 

(ii)offset by the reversal of a gain previously recognized of $499,894 which gain has been deferred until such time as regulatory approval has been obtained.

 

The net loss for the three months ended November 30, 2016 includes;

 

(i)a gain on settlement of liabilities of $470,601 related primarily to the issuance of shares on the conversion of loans due to the Chairman of the Board of Directors.

 

Analysis of Quarter ended August 31, 2018

 

During the quarter ended August 31, 2018, no revenue or gross profit was generated by us from operations at the Oil Extraction plant. The plant has not operated during the current year and is currently undergoing an expansion to a 3,000 barrel per day plant.

 

Overall expenses increased from approximately $2,987,974 for the quarter ended August 31, 2017 to $6,516,861 for the quarter ended August 31, 2018, an increase of $3,528,887. This increase was primarily due to:

 

i)An increase in travel and promotion, and investor relations costs of $532,099, primarily due to marketing expenses incurred on marketing the production plant and technology to the oil markets;

 

ii)An increase in professional fees of $1,724,959 due to fees paid to advisory board members, financial consultants and legal fees related to the plant expansion;

 

iii)An increase in share based compensation of $2,832,523 due to options issue to our directors during the current fiscal year, including the issue of 8,350,000 options in June 2018;

  

iv)Offset by a decrease in plant relocation costs of $437,800, the plant was relocated in the fourth quarter of the 2017 fiscal year.

 

v)Offset by a decrease in salaries and wages expense of $379,168 due to a reduction in salaries paid to certain management personnel

 

34

 

 

Liquidity and Capital Resources

 

As at November 30, 2018, we had liquidity of approximately $274,096, which was composed entirely of cash. We also had a working capital deficiency of approximately $5,829,414, due primarily to accounts payable, short term loans and convertible loans and accrued interest thereon which remains outstanding as of November 30, 2018. We raised cash proceeds of $3,511,310 from the private placements of shares, a further net proceeds of $450,000 from debt and $3,500,000 from convertible debt. These funds were primarily used on the expansion of the oil facility, expenditures related thereto such as professional fees, marketing costs and notes receivable advanced to third parties.

 

As at August 31, 2018, we had liquidity of approximately $2,640,001, which was composed entirely of cash. We also had a working capital deficiency of approximately $374,567, due to short term loans and accrued interest thereon which remains outstanding as of August 31, 2018. We raised $14,971,808 in private placements, a further net proceeds of $144,359 from long term debt and $250,000 from convertible debt, and $838,846 in net advances from the Chairman of the Board. These funds were primarily used on the relocation and expansion of the oil facility and expenditures related thereto such as professional fees and marketing costs.

 

Subsequent to November 30, 2018, in terms of various subscription agreements entered into with third parties, we raised an additional $2,522,106 in proceeds from private equity issues. In addition to this, we issued an additional $2,000,000 in convertible debt to an investor.

 

We continue to work on several other financing options to secure additional financing on reasonable terms. However, should we not be able to secure such funding our liquidity may not be sufficient to fund our operations, debt obligations and the capital needed to complete development of our Extraction Technology.

 

We have not paid any dividends on our common shares. We have no present intention of paying dividends on our common shares as we anticipate that all available funds will be reinvested to finance the growth of our business.

 

In addition to commitments otherwise reported in this MD&A, our contractual obligations as at November 30, 2018, include:

 

  Contractual Obligations 

Total

($ millions)

  

Up to 1 Year

($ millions)

  

2 – 5 Years

($ millions)

  

After 5 Years

($ millions)

 
  Convertible Debt[1]   4.36    4.36    -    - 
  Debt[2]   1.79    1.29    0.5    - 
  Total Contractual Obligations   6.15    5.65    0.5    - 

 

[1]Amount includes estimated interest payments. The recorded amount as at November 30, 2018 was approximately $3.45 million.
[2]Amount includes estimated interest payments. The recorded amount as at November 30, 2018 was approximately $1.64 million.

 

Off-Balance Sheet Arrangements

 

To the best of management’s knowledge, there are no off-balance sheet arrangements that have, or are reasonably likely to have, a current or future effect on the results of operations or financial condition of the Company.

 

Significant Accounting Policies and Critical Accounting Estimates

 

The following is a summary of new standards, amendments and interpretations that are effective for annual periods beginning on or after January 1, 2017:

 

a)       IAS 7, Statement of Cash Flows (“IAS 7”) – amendments

 

The amendments to IAS 7 require additional disclosure of changes in liabilities arising from financing activities.

 

b)       IAS 12, Income Taxes (“IAS 12”) - amendments

 

The amendments to IAS 12 clarify the recognition of deferred tax assets for unrealized losses.

 

35

 

 

The application of the above amendments did not have any material impact on the consolidated financial statements presented.

 

The following is a summary of new standards, amendments and interpretations that have been issued but not yet adopted in these consolidated financial statements:

 

a)       IFRS 9, Financial Instruments (“IFRS 9”)

 

IFRS 9 uses a single approach to determine whether a financial asset is measured at amortized cost or fair value, replacing the multiple classification options in IAS 39. The approach in IFRS 9 is based on how an entity manages its financial impairment methods in IAS 39. IFRS 9 is effective for annual periods beginning on or after January 1, 2018, with earlier adoption permitted. We are currently evaluating the impact of the adoption of the amendments on our financial statements; however, the impact, if any, is not expected to be significant.

 

b)       IFRS 15, Revenue from Contracts with Customers (“IFRS 15”)

 

IFRS 15 establishes a comprehensive framework for determining whether, how much and when revenue is recognized. It replaces existing revenue recognition guidance, including IAS 18 Revenue, IAS 11 Construction Contracts and IFRIC 13 Customer Loyalty Programmes. IFRS 15 is effective for annual periods beginning on or after January 1, 2018, with early adoption permitted.

 

c)       IFRS 16 Leases (IFRS 16”)

 

IFRS 16 provides a single lessee accounting model, requiring lessees to recognize assets and liabilities for all leases unless the lease term is 12 months or less or the underlying asset has a low value. Lessors continue to classify leases as operating or finance, with IFRS 16’s approach to lessor accounting substantially unchanged from its predecessor IAS 17 Leases. IFRS 16 replaces IAS 17 Leases, IFRIC 4 Determining Whether an Arrangement Contains a Lease, SIC -15 Operating Leases – Incentives, and SIC – 27 Evaluating the Substance of Transactions Involving the Legal Form of a Lease. IFRS 16 is effective for annual periods beginning on or after January 1, 2019, with earlier adoption permitted if IFRS 15 Revenue from Contracts with Customers is also applied.

 

d)       IFRS 2 Share-based Payment (“IFRS 2”) – amendments

 

The amendments to IFRS 2 provide clarification and guidance on the treatment of vesting and non-vesting conditions related to cash-settled share-based payment transactions, on share-based payment transactions with a net settlement feature for withholding tax obligations, and on accounting for modification of a share-based payment transaction that changes its classification from cash-settled to equity-settled. The amendments to IFRS 2 are effective for annual periods beginning on or after January 1, 2018, with earlier application permitted.

 

e)       IFRIC 23 – Uncertainty Over Income Tax Treatments (“IFRIC 23”)

 

IFRIC 23 clarifies application of the recognition and measurement requirements in IAS 12 when there is uncertainty over income tax treatments. It is effective for annual periods beginning on or after January 1, 2019 with early adoption permitted.

 

We are currently assessing the impact that these new and amended standards will have on the consolidated financial statements.

 

ITEM 3. PROPERTIES.

 

Our registered office address in Canada is Suite 6000, 1 First Canadian Place, 100 King Street West, Toronto, Ontario M5X 1E2, Canada. Our principal executive offices are located at 15165 Ventura Blvd, #200, Sherman Oaks, California 91403. The monthly base rent is $6,500 for the approximately 1,800 square foot premises and the lease term is five years.

 

Petrobloq’s headquarters are located at 4768 Park Granada, Calabasas, California 91302. The monthly base rent is $3,870 for the 1,800 square foot premises and the lease is for a three-year term.

 

TMC holds a mining and mineral lease, as amended, under the TMC Mineral Lease subleased from Asphalt Ridge, Inc., on the Asphalt Ridge property which is approximately 1,229.82 acres located in Uintah County, Utah and an additional 833.03 acres and 478.91 acres, respectively, held under the SITLA Mineral Leases. We are completing construction of a 20,000 square foot extraction facility based on this leased property that is anticipated to be approximately three acres.

  

36

 

 

A map of the TMC Mineral Lease property is set forth below:

 

 

Figure 1. The Index map showing the location of the PQE Oil oil sands mine in Vernal, Utah, USA. The mine and lease are on, or about Section 31, Township 5S Range 22E, Uintah County, Utah.

 

Source: JT Boyd, 2015.

 

37

 

  

ITEM 4. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT.

 

The following table sets forth as of January 31, 2019, the number and percentage of the outstanding shares of common shares which, according to the information supplied to us, were beneficially owned by: (i) each person who is currently a director; (ii) each executive officer; (iii) all current directors and executive officers as a group; and (iv) each person who, to our knowledge, is the beneficial owner of more than 5% of the outstanding common shares. All shares reflect a 30-for-1 stock split that was effected on May 19, 2017.

 

Name and Address (1)   Number of Shares
Beneficially Owned
    Percentage of Outstanding shares owned (2)  
Aleksandr Blyumkin, Director (Chairman) and Executive Chairman    

5,170,998

(3)     5.3 %
David Sealock, Chief Executive Officer     250,000           *  
Gerald Bailey, Director and President     733,859 (4)     *
Mark Korb, Chief Financial Officer     7,079 (5)     *  
Vladimir Podlipskiy, Chief Technology Officer     266,667 (6)     *
Robert Dennewald, Director     864,058 (7)     *
Travis Schneider, Director     727,548 (8)     *
All executive officers and directors as a group (7 persons)     8,020,209       8.2 %
                 
5% shareholders                
Bay Private Equity, Inc     9,300,000 (9)     8.8 %

  

* Less than 1%

   

(1)The business address for each officer and director listed above is: Petroteq Energy Inc., 15165 Ventura Blvd., #200, Sherman Oaks, California 91403.

 

(2)Based on 97,623,107 common shares outstanding as of January 31, 2019.

 

(3) Is comprised of 3,932,463 common shares held directly, 124,096 common shares held through the Alexander & Polina Blyumkin Trust and 1,114,439 common shares held indirectly through six entities in which Mr. Blyumkin has a controlling interest.

 

(4)Is comprised of 8,859 common shares and options exercisable for 1,475,000 common shares, of which 725,000 are vested and none vest within the next 60 days.

 

(5)Is comprised of 7,079 common shares.

 

(6)Is comprised of 16,667 common shares and options exercisable for 1,000,000 common shares, of which 250,000 are vested and none vest within the next 60 days.

 

(7)Is comprised of 139,058 common shares and options exercisable for 1,475,000 common shares, of which 725,000 are vested and none vest within the next 60 days.

 

(8)Is comprised of 2,548 common shares and options exercisable for 1,475,000 common shares, of which 725,000 are vested and none vest within the next 60 days.

  

(9)Is comprised of 950,000 common shares, warrants exercisable for 750,000 common shares and convertible notes, convertible into 7,600,000 common shares at conversion prices ranging from $0.40 to $1.00 per share. The beneficial owner is Bay Private Equity, Inc whose registered address is 7250 Keele Street, Suite 410, Concord, Ontario L4K 1Z8.

 

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ITEM 5. DIRECTORS AND EXECUTIVE OFFICERS

 

The following table sets forth certain information about our executive officers, key employees and directors as of January 31, 2019.

 

Name   Age   Positions and Offices with the Registrant
         
Aleksandr Blyumkin   47   Executive Chairman and Chairman of the Board of Directors
David Sealock   58   Chief Executive Officer
Mark Korb   51   Chief Financial Officer
Gerald Bailey   77   Director and President
Vladimir Podlipskiy   55   Chief Technology Officer
Robert Dennewald   65   Director
Travis Schneider   45   Director

 

Biographies

 

The following are brief biographies of our officers and directors:

 

Aleksander Blyumkin, Executive Chairman and Chairman of the Board of Directors

 

Mr. Blyumkin has been our Executive Chairman since March 26, 2018 and the Chairman of our Board of Directors of our company and MCW Fuels, Inc. (formerly McWhirter Distributing Co. Inc.) since November 2006. He also has served as our Executive Chairman from December 12, 2012 to July 18, 2017 and as our Chief Executive Officer from July 2017 to March 26, 2018. Mr. Blyumkin has vast experience in the oil and fuel industry. He has owned and managed several ventures in the oil and fuel industry and has developed oil properties in Eastern Europe, Central Asia and, most recently, in the United States. Since 2011, Mr. Blyumkin has been the Chief Executive Officer of Dalex Industries, Inc., a developer and operator of gasoline service stations in California. Mr. Blyumkin studied Economics and International Relations at Odessa State University, Ukraine.

 

We selected Mr. Blyumkin to serve on our board because he vast experience in the oil and fuel industry.

 

David Sealock, Chief Executive Officer

 

Mr. Sealock has served as our Chief Executive Officer since March 26, 2018. From January 2015 until joining our company, Mr. Sealock served as President of Autus Ventures, Inc. where he established equity financing processes for startup and intermediate oil and gas companies and managed strategic planning and portfolio optimization. Prior to that, from January 2017 until August 2017, he was Vice President of Research & Development at Petroleum Technology Alliance Canada (PTAC), a Canadian hydrocarbon industry association that serves as a neutral non-profit facilitator of collaborative R&D and technology development. There he managed the coordination and services to facilitate the implementation of specific methane related projects. From August 2014 until December 2015, Mr. Sealock served as President and Chief Operating Officer of Sulvaris. Inc. During his tenure at Sulvaris, he collaborated to deliver equity financing and JV financing to recommence project construction. From 2008 to 2014, Mr. Sealock was the Executive Vice President of Sunshine Oilsands, Ltd., and was promoted to President and Chief Executive Officer (Interim) from 2013 to 2014, where he managed daily operations for engineering, construction, technology, operations, regulatory, human resources, investor relations, health, safety & environment, marketing, supply chain management, IT & systems, and corporate governance. From 2007-2008 he was Vice President of MegaWest Energy Corp. (now Gravis Energy) and from 2006-2007 he was Senior Manager of Total E&P (formerly Deer Creek Energy, Ltd.), where he was charged with leading a large-scale business & digital transformation to integrate Deer Creek Energy’s technology infrastructure into Total’s enterprise-wide global infrastructure. Mr. Sealock holds a Bachelor Degree, Business Management and is a Registered Engineering Technologist with ASET.

  

Mark Korb, Chief Financial Officer

 

Mark Korb has served as our Chief Financial Officer since August 2014. Mr. Korb has over 20-years’ experience with high-growth companies and experience taking startup operations to the next level. Since July 2011, First South Africa Management, a company for which Mr. Korb has served as the Chief Financial Officer since January 2010 has been providing consulting services to us, including the financial expertise required of public companies. First South Africa Management provides financial management and strategic management services to various companies.

 

From 2007 to 2009, Mr. Korb was the group chief financial officer and director of Foodcorp (Proprietary) Limited (“Foodcorp”), a multimillion dollar consumer goods company based in South Africa. In his role as chief financial officer, Mr. Korb delivered operational and strategic leadership for the full group financial function during a period of change including mergers, acquisitions and organic growth. As a board director he cultivated relationships with shareholders, bond holders, financial institutions, rating agencies, and auditors. Mr. Korb was also responsible for leading the group IT strategy and implementation and supervised 16 direct reports including 10 divisional financial directors. From 2001 to 2007 Mr. Korb was the group Chief Financial Officer of First Lifestyle, initially a publicly traded company on the Johannesburg Stock Exchange in South Africa which was then purchased by management which included Mr. Korb. He anchored the full group financial function with responsibility for mergers and acquisitions activity, successfully leading the process whereby the company was sold to Foodcorp mentioned above. Upon completion of the merger, Mr. Korb was appointed as the group Chief Financial Officer of Foodcorp. Mr. Korb is also the Chief Financial Officer to several other companies including, Icagen, Inc., a Delaware corporation engaged in pharmaceutical industry.

 

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Gerald Bailey, President and Director

 

Dr. Bailey has over 50 years of experience in the international petroleum industry in all aspects, both upstream and downstream with specific Middle East skills and U.S. onshore/offshore sectors.  Dr. Bailey currently serves as our President, a position he has held since July 2017 when he resigned as our Chief Executive Officer. He previously served as our Chief Executive Officer from 2014 until July 2017 and has been a member of our Board of Directors since 2011. Dr. Bailey is currently the Chairman of Bailey Petroleum, LLC, a consulting firm for major oil and gas exploration/development corporations, a position he has held since 1997. In addition, Dr. Bailey is Chief Operating Officer of Indoklanicsa, Nicaragua (since 2012), and Vice Chairman, Trinity Energy Group, Inc. (since 2012) Dr. Bailey is retired from Exxon, lastly as President, Arabian Gulf.  During his Exxon career, he also served as the Assistant General Manager, Administration & Commercial, Abu Dhabi Onshore Oil Company; Operations Manager, Qatar General Petroleum Corp., Dukhan Operations and the Operations Manager, Qatar General Petroleum Corp., Umm Said Operations.  He was also the Operations Superintendent, Exxon Lago Oil, Aruba and has spent time in Libya as Operations Superintendent for Esso Standard, Libya, Brega, with experience in LNG and oil field production.  His earlier career included service with Texaco where he gained skills in oil additives and petrochemicals manufacturing.

 

Dr. Bailey holds a BS Degree in Chemical Engineering from the University of Houston, an MS Degree in Chemical Engineering from the New Jersey Institute of Technology, Newark, New Jersey, a PhD Degree from Columbia Pacific University, San Rafael, California and is a graduate of Engineering Doctoral Studies from Lamar University, Beaumont, TX.  He has written many articles, papers and studies on the oil industry, and has been a keynote speaker of many international industry conferences including the Money Show conference with his address, “The Future of Oil & Gas Developments,” and FreedomFest Conference, “Investing in Oil,” and also has appeared recently on national Chinese television discussing the “World Energy Outlook.” He is a member of the Middle East Policy Council, Society of Petroleum Engineers and the American Institute of Chemical Engineers.

 

We selected Dr. Bailey to serve on our board because he brings a strong business background to our Company and adds significant strategic, business and financial experience. Dr. Bailey’s business background provides him with a broad understanding of the issues facing our Company, the financial markets and the financing opportunities available to us.

 

Vladimir Podlipskiy, Chief Technology Officer

 

Mr. Podlipskiy has served as our Chief Technology Officer since May 2011. He has extensive experience as a researcher in many senior science disciplines, involved in oil extraction technologies, automobile care, household consumer and cosmetic products and research into mold remediation products, all with a focus on the utilization of benign solvents/solutions. Previously, he held research appointments in new product development for EMD Biosciences, Inc., (Merck KgaA, Darnstadt, Germany), and worked as Chief Chemist in Research & Development for Nanotech, Inc., Los Angeles, California, and as Chief Chemist for Premier Chemical, Compton, California. He is a former Premier Chemical Scientist at UCLA’s Department of Chemistry. Mr. Podlipskiy owns patents for innovative fuel additives and car care products and has authored several papers involving fuel re-formulator products and mold remediation. He is currently involved in research and development of new petroleum industry products, systems and technologies.

  

Mr. Podlipskiy is the principal research scientist responsible for the development of Petroteq Energy Inc.’s technologies used in its various oil extraction programs in Utah, and has recently finalized all fabrication/assembly details for the company’s first oil sands extraction plant installed at Asphalt Ridge, Utah. He has worked extensively with a variety of suppliers from the U.S. and Eastern Europe in the planning and design stages of the extraction unit’s systems. He holds a PhD Degree in Bio-Organic Chemistry from the Institute of Bio-Organic Chemistry & Petroleum Chemistry, Kiev, Ukraine, and a Degree in MS-Organic Chemistry from the Department of Chemistry, Kiev State University, Kiev, Ukraine.

 

Robert Dennewald, Director

 

Mr. Dennewald has served as a member of our board since April 2015. He has been the Chairman of Business Federation Luxembourg (FEDIL) since 2006 and is a Vice President of the Luxembourg Chamber of Commerce. He is also a member of our Board of Directors of the Jean-Pierre Pescatore Charity Foundation. He is a director of ING Luxembourg S.A. and of Redline Capital Partners S.A., the president of investment fund EUREFI S.A. and the angel investor of Cleantech Company APATEQ and IT company e-Kenz. In 2006 he initiated, together with four financial partners, a MBO/LBO takeover of the Eurobeton Group. In 2010, through a secondary buy-out, he took a controlling interest in Eurobeton, which is a main supplier of building materials in Luxembourg with its subsidiary Chaux de Contern. Mr. Dennewald obtained a degree in civil engineering at the University of Liège (B).

 

We selected Mr. Dennewald to serve on our board because he brings a strong business background to our Company and adds significant strategic, business and financial experience. Mr. Dennewald’s business background provides him with a broad understanding of the issues facing us, the financial markets and the financing opportunities available to us.

 

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Travis Schneider, Director

 

Mr. Schneider has served as a member of our board since December 2011. He has also served as Manager of Corporate Affairs for AgriMarine Holdings Inc. (“AgriMarine”) from October 2008 to present. AgriMarine was a publicly traded company on the TSXV and later on the Canadian Securities Exchange from 2009 until its acquisition by Dundee Corporation in 2015.

 

We selected Mr. Schneider to serve on our board because he brings a strong business background to our company and adds significant strategic, business and financial experience. Mr. Schneider’s business background provides him with a broad understanding of the issues facing us, the financial markets and the financing opportunities available to us.

 

Family Relationships

 

There are no family relationships between any of our directors or executive officers.

 

ITEM 6. EXECUTIVE COMPENSATION.

 

Executive Compensation

 

The following table sets forth for the two years ended August 31, 2018 and August 31, 2017 the compensation awarded to, paid to, or earned by, our Chief Executive Officer and our other most highly compensated executive officer whose total compensation during such years exceeded $100,000. We refer to these officers as our “named executive officers.” Certain columns were excluded as the information was not applicable.

  

Summary Compensation Table

 

Name and
Principal Position(1)
  Year  Salary
($)
   Bonus
($)
   All Other
Compensation(2)
   Stock Awards
($)
   Option
Awards
($)(7)
   Total
$
 
                            
Aleksander Blyumkin  2018   240,000    -    18,000         -    258,000 
Executive Chairman and former CEO(3)  2017   240,000    -    18,000         -    258,000 
                                  
David Sealock  2018   50,670    -    -         229,060    279,730 
Chief Executive Officer  2017   -    -    -         -    - 
                                  
Gerald Bailey(4)  2018   0    -    18,000         1,030,711(5)   1,048,891 
Director, President and former CEO  2017   100,000    -    18,000              118,000 
                                  
Mark Korb  2018   90,000    -    -         -    90,000 
Chief Financial Officer  2017   90,000    -    -         -    90,000 
                                  
Vladimir Podlipsky  2018   38,879    -    -         229,060(6)   267,939 
Chief Technology Officer  2017   -    -         74,380(6)   -    74,380 

  

(1)The business address for each officer listed above is: Petroteq Energy Inc., 15165 Ventura Blvd., #200, Sherman Oaks, California 91403.

 

(2)Mr. Blyumkin and Dr. Bailey have each earned $18,000 of director’s fees for the financial years ended August 31, 2018 and 2017. These fees have been accrued but have not been paid by us.

 

(3)Mr. Blyumkin was appointed as our Chief Executive Officer on July 26, 2017, replacing Gerald Bailey.

 

(4)Gerald Bailey resigned as Chief Executive Officer on July 26, 2017. He currently serves as our President and maintains a position on our Board of Directors. Mr. Blyumkin assumed the office of Chief Executive Officer upon Mr. Bailey’s resignation.

  

(5)On November 30, 2017, Gerald Bailey was awarded ten year options exercisable for 475,000 shares of common stock at an exercise price of CDN2,27 per share. These options are immediately exercisable. On June 6, 2018, Gerald Bailey was awarded ten year options exercisable over 1,000,000 shares of Common stock at an exercise price of CDN$1.00 per share, these options vest annually over a four year period.

 

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(6)On June 6, 2018, Mr. Podlipsky was awarded ten year options exercisable for 1,000,000 shares of common stock at an exercise price of CDN$1.00 per share, these options vest annually over a four year period. In 2017, Mr. Podlipsky was awarded 16,667 shares valued at $74,380 on the date of issue as compensation based on the success of the Extraction Technology.

 

(7)

The options issued to directors and officers on November 30, 2017 were valued at grant date using a Black Scholes valuation model. The assumptions used in the valuation were as follows: Weighted average exercise price of CDN$2.27, exercise price CDN$2.27, term of option: 10 years, risk free interest rate of 1.81% and computed volatility of the underlying stock of 127% and expected dividend yield of 0%.

 

The options issued to directors and officers on June 3, 2018 were valued at grant date using a Black Scholes valuation model. The assumptions used in the valuation were as follows: Weighted average exercise price of CDN$1.00, exercise price CDN$1.00, term of option: 10 years, risk free interest rate of 2.16% and computed volatility of the underlying stock of 125% and expected dividend yield of 0%.

  

Outstanding Equity Awards at Fiscal Year-End

 

The table below reflects all outstanding equity awards made to each of the named executive officers that are outstanding at August 31, 2018.

 

Name   Number of securities underlying unexercised options (#) exercisable     Number of securities underlying unexercised options (#) unexercisable     Option
exercise
price
    Option expiration date
                       
Aleksander Blyumkin,
Executive Chairman and former CEO(1)
    33,334       -     US $ 4.80     12/31/2018
                             
Gerald Bailey,     475,000       -     CDN $ 2.27     11/30/2027
Director, President and former CEO     250,000       750,000     CDN $ 1.00     6/6/2028
                             
Vladimir Podlipsky,                            
Chief Technology Officer     250,000       750,000     CDN $ 1.00     6/6/2028
                             

David Sealock

Chief Executive Officer

    250,000       750,000     CDN $ 1.00     6/6/2028

 

(1)These common share purchase warrants are required by the TSXV to be included by us when calculating available room under our 2019 Option Plan. Mr. Blyumkin is the registered and beneficial holder of common share purchase warrants exercisable for 16,667 common shares, and he indirectly controls common share purchase warrants exercisable for 16,667 common shares through the Alex and Polina Blyumkin Family Trust, none of which are included in the chart above. These warrants have subsequently expired.

 

Narrative to Compensation Tables

 

Overview

 

During the financial years ended August 31, 2018 and 2017, our executive compensation program was administered by our Board of Directors. Our executive compensation program has the objective of attracting and retaining a qualified and cohesive group of executives, motivating team performance and aligning the interests of executives with the interests of our shareholders through a package of compensation that is simple and easy to understand and implement. Compensation under the program was designed to achieve both current and our long-term goals of and to optimize returns to shareholders. In addition, in order to further align the interests of executives with the interests of our shareholders, we have implemented share ownership incentives through incentive stock options. Our overall compensation objectives are in line with its peer group of oil sands technology companies with opportunities to participate in equity.

  

In determining the total compensation of any member of senior management, our directors consider all elements of compensation in total rather than one element in isolation. Our directors also examine the competitive positioning of total compensation and the mix of fixed, incentive and share-based compensation.

 

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Base Salary

 

While there is no official set of benchmarks that we rely on and there is no a defined list of issuers that we use as a benchmark, we make ourselves aware of, and are cognizant of, how comparable issuers in our business compensate their executives. Our peer group in connection with salary compensation consists of a sampling of other oil sands technology companies both private and public. The Executive Chairman and Chief Executive Officer review and update our directors on the peer group and other informal channels and compares the salaries offered by us against those of the peer group generally to ensure our salary compensation is within the range of expected annual base salary for the group.

 

Bonus Framework

 

While our directors believe that a well-balanced executive compensation program must simultaneously motivate and reward participants to deliver financial results while maintaining focus on long-term goals that track financial progress and value creation, during the fiscal years ended August 31, 2018 and 2017, we did not have in place an annual team bonus or discretionary individual bonus plan and we did not pay any bonuses.

 

Group Benefits

 

We do not offer a group benefits plan of any kind.

 

Perquisites and Personal Benefits

 

While we reimburse our executive officers for expenses incurred in the course of performing their duties as executive officers of our company, we did not provide any compensation that would be considered a perquisite or personal benefit to executive officers.

 

Equity Compensation

 

2019 Option Plan

 

Incentive stock options are currently granted under the 2019 Option Plan, a fixed number stock option plan approved by shareholders on November 23, 2018, which amended and replaced our 2018 Option Plan. Pursuant to the 2019 Option Plan our Board of Directors may from time to time, in its discretion and in accordance with the TSXV requirements, grant to directors, officers and employees, as well as management company employees and consultants (as such terms are defined in Policy 4.4 as amended from time to time), non-transferable options to purchase common shares, provided that the number of common shares reserved for issuance will not exceed 19,524,621, exercisable for a period of up to ten (10) years from the date of the grant. The number of common shares reserved for issuance to any individual director or officer of our company will not exceed 5% of the issued and outstanding common shares (2% in the case of optionees providing investor relations services to us) unless disinterested shareholder approval is obtained. The exercise price of any option granted pursuant to the 2019 Option Plan shall be determined by our Board of Directors when granted, but shall not be less than the Discounted Market Price (as such term is defined in Policy 4.4 as amended from time to time). Options granted pursuant to the 2019 Option Plan are non-assignable, except by means of a will or pursuant to the laws of descent and distribution.

 

The options may be exercised no later than 12 months following the date the optionee ceases to be a director, officer or consultant of our company, subject to the expiry date of such option. However, if the employment of an employee or consultant is terminated for cause no option held by such optionee may be exercised following the date upon which termination occurred.

 

Employment Agreements

 

We do not have any written employment agreements with any of our executive officers or other employees other than David Sealock, our Chief Executive Officer. On March 26, 2018, we entered into an employment agreement with David Sealock to serve as our Chief Executive Officer. For his services, Mr. Sealock is to receive a salary of $120,000 per annum. The employment agreement term continues indefinitely until terminated in accordance with its provisions. The employment agreement also includes confidentiality obligations, inventions assignments by Mr. Sealock as well as change in control, non-solicitation and post-termination restrictions regarding corporate opportunities.

  

We may terminate the employment agreement and Mr. Sealock’s employment for Just Cause (as defined in the employment agreement) with 30 days’ notice to Mr. Sealock and without payment to him of any compensation or severance in lieu of notice past the 30 day notice period. Upon termination of employment for Just Cause, Mr. Sealock would only be entitled to any base salary due and owing up to the date of termination, all expenses properly incurred up to the date of termination in the carrying out of his duties and any accrued but unused vacation pay due and outstanding. We may also terminate the employment agreement and Mr. Sealock’s employment without Just Cause upon 15 business days’ notice to Mr. Sealock. Upon termination of employment without Just Cause, Mr. Sealock would receive any base salary due and owing up to the date of termination, a lump sum amount equal to $12,000, all expenses properly incurred up to the date of termination in the carrying out of his duties and any accrued but unused vacation pay due and outstanding. Mr. Sealock may terminate the employment agreement for Good Reason (as defined in the employment agreement) in the event of a Change of Control (as defined in the employment agreement) upon 15 business days’ notice to us. Upon termination of employment for Just Cause (as defined in the employment agreement), Mr. Sealock would be entitled to any base salary due and owing up to the date of termination, all expenses properly incurred up to the date of termination in the carrying out of his duties and any accrued but unused vacation pay due and outstanding.

 

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For the purposes of the employment agreement with Mr. Sealock, the term “Just Cause” is defined as: (i) any matter that would constitute lawful just cause for dismissal from employment at common law; (ii) conviction of the executive of a criminal offence involving dishonesty or fraud or which is likely to injure our business or reputation; (iii) misappropriation of any of our property or assets; (iv) any breach by the executive of any term of his employment or the employment agreement which has not been cured within ten days of notice to the executive of such breach; (v) any information, reports, documents or certificates being intentionally furnished by the executive to our Board or any committee thereof which the executive knows to be either false or misleading either because they include or fail to include material facts; or (vi) failure to perform his duties in a diligent and reasonable manner.

 

The term “Good Reason” (which only applies to Change of Control event) is defined as: (i) a significant change (other than a change that is clearly consistent with a promotion) in his position or duties, responsibilities, title or office held by him with us; (ii) a material reduction of his salary, benefits or any other form of remuneration or any change in the basis upon which the executive’s salary, benefits or any other form of remuneration payable by us is determined or any failure by us to increase his salary, benefits or any other forms of remuneration payable by us in a manner consistent with practices in effect from time to time with respect to our senior executives, whichever is more favorable to him; (iii) any failure by us to continue in effect any benefit, bonus, profit sharing, incentive, remuneration or compensation plan, stock ownership or purchase plan, pension plan or retirement plan in which Mr. Sealock is participating or entitled to participate from time to time, or our taking any action or failing to take any action that would adversely affect his participation in or reduce his rights or benefits under or pursuant to any such plan, or our failing to increase or improve such rights or benefits on a basis consistent with practices with respect to our senior executives, whichever is more favorable to him; (iv) any breach by us of any material provision of the employment agreement; (v) the failure by us to obtain, in a form satisfactory to Mr. Sealock, an effective assumption of our obligations under the employment agreement by any successor to us; or (vi) the good faith determination by Mr. Sealock that we have requested he misrepresent information to external parties, vendors, shareholders or any other party.

 

The term “Change of Control” is defined as: (i) the sale to a person or acquisition by a person not affiliated with us of net assets from us having a value greater than 50% of the fair market value of our net assets determined on a consolidated basis prior to such sale; (ii) any change in the holding, direct or indirect, of our shares by a person not affiliated with us as a result of which such person, or a group of persons, or persons acting in concert, or persons associated or affiliated with any such person or group, are in a position to exercise effective control over us; (iii) any reconstruction, reorganization, recapitalization, consolidation, amalgamation, arrangement, merger, transfer, sale or other transaction involving us where all of our shareholders immediately prior to such transaction hold greater than 50% of the shares of the Corporation or of the continuing corporation following completion of the transaction; or (iv) any event or transaction which our Board, in its discretion, deems to be a Change of Control.

 

Pursuant to a Technology Transfer Agreement, effective November 7, 2011, whereby we acquired from Vladimir Podlipskiy certain intellectual property rights relating to extracting bitumen from oil sands (the “Acquired Technology”), we also agreed to employ Mr. Podlipskiy to oversee and operate the Acquired Technology with the compensation of $120,000.00 per year for as long as the Acquired Technology is utilized by us. In consideration for the Acquired Technology, we issued to Mr. Podlipskiy’s designee 100,000 shares of our common shares and agreed to issue an additional 1,900,000 shares of our common shares on the date when our extraction facility at the TMC Mineral Lease in Vernal, Utah is assembled and tested. We further agreed to pay Mr. Podlipskiy upon the construction of a second plant utilizing the Acquired Technology and any plants thereafter using the Acquired Technology a royalty fee of 2% of gross sales if the price of heavy oil is below $60.00 per barrel; 3% of gross sales if the price of heavy oil is between $60.00 and $69.99 per barrel; 3.5% of gross sales if the price of heavy oil is between $70.00 and $79.99 and 4% of gross sales if the price of heavy oil is greater than $80.00.

  

Director Compensation

 

The following table sets forth information for the fiscal year ended August 31, 2018 regarding the compensation of our directors who at August 31, 2018 were not also named executive officers.

 

Name  Fees
Earned or
Paid in Cash
$
   Option
Awards
$(3)
   Other
Compensation
$
   Total
$
 
Robert Dennewald(1)   18,000    1,030,711    -    1,048,711 
Travis Schneider(1)   18,000    1,030,711    -    1,048,711 

  

1. Mr. Schneider and Mr. Dennewald have each earned $18,000 of director’s fees for the financial year ended August 31, 2018. These fees have been accrued but have not been paid by us.

 

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2. On November 30, 2017, Mr. Schneider and Mr. Dennewald, were each awarded ten year options exercisable to purchase 475,000 shares of common stock at an exercise price of CDN2,27 per share. These options are immediately exercisable. On June 6, 2018, Mr. Schneider and Mr. Dennewald were each awarded ten-year options exercisable over 1,000,000 shares of Common stock at an exercise price of CDN$1.00 per share, these options vest annually over a four year period.
   
3.

The options issued to directors on November 30, 2017 were valued at grant date using a Black Scholes valuation model. The assumptions used in the valuation were as follows: Weighted average exercise price of CDN$2.27, exercise price CDN$2.27, term of option: 10 years, risk free interest rate of 1.81% and computed volatility of the underlying stock of 127% and expected dividend yield of 0%.

 

The options issued to directors on June 3, 2018 were valued at grant date using a Black Scholes valuation model. The assumptions used in the valuation were as follows: Weighted average exercise price of CDN$1.00, exercise price CDN$1.00, term of option: 10 years, risk free interest rate of 2.16% and computed volatility of the underlying stock of 125% and expected dividend yield of 0%.

 

Compensation Committee Interlocks

 

Not Applicable

 

ITEM 7. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

 

Director Independence and Related Transactions

 

Our Board of Directors is comprised of Aleksander Bluymkin, Gerald Bailey, Robert Dennewald, and Travis Schneider, of which only Messrs. Dennewald and Schneider are deemed to be independent within the meaning of the TSXV Guide and applicable Canadian regulations.

 

The Board of Directors has appointed only one standing committee, the Audit Committee. The Board members comprising our Audit Committee are Alex Blyumkin, Travis S. Schneider and Robert Dennewald, of which only Messrs. Dennewald and Schneider are deemed to be independent within the meaning of the TSXV Guide and applicable Canadian regulations.

 

The Audit Committee meets at least two times per year.

 

Certain Relationships and Related Transactions

 

During the years ended August 31, 2018 and 2017, we received additional advances of $nil and $421,250 from various private companies controlled by the Chairman of our Board of Directors. On May 18, 2017, we entered into an agreement to settle a portion of the principal and accrued interest of these advances by issuing 586,475 of our common shares to the lenders.

 

On May 18, 2017, we entered into a Securities Purchase Agreement whereby we agreed to convert an aggregate principal debt of $204,000, including interest thereon, owing to the Chairman of the Board or companies controlled by him into 751,681 of common share at a conversion price of $0.353 per share.

 

On May 18, 2017, we entered into a Securities Purchase Agreements whereby it agreed to convert an aggregate principal debt of $115,000, including interest thereon, owing to the Chairman of the Board or companies controlled by him into 325,779 common shares at a conversion price of $0.353 per share.

 

On August 9, 2017, the promissory note of $3,000,000, owing to the Chairman of the Board, including accrued interest thereon up to August 18, 2017 of $215,625, was assigned to three different entities and, in terms of debt conversion agreements entered into on August 9, 2017, was subsequently converted into 14,391,330 common shares at a conversion price of $0.223 per share,

 

As at August 31, 2017, we had received loans of $419,322 from the Chairman of the Board of Directors. These loans were interest free and were repaid prior to August 31, 2018.

 

On May 22, 2018, we entered into a Debt Settlement Agreement whereby we agreed to convert $1,175,424 of advances made to us by the Chairman of the Board into 1,992,244 common shares at a conversion price of $0.59 per share.

 

On September 4, 2018, we entered into a Debt Settlement Agreement whereby we agreed to convert $249,285 of advances made to us by the Chairman of the Board into 336,871 common shares at a conversion price of $0.74 per share.

 

As of August 31, 2017, we owed various private companies controlled by the Chairman of the Board the aggregate sum of $242,250. These loans bore interest at 5% per annum and matured at dates ranging from on demand to September 1, 2020. As of November 30, 2018 and August 31, 2018, all amounts owed to these entities were paid in full.

 

As at November 30, 2018, the Chairman of the Board of Directors owed us $374,728.

 

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ITEM 8. LEGAL PROCEEDINGS.

 

From time to time, we are the subject of litigation arising out of our normal course of operations. While we assess the merits of each lawsuit and defends itself accordingly, we may be required to incur significant expenses or devote significant resources to defend ourselves against such litigation. Accruals are made in instances where it is probable that liabilities may be incurred and where such liabilities can be reasonably estimated. Except as disclosed in this paragraph, there are no governmental, legal or arbitration proceedings (including any such proceedings which are pending or threatened of which we are aware), which may have, or have had during the 12 months prior to the date of this registration statement, a significant effect on our and/or our financial position or profitability. Although it is possible that liabilities may be incurred in instances for which no accruals have been made, management has no reason to believe that the ultimate outcome of these matters would have a significant impact on our consolidated financial position.

 

ITEM 9. MARKET PRICE OF, AND DIVIDENDS ON THE REGISTRANT’S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS.

 

Quotations for our common shares are included in the Toronto Ventures Exchange Market TSQV under the symbol “PQE.V”.

 

At January 31, 2019, there were approximately 232 holders of record of our common shares.

 

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Since inception, no dividends have been paid on the common shares. We intend to retain any earnings for use in its business activities, so it is not expected that any dividends on the common shares will be declared and paid in the foreseeable future.

 

Securities Authorized for Issuance under Equity Incentive Plans.    At August 31, 2018, we were authorized to issue options covering up to 16,969,601 common shares.

  

The following table sets forth information about the securities authorized for issuance under our equity compensation plans for the fiscal year ended August 31, 2018.

 

   Number of securities to be issued upon exercise of outstanding options   Weighted
average
exercise price
of outstanding
options
   Number of securities remaining for future issuance under equity compensation plans 
             
Equity Compensation plans approved by the stockholders   9,858,333   CDN$1.22    

4,950,000

 
                
    9,858,333   CDN$1.22    

4,950,000

 

  

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ITEM 10. RECENT SALES OF UNREGISTERED SECURITIES.

 

As at February 5, 2019, there were 97,476,049 common shares issued and outstanding, which are listed for trading on the TSXV, warrants to purchase 20,714,715 common shares were outstanding and stock options to purchase 9,858,333 common shares were outstanding under the 2018 Option Plan (or its predecessors plans) and 8,610,416 shares reserved for other issuances. See Item 6.B “Compensation – Stock Plan” for additional information regarding the 2018 Option Plan (or its predecessors plans).

 

The number of outstanding common shares at the end of Fiscal 2018 (August 31, 2018), Fiscal 2017 (August 31, 2017), and Fiscal 2016 (August 31, 2016) were as follows: 85,163,631 shares: 54,220,699 shares, and 6,723,167 shares, respectively. There were 54,220,699 common shares outstanding at the beginning of Fiscal 2018 and 85,163,631 common shares outstanding at the end of Fiscal 2018. There were 6,723,167 common shares outstanding at the beginning of Fiscal 2017 and 54,220,699 common shares outstanding at the end of Fiscal 2017. There were 2,020,765 common shares outstanding at the beginning of Fiscal 2016 and 6,723,167 common shares outstanding at the end of Fiscal 2016.

 

As at the end of Fiscal 2018, 83,331 stock options were outstanding under the 2017 Stock Plan (or its predecessors plans).

 

The following sets forth information regarding our share capital issuances during the last three years. We have not issued any preferred shares. None of these transactions involved any underwriters, underwriting discounts or commissions, or any public offering. On May 5, 2017, we consolidated our common shares on 1-for-30 basis. The number of common shares issued and outstanding set forth below have been retroactively adjusted for this consolidation.

  

1. On January 19, 2016, we issued 190,971 common shares to Mr. Blyumkin in consideration for him personally guaranteeing three loans to us in an aggregate amount of $16,500,000.
2. On February 1, 2016, we issued 3,745 common shares in satisfaction of $35,000 of indebtedness owed to Mark Korb.
3. On February 19, 2016, we issued 31,124 common shares to Robert Dennewald for gross proceeds of $100,000.
4. On February 24, 2016, we issued 62,080 common shares in satisfaction of $160,000 of indebtedness owed to two arm’s length service providers.
5. On February 25, 2016, we issued 200,754 common shares to a lender in consideration for agreeing to extend the maturity of a $3,500,000 loan.
6. On March 7, 2016, we issued 12,976 common shares pursuant to a private offering for gross proceeds of $35,000.
7. On March 23, 2016, we issued 882,454 common shares in satisfaction of $2,447,478 of indebtedness owed pursuant to two arm’s length loans.
8. On March 24, 2016, we issued 85,160 common shares in satisfaction of $236,411 of indebtedness owed pursuant to two loans with Mr. Blyumkin.
9. On March 28, 2016, we issued 9,268 common shares pursuant to a private offering for gross proceeds of $25,000.
10. On April 1, 2016, we issued 31,386 common shares pursuant to a private offering for gross proceeds of $85,000.
11. On April 4, 2016, we issued 22,524 common shares pursuant to a private offering for gross proceeds of $61,000.
12. On April 5, 2016, we issued 33,333 common shares pursuant to a private offering for gross proceeds of $110,000.
13. On April 13, 2016, we issued 34,659 common shares in satisfaction of $129,298 of indebtedness owed to an arm’s length service provider.
14. On April 25, 2016, we issued 22,991 common shares in satisfaction of $55,556 of indebtedness owed pursuant to pursuant to a secured note issued pursuant to a securities purchase agreement dated December 15, 2016.
15. On April 25, 2016, we issued 43,847 common shares in satisfaction of $150,000 of indebtedness owed to an arm’s length service provider.
16. On May 11, 2016, we issued 36,666 common shares in satisfaction of $185,000 of indebtedness owed to two arm’s length service providers.
17. On May 16, 2016, we issued 7,560 common shares in satisfaction of $20,000 of indebtedness owed to an arm’s length service provider.
18. On May 25, 2016, we issued 10,000 common shares in satisfaction of $90,000 of indebtedness owed to an arm’s length service provider.
19. On May 30, 2016 and June 8, 2016, we issued 666,666 common shares in satisfaction of $2,500,000 of indebtedness owed to an arm’s length lender pursuant to a promissory note dated September 8, 2015.
20. On June 3, 2016, we issued 23,809 common shares pursuant to a private offering for gross proceeds of $75,000.
21. On June 10, 2016, we issued 64,411 common shares in satisfaction of CDN$217,289 of indebtedness owed to two arm’s length service providers.
22. On June 24, 2016, we issued 16,666 common shares pursuant to a private offering for gross proceeds of $50,000.

 

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23. On August 19, 2016, we issued 1,989,943 common shares (and warrants to purchase 66,666 common shares at $7.50 per share for three years) pursuant to our acquisition of 57.3% of all issued and outstanding shares of Accord.
24. On August 23, 2016, we issued 123,897 common shares in satisfaction of $396,748 of indebtedness owed pursuant to two loans ($130,602) with Mr. Blyumkin and one ($266,146) with an arm’s length lender.
25. On September 15, 2016, we issued 31,776 common shares in satisfaction of $110,000 of indebtedness owed to two arm’s length service providers.
26. On October 21, 2016, we issued 14,439 common shares (and warrants to purchase 14,439 common shares at CDN$4.725 per share until April 8, 2021) pursuant to the conversion of $50,000 of a note originally issued on April 8, 2016.
27. On November 8, 2016, we issued 43,317 common shares (and warrants to purchase 43,317 common shares at CDN$4.725 per share until April 8, 2021) pursuant to the conversion of $150,000 of a note originally issued on April 8, 2016.
28. On November 17, 2016, we issued 12,491 common shares pursuant to a private offering for gross proceeds of $65,000.
29. On November 17, 2016, we issued 24,697 common shares in satisfaction of $157,205 of indebtedness owed to three arm’s length service providers and lenders.
30. On January 17, 2017, we issued 16,666 common shares to Vladimir Podlipsky, our Chief Technology Officer, in pursuant to Restricted Stock Agreement dated April 13, 2012 executed pursuant to a Technology Transfer Agreement, wherein we agreed to issue Mr. Podlipsky 16,666 common shares upon the successful installation and testing of our oil sands extraction technology to our satisfaction.
31. On February 3, 2017, we issued 63,332 common shares in satisfaction of CDN$135,373 of indebtedness owed to an arm’s length service provider.
32. On February 24, 2017, we issued 669,760 common shares to an arm’s length lender pursuant to the conversion of $2,300,000 of a $3,500,000 loan contemplated in a loan agreement dated February 9, 2015, as amended.
33. On April 21, 2017, we issued 33,333 common shares in satisfaction of $37,500 of indebtedness owed to an arm’s length service provider.
34. On April 21, 2017, we issued 336,341 common shares pursuant to a private offering for gross proceeds of $441,464 (including $315,000 from Mr. Blyumkin).
35. On April 24, 2017, we issued 24,027 common shares pursuant to a private offering for gross proceeds of $35,000.
36. On June 12, 2017, we issued 83,333 common shares to Recruiter.com, Inc. in exchange for a 25% equity interest in the joint venture entity formed pursuant to a joint venture agreement made as of November 11, 2016, between us, Recruiter.com, Inc. and Advance Media Solutions-Venture Company.
37. On July 10, 2017, we issued 220,588 common shares pursuant to a private offering for gross proceeds of $75,000.
38. On July 11, 2017, we issued 31,083,281 common shares in satisfaction of $12,189,956 of indebtedness owed to several lenders (including 1,746,824 common shares in satisfaction of $620,277 of indebtedness owed to Mr. Blyumkin).
39. On August 10, 2017, we issued 58,593 common shares to Robert Dennewald for gross proceeds of $15,000.
40. On August 14, 2017, we issued 60,000 common shares in satisfaction of $50,000 of indebtedness owed to an arm’s length service provider.
41. On August 22, 2017, we issued 14,391,330 common shares in satisfaction of $3,215,625 of indebtedness owed to three arm’s length lenders pursuant to the assignment of a promissory note dated March 18, 2016.
42. On August 23, 2017, we issued 320,000 common shares in satisfaction of $99,840 of indebtedness owed to an arm’s length service provider.
43. On August 30, 2017, we issued 42,000 common shares pursuant to a private offering for gross proceeds of $10,080.
44. On August 31, 2017, we issued a convertible secured note in the principal amount of $565,000 bearing interest at a rate of 5% per annum, conversion price of $0.20 per share, maturing October 31, 2018 which note is convertible into units comprised of one common share and one warrant to purchase common share at an exercise price of $0.315 per share. From December 19, 2017 to May 22, 2018, a total of $508,500 in principal was converted into 1,753,447 units and from March 16, 2018 until July 11, 2018 a total of 1,753,447 warrants were exercised to purchase 1,753,447 common shares
45. On September 27, 2017, we issued 334,615 common shares pursuant to a private offering for gross proceeds of $87,000.
46. On October 20, 2017, we issued 100,000 common shares pursuant to a private offering for gross proceeds of $26,000.
47.

On November 8, 2017, we issued 754,461 common shares pursuant to a private offering for gross proceeds of $199,180.

48. On December 19, 2017 and January 22, 2018, we issued an aggregate of 517,241 common shares (and warrants to purchase 517,241 common shares at $0.315 per share until August 31, 2022) pursuant to the conversion of $150,000 of a note originally issued on August 31, 2017.
49. On January 10, 2018 and January 22, 2018, we issued an aggregate of 517,241 common shares (and warrants to purchase 517,241 common shares at $0.315 per share until August 31, 2022) pursuant to the conversion of $150,000 of a note originally issued on August 31, 2017.
50. On January 25, 2018, we issued 253,802 common shares pursuant to a private offering for gross proceeds of $180,200.
51. On January 29, 2018, we issued 870,369 common shares pursuant to a private offering for gross proceeds of $922,591.
52. On February 9, 2018, we issued an aggregate of 517,241 common shares (and warrants to purchase 517,241 common shares at $0.315 per share until August 31, 2022) pursuant to the conversion of $150,000 of a note originally issued on August 31, 2017.

 

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53. On March 9, 2018, we issued 222,203 common shares (and warrants to purchase 114,678 common shares at $1.50 per share for 24 months) pursuant to a private offering for gross proceeds of $225,000.
54.

On March 13, 2018, we issued 932,893 common shares (592,385 common shares in satisfaction of $613,750 of indebtedness and 340,508 common shares in satisfaction of CDN$381,370 of indebtedness) to five arm’s length service providers.

55. On March 16, 2018, we issued 250,000 common shares pursuant to the partial exercise, at $0.315 per share, of a warrant issued on December 19, 2017.
56. On April 11, 2018, we issued 250,000 common shares pursuant to the partial exercise, at $0.315 per share, of a warrant issued on December 19, 2017.
57. On April 19, 2018, we issued 500,000 common shares pursuant to the exercise, at $0.315 per share, of a warrant issued on January 10, 2018.
58. On May 8, 2018, we issued 493,242 common shares in satisfaction of CDN $365,000 of indebtedness owed to two arm’s length lenders pursuant to debentures originally issued on October 10, 2014, as amended.
59. On May 8, 2018, we issued 500,000 common shares in satisfaction of $795,000 of indebtedness to an arm’s length service provider.
60. On May 22, 2018, we issued an aggregate of 201,724 common shares (and warrants to purchase 201,724 common shares at $0.315 per share until August 31, 2022) pursuant to the conversion of $58,500 of a note originally issued on August 31, 2017.
61. On May 2, 2018, we issued 6,000,000 common shares (and warrants to purchase 6,000,000 common shares at $0.91 per share for three years) pursuant to a private offering for gross proceeds of $3,600,000.
62. On May 24, 2018, we issued 25,000 common shares in satisfaction of $17,500 of indebtedness owed to an arm’s length service provider.
63. On May 30, 2018, we issued 25,000 common shares in satisfaction of $17,500 of indebtedness owed to an arm’s length service provider.
64. On May 30, 2018, we issued 25,000 common shares to a member of our advisory board pursuant to an advisory board agreement entitling the holder to 100,000 common shares in three installments from May to September.
65. On June 1, 2018, we issued 517,241 common shares pursuant to the exercise, at $0.315 per share, of a warrant issued on February 9, 2018.
66. On June 11, 2018, we issued 4,799,799 common shares pursuant to a private offering for gross proceeds of $2,807,022.
67. On June 14, 2018, we issued 764,740 common shares (and warrants to purchase 329,080 common shares at $1.50 per share for two years) pursuant to a private offering for gross proceeds of $472,200.
68. On June 25, 2018, we issued 1,992,244 common shares to Mr. Blyumkin in satisfaction of $1,175,424 of indebtedness owed to Mr. Blyumkin for reimbursement of company expenses.
69. On June 28, 2018, we issued 292,893 common shares pursuant to a private offering for gross proceeds of $202,100.
70. On July 5, 2018, we issued 25,000 common shares to a consultant pursuant to an independent contractor agreement entitling the holder to 25,000 common shares in three installments at the end of each month commencing in June.
71. On July 11, 2018, we issued 236,206 common shares pursuant to the exercise, at $0.315 per share, of a warrant issued on January 22, 2018 and a warrant issued on May 22, 2018.
72 On July 26, 2018, we issued 2,765,115 common shares (and warrants to purchase 1,637,160 common shares at $1.50 per share for two years) pursuant to a private offering for gross proceeds of $1,832,600.
73. On July 31, 2018, we issued 50,000 common shares to a member of our advisory board pursuant to an advisory board agreement entitling the holder to 100,000 common shares in three installments from May to September.
74. On July 31, 2018, we issued 25,000 common shares to a consultant pursuant to an independent contractor agreement entitling the holder to 25,000 common shares in three installments at the end of each month commencing in June.
75. On August 2, 2018, we issued 287,500 common shares in satisfaction of $230,000 of indebtedness owed to an arm’s length service provider.
76. On August 28, 2018, we issued 5,922,162 common shares (and warrants to purchase 1,623,676 common shares at exercise prices ranging from US$0.94 to US$1.50 per share for two years) pursuant to a private offering for gross proceeds of $4,417,916.
77. On September 1, 2018, we issued 25,000 common shares to a consultant pursuant to an independent contractor agreement entitling the holder to 25,000 common shares in three installments at the end of each month commencing in June.
78. On September 4, 2018, we issued 542,065 common shares in satisfaction of $411,285 of indebtedness owed to two arm’s length service providers (205,194 shares for $162,000) and Mr. Blyumkin (336,871 for $249,285).
79. On September 4, 2018, we issued a convertible unsecured debenture for principal amount of $250,000 and warrants to purchase 287,356 common shares at an exercise price of $0.87 per share for one year, to an arm’s length lender. The debenture has a term of one year and bears interest at a rate of 10% per annum and at the option of the holder the principal amount of the debenture is convertible at $0.87 per share into up to 287,356 common shares.
80. On September 6, 2018, we issued 1,234,567 common shares (and warrants to purchase 925,925 common shares at an exercise price of $1.01 per share for two years) pursuant to a private offering for gross proceeds of $1,000,000.
81. On September 17, 2018, we issued secured convertible debentures with a face value of $3,300,000 (including an original issue discount of $300,000) to a third party investor for gross proceeds of $3,000,000, the convertible debenture bears interest at 10% per annum and has a maturity date, twelve months from the date of issuance. In conjunction with the issuance we issued 950,000 shares of common stock to the investor and a further 300,000 shares to a third party broker. We also issued 1 year warrants exercisable over 750,000 shares of common stock at an exercise price of $1.10 per share.

 

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82. On September 11, 2018, we issued 316,223 common shares to settle CAD$335,196 of debt owed to two convertible note holders.
83. On September 28, 2018, we issued 110,206 common shares to settle $110,516 owed to certain service providers.
84. On September 30, 2018 we issued 25,000 common shares to a consultant pursuant to an independent contractor agreement entitling the holder to 25,000 common shares in three installments at the end of each month commencing in June.
85. On October 11, 2018, we issued 833,269 common shares and warrants exercisable for the purchase of 520,408 common shares at exercise prices ranging from $1.35 to $1.50 per share to private investors for gross proceeds of $816,605.
86. On October 12, 2018, we entered into an agreement with Calvary Fund I LP whereby the we issued 250 one year units for proceeds of $250,000, each unit consisting of a $1,000 principal convertible unsecured debenture, bearing interest at 10% per annum and convertible into common shares at $0.86 per share, and a warrant exercisable for 1,162 common shares at an exercise price of $0.86 per share, for a total of 290,500 warrants.
87. On October 15, 2018, we entered into an agreement with SBI Investments LLC whereby we issued 250 one year units for proceeds of $250,000, each debenture consisting of a $1,000 principal convertible unsecured debenture, bearing interest at 10% per annum and convertible into common shares at $0.86 per share, and a warrant exercisable for 1,162 shares of common stock at an exercise price of $0.86 per share, for a total of 290,500 warrants.
88. On November 7, 2018, we issued 320,408 common shares and warrants exercisable for the purchase of 320,408 common shares at exercise prices ranging from $0.61 to $0.66 per share, to private investors for gross proceeds of $169,000.
89. On November 8, 2018, we issued 918,355 common share purchase warrants to various investors as settlement of expenses incurred by the Company.  Each common share purchase warrants entitles the holder to purchase one common share of the Company at a price of $1.01 per share and expires on November 8, 2020.
90. On November 8, 2018, we issued 28,880 common shares to a director as settlement of $23,393 of expenses incurred by him.
91. On December 3, 2018 Alpha Capital Anstalt converted the remaining debt outstanding to them of $56,500 plus interest of $13,478 into 145,788 of our common shares.
92. On December 5, 2018, we entered into settlement agreements with certain service providers and issued 566,794 common shares to settle $413,760 of outstanding debt.
93. On December 7, 2018, we issued 3,868,970 common shares and warrants exercisable for the purchase of 3,373,920 common shares at exercise prices ranging from $0.67 to $1.50 per share, to private investors for gross proceeds of $2,275,200.
94. On December 7, 2018, we issued 1,190,476 common shares and warrants exercisable for the purchase of 1,190,476 common shares at exercise prices of $0.525 per share, to an investor for gross proceeds of $500,000.  
95. On December 28,  2018, we issued a convertible debenture of $143,750 due April 29, 2019, including an original issue discount of $18,750, bearing interest at 10% per annum and convertible into common shares at US$0.48 per share, together with warrants exercisable for 260,416 common shares at a price of US$0.48 per share, for net proceeds of $125,000.
96. On January 1, 2019, we issued 25,000 common shares to a consultant pursuant to an independent contractor agreement entitling the holder to 25,000 common shares in three installments at the end of each month commencing in June.
97. On January 10, 2019, we issued 1,522,080 common shares and warrants exercisable for the purchase of 1,437,557 common shares at an exercise price of $1.50 per share, to investors for gross proceeds of $645,100.
98. On January 11, 2019, we issued 307,692 common shares and warrants exercisable for the purchase of 307,692 common shares at an exercise price of $1.50 per share for gross proceeds of $200,000.
99. On January 16, 2019, we issued a 5% convertible debenture of $2,400,000 due October 19, 2019, including an original issue discount of $400,000, convertible into common shares at $0.40 per share, to an investor for net proceeds of $2,000,000.
100. On January 25, 2019, we issued 147,058 common shares and warrants exercisable for the purchase of 147,058 common shares at an exercise price of $0.37 per share, for net proceeds of $50,000.

  

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ITEM 11. DESCRIPTION OF REGISTRANT’S SECURITIES TO BE REGISTERED.

 

The following description of our capital stock is a summary only and is qualified in its entirety by reference to our Articles of Amalgamation, as amended and Bylaws, which are included as Exhibits 3.1 and 3.2 of this registration statement.

 

Authorized/Issued Capital

 

Our authorized share capital consists of an unlimited number of common shares without nominal or par value and an unlimited number of preferred shares without nominal or par value. There are currently no preferred shares outstanding.

 

Common Shares

 

All shares on issue by us are common shares and as such the rights pertaining to these common shares are the same. There are no common shares which have superior or inferior rights. We do not currently have any preferred shares outstanding.

 

All our outstanding common shares are validly issued, fully paid and non-assessable. The rights attached to our common shares are as follows:

 

Dividend Rights. The directors may declare that a dividend be paid to the members according to the shareholders’ pro rata shareholdings and the directors may fix the amount, the time for payment and the method of payment. No dividend is payable except in accordance with the Business Corporations Act (Ontario) as amended from time to time and no dividend carries interest as against us.

 

Voting Rights. Holders of common shares have one vote for each ordinary share held on all matters submitted to a vote of shareholders. Such voting rights may be affected by the grant of any special voting rights to the holders of a class of shares with preferential rights that may be authorized in the future.

 

The quorum required for an ordinary meeting of shareholders consists of at least two shareholders present in person, or by proxy, attorney or representative appointed pursuant to our bylaws. A meeting adjourned for lack of a quorum generally is adjourned to the same day in the following week at the same time and place. At the reconvened meeting, the required quorum consists of any two members holding 5% of the shares entitled to vote at the meeting present in person, or be represented by proxy. The meeting is dissolved if a quorum is not present within a reasonable time, provided the shareholders present may adjourn the meeting to a fixed time and place.

 

To be adopted, a resolution requires approval by the holders of a majority of the voting rights represented at the meeting, in person, by proxy, or by written ballot and voting thereon

 

Rights in the Event of Liquidation. In the event of our liquidation, after satisfaction of liabilities to creditors, and the passing of a special resolution giving effect to the following, our assets will be distributed to the holders of common shares in proportion to the capital at the commencement of the liquidation paid up or which ought to have been paid up on the shares held by them, respectively. This right may be affected by the grant of preferential dividend or distribution rights to the holders of a class of shares with preferential rights, such as the right in winding up to payment in cash of the amount then paid up on the share, and any arrears of dividend in respect of that share, in priority to any other class of shares.

  

Transfer Agent. Common shares are transferable at the offices of our transfer agent and registrar, Computershare Investor Services Inc., 500 Burrard Street, 3rd Floor, Vancouver, British Columbia V6C 3B9.

 

There are no restrictions in our charter documents on the free transferability of the common shares.

 

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Changing rights attached to common shares

 

In order to change the rights of our shareholders with respect to certain fundamental changes as described in Section 168 of the Business Corporations Act (Ontario), we would need to amend our Articles to effect the change. Such an amendment would require the approval of holders of two-thirds of the votes of our common shares, and any other shares carrying the right to vote at any general meeting of our shareholders, cast at a duly called special meeting. The Business Corporations Act (Ontario) also provides that a sale, lease or exchange of all or substantially all of the property of a corporation other than in the ordinary course of business of the corporation likewise requires the approval of the shareholders at a duly called special meeting. For such fundamental changes and sale, lease and exchange, a shareholder is entitled under the Business Corporations Act (Ontario) to dissent in respect of such a resolution amending the Articles and, if the resolution is adopted and we implement such changes, demand payment of the fair value of the shareholder’s common shares.

 

Annual and Special Meetings

 

The Business Corporations Act (Ontario) provides that the directors of a corporation shall call an annual meeting of shareholders not later than 15 months after holding the last preceding annual meeting. The Business Corporations Act (Ontario) also provides that, in the case of an offering corporation, the directors shall place before each annual meeting of shareholders, the financial statements required to be filed under the Securities Act (Ontario) and the regulations thereunder relating to the period that began immediately after the end of the last completed financial year and ended not more than six months before the annual meeting and the immediately preceding financial year, if any.

 

The Board has the power to call a special meeting of shareholders at any time.

 

Notice of the date, time and location of each meeting of shareholders must be given not less than 21 days or more than 50 days before the date of each meeting to each director, to our auditor and to each shareholder who at the close of business on the record date for notice is entered in the securities register as the holder of one or more shares carrying the right to vote at the meeting.

 

Notice of a meeting of shareholders called for any other purpose other than consideration of the minutes of an earlier meeting, financial statements, reports of the directors or auditor, setting or changing the number of directors, the election of directors and reappointment of the incumbent auditor, must state the general nature of the special business in sufficient detail to permit the shareholder to form a reasoned judgment on such business, must state the text of any special resolution to be submitted to the meeting, and must, if the special business includes considering, approving, ratifying, adopting or authorizing any document or the signing of or giving of effect to any document, have attached to it, a copy of the document or state that a copy of the document will be available for inspection by shareholders at our records office or another accessible location.

 

The only persons entitled to be present at a meeting of shareholders are those entitled to vote, our directors and our auditor. Any other person may be admitted only on the invitation of the chairman of the meeting or with the consent of the meeting. In circumstances where a court orders a meeting of shareholders, the court may direct how the meeting may be held, including who may attend the meeting.

 

Limitations on the Rights to Own Securities in Our Company

 

No share may be issued until it is fully paid.

 

Neither Canadian law nor our Articles or bylaws limit the right of a non-resident to hold or vote our common shares, other than as provided in the Investment Canada Act (the “Investment Act”), as amended by the World Trade Organization Agreement Implementation Act (the “WTOA Act”). The Investment Act generally prohibits implementation of a direct reviewable investment by an individual, government or agency thereof, corporation, partnership, trust or joint venture that is not a “Canadian,” as defined in the Investment Act (a “non-Canadian”), unless, after review, the minister responsible for the Investment Act is satisfied that the investment is likely to be of net benefit to Canada. An investment in our common shares by a non-Canadian (other than a “WTO Investor,” as defined below) would be reviewable under the Investment Act if it were an investment to acquire direct control of our company, and the value of our assets were CDN$5.0 million or more (provided that immediately prior to the implementation of the investment our company was not controlled by WTO Investors). An investment in our common shares by a WTO Investor (or by a non-Canadian other than a WTO Investor if, immediately prior to the implementation of the investment our company was controlled by WTO Investors) would be reviewable under the Investment Act if it were an investment to acquire direct control of our company and the value of our assets equaled or exceeded certain threshold amounts determined on an annual basis.

 

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The threshold for a pre-closing net benefit review depends on whether the purchaser is: (a) controlled by a person or entity from a member of the WTO; (b) a state-owned enterprise (SOE); or (c) from a country considered a “Trade Agreement Investor” under the Investment Act. A different threshold also applies if the Canadian business carries on a cultural business.

 

The 2018 threshold for WTO investors that are SOEs will be CDN$398 million based on the book value of the Canadian business’ assets, up from CDN$379 million in 2017.

 

The 2018 thresholds for review for direct acquisitions of control of Canadian businesses by private sector investor WTO investors (CDN$1 billion) and private sector trade-agreement investors (CDN$1.5 billion) remain the same and are both based on the “enterprise value” of the Canadian business being acquired.

 

A non-Canadian, whether a WTO Investor or otherwise, would be deemed to acquire control of our company for purposes of the Investment Act if he or she acquired a majority of our common shares. The acquisition of less than a majority, but at least one-third of the shares, would be presumed to be an acquisition of control of our company, unless it could be established that we are not controlled in fact by the acquirer through the ownership of the shares. In general, an individual is a WTO Investor if he or she is a “national” of a country (other than Canada) that is a member of the WTO (“WTO Member”) or has a right of permanent residence in a WTO Member. A corporation or other entity will be a “WTO Investor” if it is a “WTO Investor-controlled entity,” pursuant to detailed rules set out in the Investment Act. The U.S. is a WTO Member. Certain transactions involving our common shares would be exempt from the Investment Act, including: an acquisition of the shares if the acquisition were made in the ordinary course of that person’s business as a trader or dealer in securities; an acquisition of control of our company in connection with the realization of a security interest granted for a loan or other financial assistance and not for any purpose related to the provisions of the Investment Act; and an acquisition of control of our company by reason of an amalgamation, merger, consolidation or corporate reorganization, following which the ultimate direct or indirect control in fact of us, through the ownership of voting interests, remains unchanged.

  

Impediments to Change of Control

 

In 2016, the Canadian Securities Administrators (the “CSA”) enacted amendments (the “Bid Amendments”) to the Take-Over Bid Regime. The Bid Amendments, which are very significant, are contained in National Instrument (NI) 62-104.

 

The Bid Amendments were intended to enhance the quality and integrity of the take-over bid regime and rebalance the current dynamics among offerors, offeree issuer boards of directors (“Offeree Boards”), and offeree issuer security holders by (i) facilitating the ability of offeree issuer security holders to make voluntary, informed and coordinated tender decisions, and (ii) providing the Offeree Board with additional time and discretion when responding to a take-over bid.

 

Specifically, the Bid Amendments require that all non-exempt take-over bids:

 

(1) receive tenders of more than 50% of the outstanding securities of the class that are subject to the bid, excluding securities beneficially owned, or over which control or direction is exercised, by the offeror or by any person acting jointly or in concert with the offeror (the “Minimum Tender Requirement”);

 

(2) be extended by the offeror for an additional 10 days after the Minimum Tender Requirement has been achieved and all other terms and conditions of the bid have been complied with or waived (the “10 Day Extension Requirement”); and

 

(3) remain open for a minimum deposit period of 105 days (the “Minimum 105 Day Bid Period”) unless

 

(a) the offeree board states in a news release a shorter deposit period for the bid of not less than 35 days, in which case all contemporaneous take-over bids must remain open for at least the stated shorter deposit period, or

 

(b) the issuer issues a news release that it intends to effect, pursuant to an agreement or otherwise, a specified alternative transaction, in which case all contemporaneous take-over bids must remain open for a deposit period of at least 35 days.

 

54

 

 

The Bid Amendments involved fundamental changes to the bid regime to establish a majority acceptance standard for all non-exempt take-over bids, a mandatory extension period to alleviate offeree security holder coercion concerns, and a 105 day minimum deposit period to address concerns that offeree boards did not have enough time to respond to an unsolicited take-over bid. The CSA determined not to amend National Policy 62-202 Defensive Tactics (“NP 62-202”) in connection with these amendments. They reminded participants in the capital markets of the continued applicability of NP 62-202, which means that securities regulators will be prepared to examine the actions of offeree boards in specific cases, and in light of the amended bid regime, to determine whether they are abusive of security holder rights.

 

Stockholder Ownership Disclosure Threshold in Bylaws

 

Neither our Articles nor bylaws contain a provision governing the ownership threshold above which shareholder ownership must be disclosed. Pursuant to Canadian securities legislation, an “early warning report”, news release and an “insider report” must be filed if a shareholder obtains ownership on a partially diluted basis of 10% or greater of our company.

 

Preferred Shares

 

We do not currently have any preferred shares outstanding. We are authorized to issue an unlimited number of preferred shares, issuable in one or more series. For each series of preferred shares the Board has the authority to fix the number of shares of such series and to determine the designation, rights, privileges, restrictions, and conditions attaching to such series, including: the rate or amount of or method of calculating preferential dividends, whether dividends will be cumulative or non-cumulative, the payment dates, whether the shares will be redeemable, and if so, the redemption price and terms and conditions of redemption, any voting rights, any conversion rights, any sinking fund, any purchase fund or other provisions and the amount payable on return of capital in the event of the liquidation, dissolution or winding-up of our company.

 

Shares Not Representing Capital

 

None.

 

Shares Held by Company

 

None.

  

History of Share Capital

 

As at November 30, 2018, there were 89,849,249 common shares issued and outstanding and as at August 31, 2018, there were 85,163,631 common shares issued and outstanding, which are listed for trading on the TSXV, and 9,858,333 stock options were outstanding under the 2018 Option Plan (or its predecessors plans). See Item 6.B “Compensation – Stock Plan” for additional information regarding the 2018 Option Plan (or its predecessors plans).

 

The number of outstanding common shares at the end of Fiscal 2018 (August 31, 2018), Fiscal 2017 (August 31, 2017), and Fiscal 2016 (August 31, 2016) were as follows: 85,163,631 shares: 54,220,699 shares, and 6,723,167 shares, respectively. There were 54,220,699 common shares outstanding at the beginning of Fiscal 2018 and 85,163,631 common shares outstanding at the end of Fiscal 2018. There were 6,723,167 common shares outstanding at the beginning of Fiscal 2017 and 54,220,699 common shares outstanding at the end of Fiscal 2017. There were 2,020,765 common shares outstanding at the beginning of Fiscal 2016 and 6,723,167 common shares outstanding at the end of Fiscal 2016.

 

As at the end of Fiscal 2018, 9,858,333 stock options were outstanding under the 2018 Stock Plan (or its predecessors plans).

 

55

 

 

ITEM 12. INDEMNIFICATION OF DIRECTORS AND OFFICERS.

 

Under the Business Corporations Act (Ontario), we may indemnify a director or officer, a former director or officer or another individual who acts or acted at our request as a director or officer, or an individual acting in a similar capacity, of another entity, against all costs, charges and expenses, including an amount paid to settle an action or satisfy a judgment, reasonably incurred by the individual in respect of any civil, criminal, administrative, investigative or other proceeding in which the individual is involved because of that association with us or other entity on condition that (i) the individual acted honestly and in good faith with a view to our best interests or, as the case may be, to the best interests of the other entity for which the individual acted as a director or officer or in a similar capacity at our request, and (ii) in the case of a criminal or administrative action or proceeding that is enforced by a monetary penalty, the individual also had reasonable grounds for believing that his or her conduct was lawful. Further, we may, with court approval, indemnify an individual described above in respect of an action by or on behalf of us or other entity to obtain a judgment in its favor, to which the individual is made a party because of the individual’s association with us or other entity, against all costs, charges and expenses reasonably incurred by the individual in connection with such action if the individual fulfills condition (i) above. An individual as described above is entitled as a matter of right to indemnification from us in respect of all costs, charges and expenses reasonably incurred by such individual in connection with the defense of any civil, criminal, administrative, investigative or other proceedings to which such individual is subject if he or she was not judged by a court or other competent authority to have committed any fault or omitted to do anything that he or she ought to have done, and has fulfilled conditions (i) and (ii) above.

 

In accordance with the Business Corporations Act (Ontario), we have agreed to indemnify each of our directors and officers against all costs, charges and expenses, including an amount paid to settle an action or satisfy a judgment, reasonably incurred by him in respect of any civil, criminal, administrative action or proceeding in which such individual is involved by reason of his association with us or other entity if he acted honestly and in good faith with a view to our best interests or such other entity, and he had reasonable grounds for believing that his conduct was lawful.

 

A policy of directors’ and officers’ liability insurance is maintained by the Company that insures directors and officers for losses as a result of claims against the directors and officers of the Registrant in their capacity as directors and officers and also reimburses the Registrant for payments made pursuant to the indemnity provisions under the by-laws of the Registrant and the Business Corporations Act (Ontario).

 

Insofar as indemnification for liabilities arising under the Securities Act, may be permitted to directors, officers or persons controlling us pursuant to the foregoing provisions, hawse have been informed that in the opinion of the SEC such indemnification is against public policy as expressed in the Securities Act, and is therefore unenforceable.

 

ITEM 13. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.

 

The financial statements of Petroteq Energy, Inc. appear at the end of this report beginning with the Index to Financial Statements on page F-1.

 

ITEM 14. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.

 

None.

   

ITEM 15. FINANCIAL STATEMENTS AND EXHIBITS.

 

(a) List of all financial statements filed as part of the registration statement.

 

Condensed Consolidated Interim Statements of Financial Position as of November 30, 2018 and August 31, 2018 (Unaudited) F-1
Condensed Consolidated Statements of Loss and Comprehensive Loss for the three months ended November 30, 2018 and 2017 (Unaudited) F-2
Condensed Consolidated Interim Statements of Changes in Shareholders’ Equity for the three months ended November 31, 2018 and 2017 (Unaudited) F-3
Condensed Consolidated Interim Statements of Cash Flows for the three months ended November 30, 2018 and 2017 (Unaudited) F-4
Notes to the Condensed Consolidated Interim Financial Statements for the three months ended November 30, 2018 and 2017 F-5
Report of Independent Registered Public Accountants F-36
Consolidated Statements of Financial Position for the years ended August 31, 2018 and 2017 F-37
Consolidated Statements of Loss and Comprehensive Loss for the years ended August 31, 2018 and 2017 F-38
Consolidated Statements of Changes in Stockholders’ Equity for the years ended August 31, 2018 and 2017 F-39
Consolidated Statements of Cash Flows for the years ended August 31, 2018 and 2017 F-40
Notes to Consolidated Financial Statements for the years ended August 31, 2018, 2017 and 2016 F-41

 

56

 

  

PETROTEQ ENERGY, INC.
Condensed Consolidated Interim Statements of Financial Position
As at November 30, 2018 and August 31, 2018
Expressed in US dollars

 

      November 30,   August 31, 
      2018   2018 
   Notes  (Unaudited)     
ASSETS           
Current assets             
Cash  4  $274,096   $2,640,001 
Trade and other receivables  5   404,013    404,013 
Current portion of advanced royalty payments  8(a)   349,579    331,200 
Ore inventory  7   317,839    122,242 
Other inventory      290,957    71,390 
Receivable form director      374,728    297,256 
Prepaid expenses and other current assets      160,114    331,688 
       2,171,326    4,197,790 
Advanced royalty payments  8(a)   515,757    467,886 
Notes receivable  6   1,684,487    381,550 
Mineral lease  9   11,111,143    11,111,143 
Investments      68,331    68,331 
Investment in Accord GR Energy      931,137    981,137 
Property, plant and equipment  10   25,927,244    21,188,895 
Intangible assets  11   707,671    707,671 
      $43,117,096   $39,104,403 
LIABILITIES             
Current liabilities             
Accounts payable  12  $2,410,322   $1,102,327 
Accrued expenses  12   642,874    1,900,081 
Unearned revenue      283,976    283,976 
Current portion of debt  13   1,214,594    1,027,569 
Current portion of convertible debentures  14   3,448,974    258,404 
       8,000,740    4,572,357 
Unearned advance royalties received  8(b)   170,000    170,000 
Debt  13   422,802    598,982 
Convertible debentures  14   -    250,000 
Reclamation and Restoration provision  15   586,583    583,664 
       9,180,125    6,175,003 
SHAREHOLDERS’ EQUITY             
Share capital  16   81,495,274    77,870,606 
Shares to be issued      2,522,106    996,401 
Share option reserve  17   13,377,325    12,823,000 
Share warrant reserve  18   4,783,244    3,207,915 
Deficit      (68,240,978)   (61,968,522)
       33,936,971    32,929,400 
      $43,117,096   $39,104,403 

 

Approved by the Board of Directors Aleksandr Blyumkin”   Travis Schneider”
  Alexsandr Blyumkin   Travis Schneider
  Director   Director

 

The accompanying notes are an integral part of the condensed consolidated interim financial statements

 

F-1

 

 

PETROTEQ ENERGY, INC.
Condensed Consolidated Interim Statements of Loss and Comprehensive Loss
For the three months ended November 30, 2018 and 2017
Expressed in US dollars
(Unaudited)

 

      Three months ended 
      November 30,   November 30, 
   Notes  2018   2017 
Revenues     $-   $- 
Cost of Goods Sold      33,750    111,250 
Gross Loss      (33,750)   (111,250)
Operating Expenses             
Depreciation and amortization      16,173    297,758 
General and administrative      192,206    28,478 
Capital raising fee      1,276,980    - 
Interest expense      218,679    121,484 
Other income      (26,259)   - 
Legal fees      681,365    32,625 
Professional fees      1,509,153    241,661 
Research and development costs      112,625    - 
Salaries and wages      236,612    182,000 
Share-based compensation  17(a) 20(a)   554,325    2,505,647 
Travel and promotion      1,228,464    79,814 
       6,000,323    3,489,467 
Net operating loss      6,034,073    3,600,717 
Loss on settlement of liabilities      108,973    - 
Loss on settlement of convertible debt  14(b)   79,410    - 
Equity loss from investment of Accord GR Energy, net of tax      50,000    44,995 
Net loss and Comprehensive loss      6,272,456    3,645,712 
Weighted Average Number of Shares Outstanding  19   88,734,027    54,708,759 
Basic and Diluted Loss per Share     $0.07   $0.07 

 

The accompanying notes are an integral part of the condensed consolidated interim financial statements

 

F-2

 

 

PETROTEQ ENERGY, INC.
Condensed Consolidated Interim Statements of Changes in Shareholders’ Equity
For the three months ended November 31, 2018 and 2017
Expressed in US dollars
(Unaudited)

 

      Number of Shares   Share   Shares to be   Option   Warrant       Shareholders’ 
   Notes  Outstanding*   Capital   Issued   Reserve   Reserve   Deficit   Equity 
Balance at August 31, 2017      54,220,699   $60,827,494   $56,800   $7,371,552   $618,667   $(46,856,367)  $22,018,146 
Share-based compensation  17(a) 20(a)   -    -    -    2,505,647    -    -    2,505,647 
Shares subscribed for  16   1,189,076    312,180    133,000    -    -    -    445,180 
Refund of share subscriptions                (56,800)                  (56,800)
Net loss      -    -    -    -    -    (3,645,712)   (3,645,712)
Balance at November 30, 2017      55,409,775   $61,139,674   $133,000   $9,877,199   $618,667   $(50,502,079)  $21,266,461 
Balance at August 31, 2018      85,163,631   $77,870,606   $996,401   $12,823,000   $3,207,915   $(61,968,522)  $32,929,400 
Share-based compensation  17(a) 20(a)  $1,300,000   $1,327,915    -    554,325    -    -    1,882,240 
Shares subscribed for  16   2,388,244    1,308,099    1,525,705    -   $677,506    -    3,511,310 
Settlement of debt  14(b)   316,223    334,487    -    -    -    -    334,487 
Settlement of liabilities      681,151    654,167    -    -    -    -    654,167 
Valuation of debt settlement warrants issued      -    -    -    -   $383,496    -    383,496 
Valuation of convertible debt warrants issued  14(c)-(f)   -    -    -    -   $514,327    -    514,327 
Net loss      -    -    -    -    -    (6,272,456)   (6,272,456)
Balance at November 30, 2018      89,849,249   $81,495,274   $2,522,106   $13,377,325   $4,783,244   $(68,240,978)  $33,936,971 

  

The accompanying notes are an integral part of the condensed consolidated interim financial statements

 

F-3

 

 

PETROTEQ ENERGY, INC.
Condensed Consolidated Interim Statements of Cash Flows
For the three months ended November 30, 2018 and 2017
Expressed in US dollars
(Unaudited)

 

   Three Months ended 
   November 30,   November 30, 
   2018   2017 
Cash flow used for operating activities:        
Net loss  $(6,272,456)  $(3,645,712)
Adjustments for non-cash, investing and financing items          
Depreciation and amortization   16,173    297,758 
Amortization of debt discount   156,802    - 
Loss on conversion of debt   79,409    - 
Loss (gain) on settlement of liabilities   108,973    - 
Share-based compensation   2,265,736    2,505,647 
Equity share of losses in Accord GR Energy   50,000    44,995 
Other   22,591    98,816 
Changes in operating assets and liabilities:          
Accounts payable   1,853,189    (231,245)
Accounts receivable   -    92,301 
Inventory   (415,165)   - 
Accrued expenses   (477,207)   162,880 
Prepaid expenses and deposits   171,574    (447,770)
Net cash used for operating activities   (2,440,381)   (1,122,330)
Cash flows used for investing activities:          
Purchase and construction of property and equipment   (4,754,522)   (496,064)
Investment in notes receivable   (2,202,123)   - 
Advance royalty payments   (100,000)   (99,296)
Net cash used for investing activities   (7,056,645)   (595,360)
Cash flows from financing activities:          
Repayment to executive officers   (77,472)   (226,495)
Proceeds on private equity placements   3,511,310    445,180 
Payments of debt   (252,717)   (157,821)
Proceeds from debt   450,000    789,300 
Proceeds from convertible debt   3,500,000    1,255,000 
Net cash from financing activities   7,131,121    2,105,164 
(Decrease) increase in cash   (2,365,905)   387,474 
Cash, beginning of the period   2,640,001    55,420 
Cash, end of the period  $274,096   $442,894 
Cash composed of:          
Cash  $274,096   $442,894 
Bank overdraft   -    - 
   $274,096   $442,894 
Supplemental disclosure of cash flow information          
Cash paid for interest  $27,292   $1,743 

 

The accompanying notes are an integral part of the condensed consolidated interim financial statements

 

F-4

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

1.NATURE OF OPERATIONS

 

Petroteq Energy Inc. (the “Company”) is an Ontario corporation which conducts oil sands mining and oil extraction operations in the USA. It operates through its indirectly wholly owned subsidiary company, Petroteq Oil Sands Recovery, LLC (“POSR”), which is engaged in mining and oil extraction from tar sands, and its 44.7% owned and equity accounted company Accord GR Energy, Inc. (“Accord”), which is engaged in using a specialized technology to extract oil from oil wells which have been depleted using conventional extraction methods.

 

The Company’s registered office is located at Suite 6000, 1 First Canadian Place, 100 King Street West, Toronto, Ontario, M5X IE2, Canada and its principal operating office is located at 15165 Ventura Blvd, Suite 200, Sherman Oaks, California 91403, USA.

 

POSR is engaged in a tar sands mining and oil processing operation, using a closed-loop solvent based extraction system that recovers bitumen from surface mining, and has completed the construction of an oil processing plant in the Asphalt Ridge area of Utah.

 

On July 4, 2016, the Company acquired 57.3% of the issued and outstanding common shares of Accord which, due to additional share subscriptions in Accord by other shareholders since August 31, 2016, was reduced to 44.7% as of August 31, 2017. The investment in Accord has therefore been recorded using the equity method for the years ended August 31, 2018 and 2017. The investment in Accord was consolidated for the year ended August 31, 2016 (Note 3(a)).

 

On April 6, 2017, the shareholders of the Company approved the consolidated its shares on a 30 for one basis, which was effected on May 5, 2017 (Note 16). The number of shares issued and outstanding have been retroactively adjusted for this consolidation in these financial statements.

 

In November 2017, the Company formed a wholly owned subsidiary, Petrobloq, LLC, to design and develop a blockchain-powered supply chain management platform for the oil and gas industry.

 

On June 1, 2018, the Company finalized the acquisition of a 100% interest in two leases for 1,312 acres of land within the Asphalt Ridge, Utah area. The lease contains approximately 7.331 million barrels of contingent resource expanding Petroteq’s total contingent resource of oil by 8.5% to 93.4 million barrels.

 

The Company has incurred losses for several years and, at November 30, 2018, has an accumulated deficit of $68,240,978 (August 31, 2018 - $61,968,522) and working capital (deficiency) of $5,829,414 (August 31, 2018 - $374,567). These condensed consolidated interim financial statements have been prepared on the basis that the Company will be able to realize its assets and discharge its liabilities in the normal course of business. The ability of the Company to continue as a going concern is dependent on obtaining additional financing, which it is currently in the process of obtaining. There is a risk that additional financing will not be available on a timely basis or on terms acceptable to the Company. These condensed consolidated interim financial statements do not reflect the adjustments or reclassifications that would be necessary if the Company were unable to continue operations in the normal course of business.

 

F-5

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

2.BASIS OF PREPARATION

 

(a)Statement of compliance

 

The unaudited condensed consolidated interim financial statements have been prepared in accordance with IAS 34 “Interim Financial Reporting” and should be read in conjunction with the Company’s annual consolidated financial statements for the years ended August 31, 2018 which were prepared in accordance with IFRS as issued by the International Accounting Standards Board (“IASB”) and Interpretations of the International Financial Reporting Interpretations Committee (“IFRIC”).

 

The unaudited condensed consolidated interim financial statements for the three months ended November 30, 2018 were approved and authorized for issuance by the Board of Directors on January 29, 2019.

 

(b)Basis of measurement

 

The condensed consolidated interim financial statements have been prepared on a historical cost basis except for certain financial assets and financial liabilities which are measured at fair value, as explained in the accounting policies set out in Note 3. The Company’s reporting currency and the functional currency of all of its operations is the U.S. dollar, as it is the principal currency of the primary economic environment in which the Company operates.

 

(c)Significant accounting judgments and estimates

 

The preparation of the condensed consolidated interim financial statements in accordance with IFRS requires management to make judgments, estimates and assumptions that affect the application of accounting policies and the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the condensed consolidated interim financial statements and the reported amounts of revenues and expenses during the reporting period. The significant accounting judgments and estimates included in these condensed consolidated interim financial statements are:

 

Useful lives and depreciation rates for intangible assets and property, plant and equipment

 

Depreciation expense is recorded on the basis of the estimated useful lives or units of expected production of intangible assets and property, plant and equipment. Changes in the useful life of assets from the initial estimate could impact the carrying value of intangible assets and property, plant and equipment and an adjustment would be recognized in profit or loss.

 

Review of carrying value of assets and impairment charges

 

When determining possible impairment of the carrying values of assets, management of the Company reviews the recoverable amount (the higher of the fair value less costs to sell or the value in use) of non-financial assets and objective evidence indicating impairment in the case of financial assets. These determinations and their individual assumptions require that management make a decision based on the best available information at each reporting period. Changes in these assumptions may alter the results of the impairment evaluation, the impairment charges recognized in profit or loss and the resulting carrying amounts of assets.

 

Provisions

 

Provisions are recorded based on the best estimate of the likelihood, timing, and magnitude of a future outflow of economic resources. Where the effect of the time value of money is material, the present value of the provision is recognized using a discount rate that reflects current market assessments of the time value of money.

 

F-6

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

2.BASIS OF PREPARATION (continued)

 

(c)Significant accounting judgments and estimates (continued)

 

Income taxes and recoverability of deferred tax assets

 

Actual amounts of income tax expense are not final until tax returns are filed and accepted by taxation authorities. Therefore, profit or loss in future reporting periods may be affected by the difference between the income tax expense estimates and the final tax assessments.

 

Judgment is required in determining whether deferred tax assets are recognized on the condensed consolidated interim statement of financial position. Deferred tax assets, including those arising from unutilized tax losses, require management of the Company to assess the likelihood that the Company will generate sufficient taxable profit in future periods in order to utilize recognized deferred tax assets. Estimates of future taxable profit are based on forecast cash flows from operations and the application of existing tax laws in each jurisdiction. To the extent that future cash flows and taxable profit differ from estimates, the ability of the Company to realize the deferred tax assets recorded on the condensed consolidated interim statement of financial position could be impacted. The Company has not recognized any deferred tax assets as at November 30, 2018 and August 31, 2018.

 

3.SIGNIFICANT ACCOUNTING POLICIES

 

(a)Basis of consolidation

 

The condensed consolidated interim financial statements include the financial statements of the Company and the entities controlled by the Company (its “subsidiaries”). Control is achieved where the Company has the power to govern the financial and operating policies of an entity and obtain the economic benefits from its activities.

 

The consolidated entities are:

 

  Entity  % of Ownership   Jurisdiction
  Petroteq Energy Inc.   Parent   Canada
  Petroteq Energy CA, Inc.   100%  USA
  MCW OSR Inc.   100%  USA
  MCW Oil Sands, Inc.   100%  USA
  Petroteq Oil Sands Recovery, LLC   100%  USA
  TMC Capital, LLC   100%  USA
  Petrobloq, LLC   100%  USA

 

The Company has accounted for its investment in Accord GR Energy, Inc. (“Accord”) on the equity basis since March 1, 2017. The Company had previously owned a controlling interest in Accord and the results were consolidated in the Company’s financial statements. However, subsequent cash contributions into Accord reduced the Company’s ownership to 44.7% as of March 1, 2017 and the results of Accord were deconsolidated from that date.

 

All intercompany transactions, balances, income and expenses are eliminated in full on consolidation.

 

F-7

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

3.SIGNIFICANT ACCOUNTING POLICIES (continued)

 

(b)Business combinations

 

The Company accounts for business combinations using the acquisition method, under which the acquirer measures the cost of the business combination as the total of the fair values, at the date of exchange, of the assets obtained, liabilities incurred and equity instruments issued by the acquirer in exchange for control of the acquiree. Goodwill is measured as the fair value of the consideration transferred, including the recognized amount of any non-controlling interest in the acquiree, less the net recognized amount (generally the fair value) of the identifiable assets and liabilities assumed, measured as at the acquisition date.

 

Transaction costs, other than those associated with issue of debt or equity securities, that the Company incurs in connection with a business combination are expensed as incurred.

 

(c)Income recognition

 

The Company sells hydrocarbon products (bitumen or crude oil) produced by its oil extraction facility at prevailing market prices. The Company also expects to enter into short term supply agreements with customers. Revenues are recognized when the hydrocarbon products are delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, when prices are fixed or determinable and when collectability is reasonably assured.

 

(d)Investment in associate

 

An associate is an entity over which the Company has significant influence and that is neither a subsidiary nor an interest in a joint venture. Significant influence is the power to participate in the financial and operating policy decisions of the investee but is not control or joint control over those policies.

 

The results and assets and liabilities of associates are incorporated in the condensed consolidated interim financial statements using the equity method of accounting. Under the equity method, investment in associate is carried in the condensed consolidated interim statement of financial position at cost as adjusted for changes in the Company’s share of the net assets of the associate, less any impairment in the value of the investment. Losses of an associate in excess of the Company’s interest in that associate are not recognized. Additional losses are provided for, and a liability is recognized, only to the extent that the Company has incurred legal or constructive obligations or made payment on behalf of the associate.

 

(e)Property, plant and equipment

 

Property, plant and equipment is recorded at cost and amortized over their useful lives or over the expected units of production. Maintenance and repairs are expensed as incurred. Major renewals, betterments and start-up costs are capitalized. When items of property, plant or equipment are sold, impaired, or retired, the related costs and accumulated amortization are removed and any gain or loss is included in net income. Amortization is determined on a straight-line method with the following expected useful lives:

 

  Machinery and equipment 5-7 years
  Furniture and fixtures 7 years
  Leasehold improvements Lease term
  Oil extraction facility Expected total unit of production

 

F-8

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

3.SIGNIFICANT ACCOUNTING POLICIES (continued)

 

(f)Oil and gas properties

 

Oil and gas property interests

 

Assets owned are recorded at cost less accumulated depreciations and accumulated impairment losses. The Company initially capitalizes the costs of acquiring these properties, directly and indirectly, and thereafter expenses exploration activities, pending the evaluation of commercially recoverable reserves. The results of exploratory programs can take considerable time to analyze and the determination that commercial reserves have been discovered requires both judgment and industry experience. All development costs are capitalized after it has been determined that a property has recoverable reserves. On the commencement of commercial production, net capitalized costs are charged to operations on a unit-of-production basis, by property, using estimated proven and probable recoverable reserves as the depletion base.

 

Oil and gas reserves

 

Oil and gas reserves are evaluated by independent qualified reserves evaluators. The estimation of reserves is a subjective process. Estimates are based on projected future rates of production, estimated commodity prices, engineering data and the timing of future expenditures, all of which are subject to uncertainty and interpretation. Reserves estimates can be revised either upwards or downwards based on updated information such as future drilling, testing and production levels. Reserves estimates, although not reported as part of the Company’s condensed consolidated interim financial statements, can have a significant effect on net earnings as a result of their impact on depreciation and depletion rates, asset impairment and goodwill impairment.

 

(g)Intangible assets

 

Intangible assets are recorded at cost less accumulated depreciation and accumulated impairment losses. Amortization of intangible assets is recorded on a straight-line basis over a life determined by the maximum length of the benefits expected or on the basis of expected units of production from acquired intellectual property, technology and technology licenses. Intangible assets with indefinite useful lives are not amortized and are tested for impairment at least annually.

 

The useful life for the Oil Extraction Technologies was established as 15 years in these condensed consolidated interim financial statements as at August 31, 2017. On August 31, 2018, the Company determined that amortizing the Oil Extraction Technologies over units of production was more accurate estimation of the how the benefits are expected to be received by the Company. At that time, it was not determinable as the oil extraction facility was not yet ready for use and no amortization was recorded during the years ended August 31, 2017 and 2018 as commercial production using the Technologies had not commenced.

 

(h)Impairment of assets

 

At the end of each reporting period, the Company’s property and equipment, oil and gas properties, and intangible assets are reviewed for indications that the carrying amount may not be recoverable. If any such indication is present, the recoverable amount of the asset is estimated in order to determine whether impairments exist. Where the asset does not generate cash flows that are independent from other assets, the Company estimates the recoverable amount of the cash-generating unit to which the asset belongs.

 

F-9

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

3.SIGNIFICANT ACCOUNTING POLICIES (continued)

 

(h)Impairment of assets (continued)

 

The recoverable amount of an asset is the higher of fair value less costs to sell and value in use. In assessing value in use, the estimated future cash flows are discounted to their present value, using a pre-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the asset for which estimates of future cash flows have not been adjusted. The cash flows used in the impairment assessment require management to make assumptions and estimates about recoverable resources, production quantities, future commodity prices, operating costs and future development costs. Changes in any of the assumptions, such as a downward revision in reserves, a decrease in future commodity prices or an increase in operating costs, could result in an impairment of carrying values.

 

If the recoverable amount of an asset or cash generating unit is estimated to be less than its carrying amount, the carrying amount is reduced to the recoverable amount. Impairment is recognized immediately in the condensed consolidated interim statement of (income) loss and comprehensive (income) loss. Where an impairment subsequently reverses, the carrying amount is increased to the revised estimate of the recoverable amount but only to the carrying value that would have been recorded if no impairment had previously been recognized. A reversal is recognized as a reduction in the impairment charge for the period.

 

(i)Financial instruments

 

Financial instruments consist of financial assets and financial liabilities and are initially recognized at fair value, net of transaction costs if applicable. Measurement in subsequent periods depends on whether the financial instrument is classified as held-to-maturity, loans and receivables, fair value through profit or loss (“FVTPL”), available-for-sale, or other financial liabilities.

 

Held-to-maturity investments and loans and receivables are measured at amortized cost, with amortization of premiums or discounts, losses and impairment included in current period interest income or expense. Financial assets and liabilities are classified as FVTPL when the financial instrument is held for trading or are designated as FVTPL. Financial instruments at FVTPL are measured at fair market value with all gains and losses included in operations in the period in which they arise. Available-for-sale financial assets are measured at fair market value with revaluation gains and losses included in other comprehensive income until the asset is removed from the condensed consolidated interim statement of financial position, and losses due to impairment are included in operations. All other financial assets and liabilities, except for cash and cash equivalents, are carried at amortized cost.

 

The Company’s financial instruments are:

 

Cash, classified as FVTPL and measured at fair value
Trade and other receivables and notes receivable, classified as loans and receivables and measured at amortized cost
Accounts payable, accrued expenses, payable to director, convertible debentures and long-term debt, classified as other financial liabilities and measured at amortized cost

 

The recorded values of cash, trade and other receivables, notes receivable, accounts payable, accrued expenses and due to or from director approximate their fair values based on their short term nature. The recorded values of convertible debentures and long-term debt approximate their fair values when the interest rates of the debt approximate market rates.

 

In accordance with industry practice, the Company includes amounts in current assets and current liabilities for current maturities receivable or payable under contracts which may extend beyond one year.

F-10

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

3.SIGNIFICANT ACCOUNTING POLICIES (continued)

 

(i)Financial instruments (continued)

 

The Company classifies and discloses fair value measurements based on a three-level hierarchy:

 

Level 1 – inputs are unadjusted quoted prices in active markets for identical assets or liabilities;
Level 2 – inputs other than quoted prices in Level 1 that are observable for the asset or liability, either directly or indirectly; and
Level 3 – inputs for the asset or liability that are not based on observable market data.

 

(j)Provisions

 

Provisions are recorded when a present legal or constructive obligation exists as a result of past events where it is probable that an outflow of resources embodying economic benefits will be required to settle the obligation, and a reliable estimate of the amount of the obligation can be made.

 

The amount recognized as a provision is the best estimate of the consideration required to settle the present obligation at the condensed consolidated interim statement of financial position date, taking into account the risks and uncertainties surrounding the obligation. Where a provision is measured using the cash flows estimated to settle the present obligation, its carrying amount is the present value of those cash flows. When some or all of the economic benefits required to settle a provision are expected to be recovered from a third party, the receivable is recognized as an asset if it is virtually certain that reimbursement will be received and the amount receivable can be measured reliably. Over time, the discounted provision is increased for the change in present value based on the discount rates that reflect current market assessments and the risks specific to the liability. The periodic unwinding of the discount is recognized in the condensed consolidated interim statement of loss (income) as part of interest expense.

 

When the provision liability is initially recognized, the present value of the estimated costs is capitalized by increasing the carrying amount of the related asset to the extent that it was incurred as a result of the development or construction of the asset. Additional provisions which arise due to further development or construction of assets are recognized as additions or charges to the corresponding asset and provisions when they occur.

 

Changes in the estimated timing of provisions or changes to the estimated future costs are dealt with prospectively by recognizing an adjustment to the provision and a corresponding adjustment to the asset to which it relates. Any reduction in the provision and, therefore, any deduction from the asset to which it relates may not exceed the carrying amount of that asset. If it does, any excess over the carrying value is recognized immediately in the condensed consolidated interim statement of loss (income).

 

(k)Income taxes

 

Provisions for income taxes consist of current and deferred tax expense and are recorded in operations.

 

Current tax expense is the expected tax payable on the taxable income for the period, using tax rates enacted or substantively enacted at the end of the period, adjusted for amendments to tax payable for previous years.

 

F-11

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

3.SIGNIFICANT ACCOUNTING POLICIES (continued)

 

(k)Income taxes (continued)

 

Deferred tax assets and liabilities are computed using the asset and liability method on temporary differences between the carrying amounts of assets and liabilities on the condensed consolidated interim statement of financial position and their corresponding tax values, using the enacted or substantially enacted, income tax rates at each condensed consolidated interim statement of financial position date. Deferred tax assets also result from unused losses and other deductions carried forward. The valuation of deferred tax assets is reviewed on a regular basis and adjusted to the extent that it is not probable that sufficient taxable profit will be available to allow all or part of the deferred income tax asset to be utilized by use of a valuation allowance to reflect the estimated realizable amount.

 

(l)Comprehensive income or loss

 

Other comprehensive income or loss is the change in net assets arising from transactions and other events and circumstances from non-owner sources. Comprehensive income comprises net income or loss and other comprehensive income or loss. Financial assets that are classified as available-for-sale will have revaluation gains and losses included in other comprehensive income or loss until the asset is removed from the condensed consolidated interim statement of financial position. At present, the Company has no other comprehensive income or loss.

 

(m)Earnings per share

 

Basic earnings per share is computed by dividing net income or loss attributable to common shareholders of the Company by the weighted average number of common shares outstanding during the period.

 

Diluted earnings per share is determined by adjusting net income or loss attributable to common shareholders of the Company and the weighted average number of common shares outstanding by the effects of potentially dilutive instruments, if such conversion would decrease earnings per share.

 

(n)Share-based payments

 

The Company may grant share purchase options to directors, officers, employees and others providing similar services. The fair value of these share purchase options is measured at grant date using the Black-Scholes option pricing model taking into account the terms and conditions upon which the options were granted. Share-based compensation expense is recognized over the period during which the options vest, with a corresponding increase in equity.

 

The Company may also grant equity instruments to consultants and other parties in exchange for goods and services. Such instruments are measured at the fair value of the goods and services received on the date they are received and are recorded as share-based compensation expense with a corresponding increase in equity. If the fair value of the goods and services received are not reliably determinable, their fair value is measured by reference to the fair value of the equity instruments granted.

 

(o)Reclamation and restoration obligations

 

Liabilities related to environmental protection and reclamation costs are recognized when the obligation is incurred and the fair value of the related costs can be reasonably estimated. This includes future site restoration and other costs as required due to environmental law or contracts. Reclamation and restoration obligations are determined by discounting the expected future cash outflows for reclamation and restoration at a pre-tax rate that reflects current market assessments of the time value of money

 

F-12

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

3.SIGNIFICANT ACCOUNTING POLICIES (continued)

 

(p)Comparative amounts

 

The comparative amounts presented in these condensed consolidated interim financial statements have been reclassified where necessary to conform to the presentation used in the current year.

 

(q)New accounting standards and interpretations

 

The following is a summary of new standards, amendments and interpretations that are effective for annual periods beginning on or after January 1, 2017:

 

(a)IAS 7, Statement of Cash Flows (“IAS 7”) – amendments

 

The amendments to IAS 7 require additional disclosure of changes in liabilities arising from financing activities.

 

(b)IAS 12, Income Taxes (“IAS 12”) - amendments

 

The amendments to IAS 12 clarify the recognition of deferred tax assets for unrealized losses.

 

The application of the above amendments did not have any material impact on these condensed consolidated interim financial statements.

 

The following is a summary of new standards, amendments and interpretations that have been issued but not yet adopted in these condensed consolidated interim financial statements:

 

(a)IFRS 9, Financial Instruments (“IFRS 9”)

 

IFRS 9 uses a single approach to determine whether a financial asset is measured at amortized cost or fair value, replacing the multiple classification options in IAS 39. The approach in IFRS 9 is based on how an entity manages its financial impairment methods in IAS 39. IFRS 9 is effective for annual periods beginning on or after January 1, 2018, with earlier adoption permitted. The Company is currently evaluating the impact of the adoption of the amendments on its financial statements; however, the impact, if any, is not expected to be significant.

 

(b)IFRS 15, Revenue from Contracts with Customers (“IFRS 15”)

 

IFRS 15 establishes a comprehensive framework for determining whether, how much and when revenue is recognized. It replaces existing revenue recognition guidance, including IAS 18 Revenue, IAS 11 Construction Contracts and IFRIC 13 Customer Loyalty Programmes. IFRS 15 is effective for annual periods beginning on or after January 1, 2018, with early adoption permitted.

 

F-13

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

3.SIGNIFICANT ACCOUNTING POLICIES (continued)

 

(q)New accounting standards and interpretations (continued)

 

(c)IFRS 16 Leases (IFRS 16”)

 

IFRS 16 provides a single lessee accounting model, requiring lessees to recognize assets and liabilities for all leases unless the lease term is 12 months or less or the underlying asset has a low value. Lessors continue to classify leases as operating or finance, with IFRS 16’s approach to lessor accounting substantially unchanged from its predecessor IAS 17 Leases. IFRS 16 replaces IAS 17 Leases, IFRIC 4 Determining Whether an Arrangement Contains a Lease, SIC -15 Operating Leases – Incentives, and SIC – 27 Evaluating the Substance of Transactions Involving the Legal Form of a Lease. IFRS 16 is effective for annual periods beginning on or after January 1, 2019, with earlier adoption permitted if IFRS 15 Revenue from Contracts with Customers is also applied.

 

(d)IFRS 2 Share-based Payment (“IFRS 2”) – amendments

 

The amendments to IFRS 2 provide clarification and guidance on the treatment of vesting and non-vesting conditions related to cash-settled share-based payment transactions, on share-based payment transactions with a net settlement feature for withholding tax obligations, and on accounting for modification of a share-based payment transaction that changes its classification from cash-settled to equity-settled. The amendments to IFRS 2 are effective for annual periods beginning on or after January 1, 2018, with earlier application permitted.

 

(e)IFRIC 23 – Uncertainty Over Income Tax Treatments (“IFRIC 23”)

 

IFRIC 23 clarifies application of the recognition and measurement requirements in IAS 12 when there is uncertainty over income tax treatments. It is effective for annual periods beginning on or after January 1, 2019 with early adoption permitted.

 

The Company has assessed the impact that these new and amended standards have on the condensed consolidated interim financial statements, and no significant impact was identified.

 

4.CASH

 

The Company considers all highly liquid instruments purchased with a maturity of three months or less to be cash equivalents.

 

5.TRADE AND OTHER RECEIVABLES

 

The Company’s trade and other receivables consist of:

 

     November 30,
2018
   August 31,
2018
 
           
  Goods and services tax receivable  $59,013   $59,013 
  Other receivables   345,000    345,000 
     $404,013   $404,013 

 

Information about the Company’s exposure to credit risks for trade and other receivables is included in Note 26(a)(i).

 

F-14

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

 

6.NOTES RECEIVABLE

 

The Company’s notes receivables consist of:

 

            Principal due   Principal due 
     Maturity Date  Interest Rate   November 30,
2018
   August 31,
2018
 
                  
  Private debtor  October 5, 2019   5%  $100,000   $- 
  Private debtor  March 15, 2020   5%   76,000    76,000 
  Private debtor  August 20, 2021   5%   362,000    300,000 
  Private debtor  August 20, 2021   5%   1,139,223    - 
  Interest accrued           7,264    5,550 
             $1,684,487   $381,150 

 

7.ORE INVENTORY

 

On June 1, 2015, the Company acquired a 100% interest in TMC Capital LLC, which holds the rights to mine ore from the Asphalt Ridge deposit. The mining and crushing of the bituminous sands has been contracted to an independent third party.

 

During the three months ended November 30, 2018, the cost of mining, hauling and crushing the ore, amounting to $317,839 (August 31, 2018: $122,242), was recorded as the cost of the crushed ore inventory.

 

8.ADVANCED ROYALTY PAYMENTS

 

(a)Advance royalty payments to Asphalt Ridge, Inc.

 

During the year ended August 31, 2015, the Company acquired TMC Capital, LLC, which has a mining and mineral lease with Asphalt Ridge, Inc. (the TMC Mineral Lease”) (Note 9(b)). The mining and mineral lease with Asphalt Ridge, Inc. required the Company to make minimum advance royalty payments which can be used to offset future production royalties for a maximum of two years following the year the advance royalty payment was made.

 

On October 1, 2015, the Company and Asphalt Ridge, Inc. amended the advance royalty payments in the TMC Mineral Lease. All previous advance royalty payments required under the original agreement were deemed to be paid in full. The amended advance royalty payments required were: $60,000 per quarter from October 1, 2015 to September 30, 2017, $100,000 per quarter from October 1, 2017 to June 30, 2020 and $150,000 per quarter thereafter.

 

On March 12, 2016, a second amendment was made to the TMC Mineral Lease. The amended advanced royalty payments required are $60,000 per quarter from October 1, 2015 to February 28, 2018, $100,000 per quarter from March 1, 2018 to December 31, 2020 and $150,000 per quarter thereafter.

 

Effective February 21, 2018, a third amendment was made to the TMC Mineral Lease. The amended advanced royalty payments required are $100,000 per quarter from July 1, 2018 to June 30, 2020 and $150,000 per quarter thereafter.

 

F-15

 

 

PETROTEQ ENERGY INC.
Notes to the Condensed Consolidated Interim Financial Statements
For the three months ended November 30, 2018 and 2017
Expressed in US dollars

  

8.ADVANCED ROYALTY PAYMENTS (continued)

 

(a)Advance royalty payments to Asphalt Ridge, Inc. (continued)

 

As at November 30, 2018, the Company has paid advance royalties of $1,990,336 (August 31, 2018 - $1,890,336) to the lease holder, of which a total of $1,125,000 have been used to pay royalties as they have come due under the terms of the TMC Mineral Lease. During the three months ended November 30, 2018, $100,000 in advance royalties were paid and $33,750 have been used to pay royalties which have come due. The royalties expensed have been recognized in cost of goods sold on the condensed consolidated interim statement of loss and comprehensive loss.

 

As at November 30, 2018, the Company expects to record minimum royalties paid of $349,580 from these advance royalties either against production royalties or for the royalties due within a one year period.

 

(b)Unearned advance royalty payments from Blackrock Petroleum, Inc.

 

During the year ended August 31, 2015, the Company entered into a sublease agreement with Blackrock Petroleum, Inc. (“Blackrock”), pursuant to which it received $170,000 of unearned advance royalties. The sublease was for a portion of the mining and mineral lease with Asphalt Ridge, Inc. (Note 9(b)). Blackrock is a company associated with Accord and the sublease was effectively terminated in the acquisition by the Company of control of Accord on July 4, 2016.

 

9.MINERAL LEASES

 

     TMC Mineral Lease   POSR Mineral Lease   Total 
  Cost            
  August 31, 2017  $11,091,388   $-   $11,091,388 
  Additions   -    19,755    19,755 
  August 31, 2018   11,091,388    19,755    11,111,143 
  Additions   -    -    - 
  November 30, 2018  $11,091,388   $19,755   $11,111,143 
                  
  Accumulated Amortization               
  August 31, 2017  $-   $-   $- 
  Additions   -    -    - 
  August 31, 2018   -    -    - 
  Additions   -    -    - 
  November 30, 2018  $-   $-   $- 
                  
  Carrying Amount               
  August 31, 2017  $11,091,388   $-   $11,091,388 
  August 31, 2018  $11,091,388   $19,755   $11,111,143 
  November 30, 2018  $11,091,388   $19,755   $11,111,143 

 

F-16

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

 

9.MINERAL LEASES (continued)

 

(a)TMC mineral lease

 

On June 1, 2015, the Company acquired TMC Capital, LLC (“TMC”). TMC holds a mining and mineral lease, subleased from Asphalt Ridge, Inc., on the Asphalt Ridge property located in Uintah County, Utah (the “TMC Mineral Lease”).

 

The primary term of the TMC Mineral Lease was from July 1, 2013 to July 1, 2018. During the primary term, the Company was required to meet certain requirements for oil production. After July 1, 2018, the TMC Mineral Lease would remain in effect as long as certain requirements for oil production continue to be met by the Company. If the Company failed to meet these requirements, the Lease would automatically terminate 90 days after the calendar year in which the requirements were not met. In addition, the Company was required to make certain advance royalty payments to the lessor (Note 8(a)). The TMC Mineral Lease was subject to a 10% royalty for the first three years and varying percentages thereafter based on the price of oil. An additional 1.6% royalty is payable to the previous lessees of the TMC Mineral Lease. The TMC Mineral Lease also required the Company to make minimum expenditures on the property of $1,000,000 for the first three years, increasing to $2,000,000 for the next three years.

 

Amendments were made to certain key terms of the TMC Mineral Lease on October 1, 2015, March 1, 2016, February 1, 2018, and November 21, 2018, which are summarized below.

 

Among the amendments, certain properties previously excluded were included in the lease agreement. In addition, the termination clause was amended to:

 

(i)Termination will be automatic if there is a lack of a written financial commitment to fund the proposed 1,000 barrel per day production facility prior to July 1, 2019 and another 1,000 barrel per day production facility prior to July 1, 2020.
(ii)Cessation of operations or inadequate production due to increased operating costs or decreased marketability and production is not restored to 80% of capacity within six months of such cessation.
(iii)The proposed 3,000 barrel per day plant fails to produce a minimum of 80% of its rated capacity for at least 180 calendar days during the lease year commencing July 1, 2021 plus any extension periods.
(iv)The lessee may surrender the lease with 30 days written notice.
(v)Breach of material terms of the lease, the lessor will inform the lessee in writing and the lessee will have 30 days to cure financial breaches and 150 days to cure any other non-monetary breach.

 

The term of the lease was extended by the termination clause, providing a written commitment is obtained to fund the 3,000 barrel per day proposed plant. The Company is required to produce a minimum average daily quantity of bitumen, crude oil and/or bitumen products, for a minimum of 180 days during each lease year and 600 days in three consecutive lease years, of:

 

(i)By July 1, 2019 plus any extension periods, 80% of 1,000 barrels per day.
(ii)By July 1, 2020 plus any extension periods, 80% of 2,000 barrels per day.
(iii)By July 1, 2021, plus any extension periods, 80% of 3,000 barrels per day.

 

Minimum expenditures to be incurred on the properties are $2,000,000 beginning July 1, 2021 if a minimum daily production of 3,000 barrels per day during a 180 day period is not achieved.

 

F-17

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

 

9.MINERAL LEASES (continued)

 

(a)TMC mineral lease (continued)

 

Advance royalties required are:

 

(i)From July 1, 2018 to June 30, 2020, minimum payments of $100,000 per quarter.
(ii)From July 1, 2020, minimum payments of $150,000 per quarter.
(iii)Minimum payments commencing on July 1, 2020 will be adjusted for CPI inflation.

 

Production royalties payable are amended to 8% of the gross sales revenue, subject to certain adjustments up until June 30, 2020. After that date, royalties will be calculated on a sliding scale based on crude oil prices ranging from 8% to 16% of gross sales revenues, subject to certain adjustments.

 

(b)Petroteq Oil Sands Recovery, LLC mineral lease (the “SITLA Mineral Lease”)

 

On June 1, 2018, the Company acquired mineral rights under two mineral leases entered into between the State of Utah’s School and Institutional Trust Land Administration (“SITLA”), as lessor, and POSR, as lessee, covering lands in Asphalt Ridge that largely adjoin the lands held under the TMC Mineral Lease (collectively, the “SITLA Mineral Leases”). The SITLA Mineral Leases are valid until May 30, 2028 and have rights for extensions based on reasonable production. The leases remain in effect beyond the original lease term so long as mining and sale of the tar sands are continued and sufficient to cover operating costs of the Company.

 

Advanced royalty of $10 per acre are due annually each year the lease remains in effect and can be applied against actual production royalties. The advanced royalty is subject to price adjustment by the lessor after the tenth year of the lease and then at the end of each period of five years thereafter.

 

Production royalties payable are 8% of the market price of marketable product or products produced from the tar sands and sold under arm’s length contract of sale. Production royalties have a minimum of $3 per barrel of produced substance and may be increased by the lessor after the first ten years of production at a maximum rate of 1% per year and up to 12.5%.

 

F-18

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

 

10.PROPERTY, PLANT AND EQUIPMENT

 

     Oil Extraction Plant   Other Property and Equipment   Total 
  Cost            
  August 31, 2017  $16,846,500   $315,967   $17,162,467 
  Additions   6,254,535    78,588    6,333,123 
  August 31, 2018   23,101,035    394,555    23,495,590 
  Additions   4,737,232    17,290    4,754,522 
  November 30, 2018  $27,838,267   $411,845   $28,250,112 
                  
  Accumulated Amortization               
  August 31, 2017  $2,148,214   $107,300   $2,255,514 
  Additions   -    51,181    51,181 
  August 31, 2018   2,148,214    158,481    2,306,695 
  Additions   -    16,173    16,173 
  November 30, 2018  $2,148,214   $174,654   $2,322,868 
                  
  Carrying Amount               
  August 31, 2017  $14,698,286   $208,667   $14,906,953 
  August 31, 2018  $20,952,821   $236,074   $21,188,895 
  November 30, 2018  $25,690,053   $237,191   $25,927,244 

 

(a)Oil Extraction Plant

 

In June 2011, the Company commenced the development of an oil extraction facility on its mineral lease in Maeser, Utah and entered into construction and equipment fabrication contracts for this purpose. On September 1, 2015, the first phase of the plant was completed and was ready for production of hydrocarbon products for resale to third parties. During the year ended August 31, 2017 the Company began the dismantling and relocating the oil extraction facility to its TMC Mineral Lease facility to improve production and logistical efficiencies whilst continuing its project to increase production capacity to a minimum capacity of 1,000 barrels per day. The plant has been relocated to the TMC mining site and expansion of the plant to production of 1,000 barrels per day has been substantially completed.

 

The cost of construction includes capitalized borrowing costs for the three months ended November 30, 2018 of $nil (year ended August 31, 2018: $18,666) and total capitalized borrowing costs as at November 30, 2018 of $2,230,746 (August 31, 2018 - $2,230,746).

 

As a result of the relocation of the plant and the planned expansion of the plant’s production capacity to 1,000 barrels per day, and subsequently to an additional 3,000 barrels per day, the Company reevaluated the depreciation policy of the oil extraction plant and the oil extraction technologies (Note 11(a)) and determined that depreciation should be recorded on the basis of the expected production of the completed plant at various capacities. No amortization has been recorded during the three months ended November 30, 2018 and the 2018 fiscal year as there has only been test production during that period.

 

F-19

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

 

11.INTANGIBLE ASSETS

 

     Oil Extraction Technology 
  Cost     
  August 31, 2017  $809,869 
  Additions   - 
  August 31, 2018   809,869 
  Additions   - 
  November 30, 2018  $809,869 
        
  Accumulated Amortization     
  August 31, 2017  $102,198 
  Additions   - 
  August 31, 2018   102,198 
  Additions   - 
  November 30, 2018  $102,198 
        
  Carrying Amounts     
  August 31, 2017  $707,671 
  August 31, 2018  $707,671 
  November 30, 2018  $707,671 

 

(a)Oil extraction technologies

 

During the year ended August 31, 2012, the Company acquired a closed-loop solvent based oil extraction technology which facilitates the extraction of oil from a wide range of bituminous sands and other hydrocarbon sediments. The Company has filed patents for this technology in the USA and Canada and has employed it in its oil extraction plant. The Company commenced partial production from its oil extraction plant on September 1, 2015 and was amortizing the cost of the technology over fifteen years, the expected life of the oil extraction plant. Since the Company has substantially completed the increase in capacity of the plant to 1,000 barrels during fiscal 2018, and expects to further expand the capacity to an additional 3,000 daily, it determined that a more appropriate basis for the amortization of the technology is the units of production at the plant after commercial production begins again. No amortization of the technology was recorded during the 2018 fiscal year.

 

F-20

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

 

12.ACCOUNTS PAYABLE AND ACCRUED EXPENSES

 

Accounts payable as at November 30, 2018 and August 31, 2018 consist primarily of amounts outstanding for construction and expansion of the oil extraction plant and other operating expenses that are due on demand.

 

Accrued expenses as at November 30, 2018 and August 31, 2018 consist primarily of other operating expenses and interest accruals on long-term debt (Note 13) and convertible debentures (Note 14).

 

Information about the Company’s exposure to liquidity risk is included in Note 26(c).

 

13.DEBT

 

            Principal due   Principal due 
  Lender  Maturity Date  Interest
Rate
   November 30,
2018
   August 31,
2018
 
                  
  Private lenders  September 1, 2018   10.00%  $350,000   $200,000 
  Private lenders  May 1, 2019   5.00%   566,974    632,512 
  Private lenders  September 17, 2019   10.00%   100,000    - 
  Private lenders  July 28, 2020   10.00%   -    120,900 
  Private lenders  August 31, 2020   5.00%   70,900    70,900 
  Equipment loans  April 20, 2020 – November 7, 2021   4.30 - 12.36%   549,522    602,239 
                     
  Total loans          $1,637,396   $1,626,551 

 

The maturity date of the long term debt is as follows:

 

     November 30,
2018
   August 31,
2018
 
           
  Principal classified as repayable within one year  $1,214,594   $1,027,569 
  Principal classified as repayable later than one year   422,802    598,982 
             
     $1,637,396   $1,626,551 

 

(a)Private lenders

 

(i)On July 3, 2018, the Company received a $200,000 advance from a private lender bearing interest at 10% per annum and repayable on September 2, 2018. The loan is guaranteed by the Chairman of the Board. The loan was repaid on September 4, 2018. On October 30, 2018 the Company received a further advance of $350,000 from the same lender, interest free and repayable on December 2, 2018.

 

F-21

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

 

13.DEBT (continued)

 

(a)Private lenders (continued)

 

(ii)On October 10, 2014, the Company issued two secured debentures for an aggregate principal amount of CAD $1,100,000 to two private lenders. The debentures bear interest at a rate of 12% per annum, maturing on October 15, 2017 and are secured by all of the assets of the Company. In addition, the Company issued common share purchase warrants to acquire an aggregate of 16,667 common shares of the Company. On September 22, 2016, the two secured debentures were amended to extend the maturity date to January 31, 2017. The terms of these debentures were renegotiated with the debenture holders to allow for the conversion of the secured debentures into common shares of the Company at a rate of CAD $4.50 per common share and to increase the interest rate, starting June 1, 2016, to 15% per annum. On January 31, 2017, the two secured debentures were amended to extend the maturity date to July 31, 2017. Additional transaction costs and penalties incurred for the loan modifications amounted to $223,510. On February 9, 2018, the two secured debentures were renegotiated with the debenture holders to extend the loan to May 1, 2019. A portion of the debenture amounting to CAD $628,585 was amended to be convertible into common shares of the Company, of which, CAD $365,000 have been converted on May 1, 2018. The remaining convertible portion is interest free and was to be converted from August 1, 2018 to January 1, 2019. The remaining non-convertible portion of the debenture was to be paid off in 12 equal monthly instalments beginning May 1, 2018. On September 11, 2018, the remaining convertible portion of the debenture was converted into common shares of the Company and a portion of the non-convertible portion of the debenture was settled through the issue of 316,223 common shares of the Company.

 

(iii)On October 4, 2018, the Company received an advance of $100,000 from Bay Private Equity in terms of a debenture line of credit of $9,500,000 made available to the Company. The debenture matures on September 17, 2019 and bears interest at 10% per annum. As compensation of the line of credit the Company issued 950,000 commitment shares to Bay Private Equity and a further 300,000 shares as a finders fee to a third party.

 

(iv)The Company received advances from a private lenders during the years ended August 31, 2018 and 2017 in the form of unsecured promissory notes. These promissory notes mature on July 28, 2020, and bear interest at 10% per annum. The Company repaid the remaining private lender and advanced the lender a further $1,260,123, refer note 6 above.

 

(v)The Company received advances from a private lenders during the year ended August 31, 2018 and 2017 in the form of unsecured promissory notes. This promissory notes matures on August 31, 2020 and bear interest at 5% per annum.

 

(b)Equipment loans

 

The Company entered into two equipment loan agreements with financial institutions to acquire equipment for the oil extraction facility. The loans had a term of 60 months and bore interest at rates between 4.3% and 4.9% per annum. Principal and interest were paid in monthly installments. These loans were secured by the acquired assets.

 

On May 7, 2018, the Company entered into a negotiable promissory note and security agreement with Commercial Credit Group to acquire a crusher from Power Equipment Company for $660,959. An implied interest rate was calculated as 12.36% based timing of the initial repayment of $132,200 and subsequent 42 monthly instalments of $15,571. The promissory note was secured by the equipment financed.

 

F-22

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

 

14.CONVERTIBLE DEBENTURES

 

            Principal due   Principal due 
  Lender  Maturity Date  Interest Rate   November 30,
2018
   August 31,
2018
 
                  
  Alpha Capital Anstalt  October 31, 2018   5.00%  $56,500   $56,500 
  Private lenders  January 1, 2019   0.00%   -    201,904 
  Calvary Fund I LP  September 4, 2019   10.00%   250,000    250,000 
  Bay Private Equity, Inc.  September 17, 2019   5.00%   3,300,000    - 
  Calvary Fund I LP  September 4, 2019   10.00%   250,000    - 
  SBI Investments LLC  September 4, 2019   10.00%   250,000    - 
              4,106,500    508,404 
  Unamortized debt discount           (657,526)   - 
  Total loans          $3,448,974   $508,404 

 

The maturity date of the convertible debentures are as follows:

 

     November 30,
2018
   August 31,
2017
 
           
  Principal classified as repayable within one year  $3,448,974   $258,404 
  Principal classified as repayable later than one year   -    250,000 
     $3,448,974   $508,404 

 

(a)Alpha Capital Anstalt

 

On August 31, 2017, the Company issued a convertible secured note for $565,000 to Alpha Capital Anstalt. The convertible secured note bears interest at a rate of 5% per annum and matures on October 31, 2018. The convertible secured note is convertible into units, consisting of one common share of the Company and one common share purchase warrant of the Company, at a conversion price of $0.29 per unit until August 31, 2022. Each warrant would entitle the holder to acquire one additional common share at an exercise price of $0.315 per share until August 31, 2022. The convertible secured note is secured by all of the assets of the Company.

 

From December 19, 2017 to May 22, 2018, a total of $508,500 of the principal of the convertible secured notes was converted into 1,753,447 units. From March 16, 2018 to July 11, 2018, Alpha Capital Anstalt exercised a total of 1,753,447 warrants to purchase 1,753,447 common shares of the Company. On December 3, 2018, the remaining $56,500 and accrued interest thereon of $13,479 was settled by the issue of 145,788 common shares.

 

(b)Private lenders

 

According to the terms of an amendment made with two debenture holders and the Company on February 9, 2018, a portion of their debentures was convertible into common shares (Note 13(a)(iii)). On September 11, 2018, the remaining convertible portion of the debenture was converted into common shares of the Company through the issue of 316,223 common shares of the Company.

 

F-23

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

 

14.CONVERTIBLE DEBENTURES (continued)

 

(c)Calvary Fund I LP

 

On September 4, 2018, the Company issued units to Calvary Fund I LP for $250,000, which was originally advanced on August 9, 2018. The units consists of 250 units of $1,000 convertible debenture and 1,149.424 commons share purchase warrants. The convertible debenture bears interest at 10%, matures on September 4, 2018 and is convertible one common share of the Company at a price of $0.87 per common share. The common share purchase warrants entitle the holder to acquire additional common shares of the Company at a price of $0.87 per share and expires on September 4, 2019.

 

(d)Bay Private Equity, Inc.

 

On September 17, 2018, the Company issued 3 one year Convertible units of $1,100,000 each to Bay Private Equity, Inc. (“Bay”) for net proceeds of $2,979,980 related to this agreement. These units bear interest at 5% per annum and mature one year from the date of issue. Each unit consists of one senior secured convertible debenture of $1,100,000 and 250,000 common share purchase warrants. Each convertible debenture may be converted to common shares of the Company at a conversion price of $1.00 per share. Each common share purchase warrant entitles the holder to purchase an additional common share the Company at a price of $1.10 per share for one year after the issue date.

 

(e)Calvary Fund I LP

 

On October 12, 2018, the Company entered into an agreement with Calvary Fund I LP whereby the Company issued 250 one year units for proceeds of $250,000, each unit consisting of a $1,000 principal convertible unsecured debenture, bearing interest at 10% per annum and convertible into common shares at $0.86 per share, and a warrant exercisable for 1,162 common shares at an exercise price of $0.86 per share.

 

(f)SBI Investments, LLC

 

On October 15, 2018, the Company entered into an agreement with SBI Investments LLC whereby the Company issued 250 one year units for proceeds of $250,000, each debenture consisting of a $1,000 principal convertible unsecured debenture, bearing interest at 10% per annum and convertible into common shares at $0.86 per share, and a warrant exercisable for 1,162 shares of common stock at an exercise price of $0.86 per share.

 

F-24

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

 

15.RECLAMATION AND RESTORATION PROVISIONS

 

     Oil Extraction Facility   Site Restoration   Total 
               
  Balance at August 31, 2017  $364,140   $208,080   $572,220 
  Accretion expense   7,283    4,161    11,444 
  Balance at August 31, 2018   371,423    212,241    583,664 
  Accretion expense   1,858    1,061    2,919 
  Balance at November 30, 2018  $373,281   $213,302   $586,583 

 

(a)Oil Extraction Plant

 

In accordance with the terms of the lease agreement, the Company is required to dismantle its oil extraction plant at the end of the lease term, which is expected to be in 25 years. During the year ended August 31, 2015, the Company recorded a provision of $350,000 for dismantling the facility.

 

Because of the long-term nature of the liability, the greatest uncertainties in estimating this provision are the costs that will be incurred and the timing of the dismantling of the oil extraction facility. In particular, the Company has assumed that the oil extraction facility will be dismantled using technology and equipment currently available and that the plant will continue to be economically viable until the end of the lease term.

 

The discount rate used in the calculation of the provision as at August 31, 2018 and 2017 is 2.0%.

 

(b)Site restoration

 

In accordance with environmental laws in the United States, the Company’s environmental permits and the lease agreements, the Company is required to restore contaminated and disturbed land to its original condition before the end of the lease term, which is expected to be in 25 years. During the year ended August 31, 2015, the Company provided $200,000 for this purpose.

 

The site restoration provision represents rehabilitation and restoration costs related to oil extraction sites. This provision has been created based on the Company’s internal estimates. Significant assumptions in estimating the provision include the technology and equipment currently available, future environmental laws and restoration requirements, and future market prices for the necessary restoration works required.

 

The discount rate used in the calculation of the provision as at August 31, 2018 and 2017 is 2.0%.

 

F-25

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

  

16.COMMON SHARES

 

  Authorized unlimited common shares without par value
  Issued and Outstanding 89,849,249 common shares as at November 30, 2018.

 

Between September 4, 2018 and November 8, 2018, the Company issued 681,151 shares of common stock to several investors in settlement of $545,194 of trade debt.

 

Between September 1, 2018 and September 30, 2018, the Company issued 1,300,000 shares valued at $1,327,915 as compensation for professional services rendered to the Company, including 1,250,000 shares of common stock issued as fees for the Bay Private Equity convertible debt raise, refer note 14(d) above.

 

On September 6, 2018, the Company issued 1,234,567 units to an investor for net proceeds of $1,000,000. Each unit consists of one share of common stock and three quarters of a share purchase warrant for a total warrant exercisable over 925,925 shares of common stock.

 

On September 28, 2018, the Company issued 316,223 shares to two private investors in settlement of the remaining portion of their convertible debt of $255,078. Refer note 14(b) above.

 

On October 11, 2018, the Company issued 81,229 shares of common stock to investors for net proceeds of $79,605. In addition a further 752,040 units were issued to investors for net proceeds of $737,000. Each unit consisting of one share of common stock and a warrant exercisable for a share of common stock at exercise prices ranging from $1.35 to $1.50.

 

On November 7, 2018, the Company issued 320,408 units to investors for net proceeds of $169,000. Each unit consisting of one share of common stock and a warrant exercisable for a share of common stock at an exercise price ranging from $0.61 to $0.66 per share. 

 

17.SHARE PURCHASE OPTIONS

 

(a)Stock option plan

 

The Company has a stock option plan which allows the Board of Directors of the Company to grant options to acquire common shares of the Company to directors, officers, key employees and consultants. The option price, term and vesting are determined at the discretion of the Board of Directors, subject to certain restrictions as required by the policies of the TSX Venture Exchange. The stock option plan is a 20% fixed number plan with a maximum of 17,919,849 common shares reserved for issuance.

 

During the three months ended November 30, 2018, no share options were granted. During the year ended August 31, 2018 the Company granted 9,775,000 share options to directors, officers and consultants of the Company. The weighted average fair value of the options granted was estimated at $0.87 per share at the grant date using the Black-Scholes option pricing model.

 

During the three months ended November 30, 2018 the share based compensation expense of $554,325 relates to the vesting of options granted during the year ended August 31, 2018. The share based compensation expense for the three months ended November 30, 2017 of $2,505,647 relates to options issued during that period with immediate vesting.

 

F-26

 

 

PETROTEQ ENERGY INC.

Notes to the Condensed Consolidated Interim Financial Statements

For the three months ended November 30, 2018 and 2017

Expressed in US dollars

  

17.SHARE PURCHASE OPTIONS (continued)

 

(b)Share purchase options

 

Share purchase option transactions under the stock option plan were:

 

Share purchase options outstanding and exercisable as at November 30, 2018 are:

 

  Expiry Date  Exercise Price  Options Outstanding   Options Exercisable 
  December 31, 2018  USD $4.80   50,000    50,000 
  February 1, 2026  CAD $5.85   33,333    33,333 
  November 30, 2027  CAD $2.27   1,425,000    1,425,000 
  June 5, 2028  CAD $1.00   8,350,000    3,400,000 
         9,858,333    4,908,333 
  Weighted average remaining contractual life      9.3 years    9.4 years 
  Weighted average exercise price      CAD $1.22    CAD $1.44 

 

18.SHARE PURCHASE WARRANTS

 

Share purchase warrants outstanding as at November 30, 2018 are:

 

  Expiry Date  Exercise Price  Warrants Outstanding 
  April 12, 2019  USD $4.95   16,667 
  August 19, 2019  USD $7.50   66,665 
  September 4, 2019  USD $0.87   287,356 
  September 17, 2019  USD $1.10   750,000 
  October 12, 2019  USD $0.86   290,500 
  October 15, 2019  USD $0.86   290,500 
  November 5, 2019  CAD $28.35   25,327 
  March 9, 2020  USD $1.50   114,678