Reporting Guide

This guide is designed to assist you as you complete the 2018 Annual Oil and Gas Extraction Survey. If you need more information, please call the Statistics Canada Help Line at the number below.

Your answers are confidential.

Statistics Canada is prohibited by law from releasing any information it collects which could identify any person, business, or organization, unless consent has been given by the respondent or as permitted by the Statistics Act.

Statistics Canada will use information from this survey for statistical purposes.

Help Line: 1-877-949-9492

Table of contents

• A – Reporting instructions
• B – Definitions
• C – Revenue and expenses, deductions and net income
• D – Balance sheet
• E – Abandonment and reclamation costs
• F – Capital expenditures for crude oil in-situ, mining or upgraders
• G – Operating expenses for crude oil in-situ, mining or upgraders
• H – Operating expenses by provincial jurisdiction – Oil and Gas Extraction sector
• I – Upstream exploration expenditures by provincial and/or territorial jurisdiction– Oil and Gas Extraction sector (except oil sands)
• J – Upstream development expenditures by provincial and/or territorial jurisdiction– Oil and Gas Extraction sector (except oil sands)
• K – Upstream production expenditures by provincial and/or territorial jurisdiction– Oil and Gas Extraction sector (except oil sands)
• L – Upstream overhead expenditures by provincial jurisdiction and/or territorial jurisdiction – Oil and Gas Extraction sector

A – Reporting Instructions

Please report information for the period of January to December, 2018.

Please complete all sections as applicable.

If the information requested is unknown, please provide your best estimate.

B – Definitions

The Oil and Gas Extraction (except oil sands) industry, formerly known as Conventional Oil and Gas Extraction, comprises establishments primarily engaged in the exploration for, and/or production of, petroleum or natural gas from wells in which the hydrocarbons will initially flow or can be produced using normal pumping techniques.

Oil Sands Extraction, formerly known as Non-Conventional Extraction, industry relates to operations taking place in the geographical areas of Cold Lake, Peace River and Athabasca. The industry comprises establishments primarily engaged in producing crude oil and bitumen from oil sands or from reservoirs in which the hydrocarbons are semisolids and conventional production methods are not possible.

In-situ refers to the extraction techniques of drilling wells and then injecting steam, combustion or other sources of heat into the reservoir to warm the bitumen so it can be pumped to the surface.

Mining is the extraction of and production of crude oil from oil sands or from reservoirs in which the hydrocarbons are semisolids, using open-pit mining techniques.

Upgraders convert heavy bitumen into lighter crude oil.

C – Revenue and expenses, deductions and net income

Sales: Report the sales or transfer value of produced goods before any adjustment or intersegment elimination. Please include royalties and taxes that are imposed at the time of sale. Exclude G.S.T.

Other production revenue: Report the sales of services related to the oil and gas industry such as gas processing and well operating fees.

Other non-production revenue: Include all revenue not reported in sales or other production revenue, such as foreign currency gains and losses, dividends.

Royalties and similar payments: The total expenditures reported for royalties.

Operating expenses: Please include cost of materials and supplies used in extraction, production, surface lease rentals, lifting costs and all other expenditures which are related to producing operations. Exclude any 'non-cash' charges and royalties. All general and administrative costs related to producing activities and charged to current year operations should also be included here. The total operating expenses reported should equal the sum of operating expenditures for the oil sands extraction sector (question 33) plus the sum of operating expenses for the Oil and Gas Extraction sector (questions 35 to 38).

Salaries, wages and benefits: Include the cost of salaries and wages (including bonuses and commissions, employer contributions to pension, medical, unemployment insurance plans, etc.) paid to your own workforce during the reporting period.

Other operating expenses: Include only costs associated with non-producing operations and other expense items not reported elsewhere.

Interest expense: Include interest paid on bank loans, bonds, etc.

Federal income tax: Include federal income tax pertaining to the current period and assumed to be currently due.

Provincial income tax: Include provincial income tax pertaining to the current period and assumed to be currently due. The amount reported should include the Saskatchewan Corporate Capital Tax Surcharge if applicable.

Deferred income tax: Include accrued tax obligations reflected as an expense in the income statement, but not payable in the current reporting period.

Exploration and development charged to current operations: Include exploration and development expenses charged to current operations.

Amortization and depreciation expense: The systematic charge-off to expense of costs for depreciable assets that had been initially capitalised or deferred. Write-downs of depreciable assets resulting from impairments should be included in this category. However, write-offs arising from unusual dispositions and gains/losses on sales of assets should be reported under "Write-offs and amortization of deferred charges" and "Other non-cash items" respectively.

Depletion: Include the current depletion charges for costs subject to such deduction. Write-offs resulting from the application of ceiling tests should be reported under "Write-offs and amortization of deferred charges". Gains and losses on disposal of properties should be reported under "Other non-cash items".

Write-offs and amortization of deferred charges: Adjustments may be made for non-operating items which the company ordinarily eliminates from its reported "Internal cash flow".

Other non-cash expenses and deductions: Include non-cash items not reported elsewhere such as unrealised losses on currency transactions, non-controlling shareholders' interest in earnings of consolidated subsidiaries, and the equity portion of losses of unconsolidated affiliates. This item should be reduced by such non-cash revenue items as unrealised currency gains, non-controlling shareholders' interest in losses of consolidated subsidiaries, and equity in earnings of unconsolidated affiliates.

Number of employees: Provide the number of employees associated with salary, wages and benefits costs.

D – Balance sheet

Total current assets: Includes such items as cash, marketable securities, accounts receivable, inventories, etc.

Net capital assets: Includes land not held for the purpose of re-sale, amortizable assets such as buildings, machinery and equipment, etc.

Other assets: Include all assets not reported as either current or capital assets.

Current liabilities: Includes such items as current portion of long-term debt, accounts payable, notes payable, etc.

Long term debt: Includes all debt with a maturity of greater than one year.

Other liabilities: Include all liabilities not reported as either a current liability or long-term debt.

Equity: Includes common shares, preferred shares, retained earnings and all other equity.

E - Abandonment and Reclamation Costs

Include all costs related to abandonment and remediation such as well plugging and abandonment and remediation.

F – Capital expenditures for crude oil in-situ, mining or upgraders

Note: Regarding partnerships and joint venture activities or projects, report the expenditures reflecting your company's net interest in such oil sands projects or ventures.

Oil rights acquisitions, fees and retention costs:

• In-situ: Expenditures associated with land and lease acquisition relating to oil rights, fees and retention.
• Mining: Expenditures associated with the purchase of land and lease from others.
  Note: for in-situ and mining please include all fees associated with using land agents.
• Upgraders: Include expenses associated with upgrader facilities.

Machinery and equipment: Include items such as boilers, compressors, motors, pumps and any other items that may be termed manufacturing or mining equipment as opposed to a fixed installation such as a building.

Drilling and pre-mining expenditures: Drilling expenditures include core hole and delineation drilling. Include the cost of casing and other materials and equipment left in place, core analysis, logging, road building, and other directly related services. Pre-mining costs include overburden removal and other pre-production expenditures.

Capitalised overhead: Report the cost of capitalized overhead not allocated above. These overhead charges should exclude any amounts reported under Operating cost by provincial jurisdiction – Oil and Gas Extraction (except oil sands) sector and Upstream expenditures by provincial jurisdiction – Oil and Gas Extraction (except oil sands) sector.

Research and other expenditures: Include all research costs associated with oil sands extraction such as: laboratory work, consultants' fees, performance evaluations, and experimental pilot plants (including any capitalised operating costs). Other costs include items such as drainage systems, roadways, tankages, anti-pollution equipment and fixed installations not including machinery and equipment.

G – Operating expenses for crude oil in-situ, mining or upgraders

Field, well and/or plant: Include all direct operating expenses and any other expenses directly related to the mining, processing, upgrading and delivery of the product, and cost of purchased fuel and electricity.

Taxes: Include taxes to federal, provincial and municipal governments, but exclude royalties, income taxes, and taxes that are part of the list price of purchases.

Purchased fuel and electricity: Include costs for fuel and electricity for all sites.

Water handling and disposal: Include all costs pertaining to water handling and disposal.

Operating overhead: Include all remaining general and administrative expenses related to upstream operations, including any corporate allocation to this segment. (These overhead charges should exclude any reported under Capitalised overhead, question 24).

H - Operating expenses by provincial jurisdiction – Oil and Gas Extraction sector

Operating expenses: include all direct costs such as wages and salaries, materials and supplies, fuel and power, well conditioning costs, municipal taxes, other direct operating expenses, maintenance and repairs expensed and contract services. Also include the non-capitalised cost of purchased injection materials used in enhanced recovery projects.

Field, well and gathering operations for oil and gas: Include primary, secondary, and tertiary recovery and pressure maintenance facilities, gathering systems and other well site facilities, surface lease rentals, and cost of purchased fuel and electricity.

Natural gas processing plants: Include expenses associated with field processing plants as well as reprocessing activities, recycling projects, and cost of purchased fuel and electricity.

Taxes: Include taxes to federal, provincial and municipal governments, but exclude royalties, income taxes, and taxes that are part of the list price of purchases

Overhead: Include all remaining general and administrative expenses related to upstream operations, including any corporate allocation to this segment. (These overhead charges should exclude any reported under upstream expenditures by provincial jurisdiction.)

I – Upstream exploration expenditures by provincial and/or territorial jurisdiction– Oil and Gas Extraction sector (except oil sands)

Oil and gas rights acquisition and retention: Acquisition and retention costs and fees for oil and gas rights (include bonuses, legal fees and filing fees; exclude inter-company sales or transfers).

Land and leases purchased from other petroleum companies: Purchases from companies that are engaged primarily in petroleum activities.

Note: for questions 40 and 41 please include all fees associated with using land agents.

Geological and geophysical services: include all seismic, geological and geophysical expenditures. Include seismography, geological photography, digital processing, velocity surveying, stratigraphic testing, aeromagnetic surveying, core drilling and environmental impact studies. Also include such activities as bulldozing and dirt work, flying seismic crews in and out, (both company owned and contract), bottomhole contributions and other similar pre-exploration expenditures.

Exploration drilling: Drilling outside a proven area or within a proven area but to a previously untested horizon, in order to determine whether oil or gas reserves exist rather than to develop proven reserves discovered by previous drilling. Include costs of dry wells, casing and other materials and equipment abandoned in place, productive wells, including capped wells, and wells still in progress at year-end. Include, also, costs incurred in fighting blow-outs, runaways, and in replacing damaged equipment.

J – Upstream development expenditures by provincial and/or territorial jurisdiction– Oil and Gas Extraction sector (except oil sands)

Development drilling: Drilling within the proven area of an oil or gas reservoir to the depth of a stratigraphic horizon known to be productive for the purpose of extracting oil or gas reserves. This will cover costs of dry wells, including casing and other materials and equipment abandoned in place; productive wells, including capped well; and wells still in progress at year end. Include, also, costs incurred in fighting blow-outs, runaways, and in replacing damaged equipment. Exclude costs associated with service wells.

Note: There should be no development expenditures until a development plan has been approved.

Proven purchased reserves: Purchases from those companies that are engaged primarily in petroleum activities.

K – Upstream production expenditures by provincial and/or territorial jurisdiction– Oil and Gas Extraction sector (except oil sands)

Enhanced recovery projects: Include only expenditures on facilities in tertiary projects involving steam injection, miscible flooding, etc. Include service wells, both tangible and intangible, include the costs of drilling and equipping injection wells and the cost of capitalized injection fuel (miscible fluid). Exclude non-recoverable injection fluids charged to current operations.

Natural gas processing plants: Report only the capitalized amounts of the plants, including structures, measuring, regulating and related equipment.

Production facilities: Include tangible well and lease equipment comprising casing, tubing, wellheads, pumps, flowlines, separators, treaters, dehydrators. Include gathering pipelines, lease and centralized tank batteries and associated facilities prior to delivery to trunk pipelines terminals, and other production facilities. Include, also, costs associated with intangibles such as pre-production studies costs, and those expenditures that you consider to be pre-development.

Non-production facilities: Include automotive, airplane, communication, office and miscellaneous equipment not otherwise provided.

Drilling rigs and supply boats: Report expenditures including progress payments for the purchase of new and imported used and new drilling rigs (on and offshore) and supply boats.

L – Upstream overhead expenditures by provincial jurisdiction and/or territorial jurisdiction – Oil and Gas Extraction sector

Allocate capitalised upstream overhead to the categories indicated. These overhead charges should exclude any reported under Operating cost by provincial jurisdiction – Oil and Gas Extraction sector.

This original U.S. Energy Information Administration (EIA) document has been modified only slightly to better reflect Canadian legislation and standards.

Purpose

This monthly survey collects data on the activities of all Canadian refineries, terminals and upgraders involved in the production and distribution of refined petroleum products. This data is required for integration into the input-output sector of the Canadian System of National Accounts. Data is made available under the authority of the Statistics Act to other federal departments and provincial authorities through data sharing agreements subject to embodied principles of data confidentiality. Data is intended for use by survey respondents, industry associations, industry analysts, the press and the general public to assess trends in the Canadian petroleum sector.

Who Must Submit

To be completed by the operators of all petroleum refineries, upgraders and terminals located in Canada.

When to Submit

The survey must be received by Statistics Canada 10 days following the month in review.

How to Submit

An email invitation is sent to respondents to download an excel spreadsheet based questionnaire for completion and to provide access to a secure portal to upload the data to Statistic Canada.

• Login to the survey link.
• Download, complete, and save the questionnaire.
• Return to the survey link and follow the instructions to attach the completed questionnaire.

General Instructions

Respondent Identification Data

• Confirm the legal name of the reporting company.
• Confirm the operating name if appropriate.
• Confirm the establishment name.
• Confirm the physical address of the reporting company.
• Confirm the mailing address of the Contact. (Note: If the physical address and mailing address are the same, provide the information only for the physical address.)
• Confirm the name, telephone number, facsimile number, and e-mail address of the person to contact concerning information shown on the report. The person listed should be the person most knowledgeable of the specific data reported.

Operations

Quantities: Report using the following criteria.

Report all quantities to the nearest whole number in Cubic Metres.

Report for each product, beginning and end-of-month stocks, receipts, inputs, production, shipments, and fuel use and losses and adjustments during the month.

All values should be positive except for Losses and Adjustments, which can be negative.

Most products should balance: Stocks Beginning of Month + Receipts + Production = Inputs + Shipments + Fuel Uses + Losses and Adjustments + Stocks End of Month.

Report data for only those lines which are applicable to your operation. If there are no data for a specific line, leave the entire line blank.

Stocks (Beginning and End of Month)

Report beginning stocks as of midnight of the last day of the month prior to the current report month. Report ending stocks as of midnight of the last day of the current report month. All stocks should be corrected to 15.6^oC less basic sediment and water (BS&W).

Report all stocks in the custody of the establishment regardless of ownership. Reported stock quantities should represent actual measured inventories.

Report stocks of mixed liquefied petroleum gases (including unfractionated streams) by the individual components (i.e., ethane, propane, normal butane, and isobutane) as determined by chemical analysis.

Report ending stocks of all liquefied gases on their individual product lines as well as totals on the line hydrocarbon gas liquids, TOTAL.

Report all domestic and foreign stocks held at the refinery, terminal and upgrader.

Report stocks of oxygenates held at oxygenate production facilities which are either located within or adjacent to the refinery complex whose oxygenates are dedicated for use by this refinery complex (Captive Oxygenate Plants).

Report end-of-month stocks of unfinished oils by degree Celsius end-point. The following are the degree end-point categories: Naphthas and Lighter, less than 205^oC; Kerosene and Light Gas Oils, 205^oC to 343^oC; Heavy Gas Oils, 344^oC to 538^oC; and Residuum, greater than 538^oC.

Receipts During the Month

Report all receipts at the refinery, terminal and upgrader after the products are actually received at the establishment.

Oxygenates (excluding Fuel Ethanol), TOTAL is the sum of oxygenates received from sources outside the refinery (Merchant Plants), and oxygenates produced at the refinery (Captive Plants).

Report receipts of Natural Gas Plant Liquids and Liquefied Refinery Gases (including olefins and derivatives). Include both fuel use and petrochemical feedstock use.

Exclude natural gas used as a feedstock to produce hydrogen from refinery receipts. Also exclude natural gas received at the refinery for use as a fuel.

Inputs During Month (Refineries and Upgraders only)

Report the volume of crude oil, unfinished oils, natural gas plant liquids, other hydrocarbons, hydrogen, oxygenates, and liquefied refinery gases input to refinery processing units for the purpose of producing finished petroleum products.

Report gross refinery input for each item identified on the survey form.

Note: Gross inputs are typically greater than crude oil inputs since gross inputs include materials other than crude oil as well as any re-runs of the same cubic metres through the atmospheric crude oil distillation unit.

Exclude from input of Crude Oil any oils that have undergone prior refinery processing. Such oils should be reported as inputs of intermediate product (typically, unfinished oils or motor gasoline blending components) or finished product. An "Input" of a finished product, such as a finished motor gasoline or distillate fuel oil, represents a reclassification of a finished product.

Exclude inputs of product used to manufacture finished petrochemicals. Input of natural gas to produce hydrogen should be excluded. Input of feedstock to manufacture oxygenates should be excluded. Inputs of finished petroleum products are explained under "Reclassification of Inventory".

Input During the Month (Terminals only)

Report as input any finished product, blending component, oxygenate, or other material blended or reclassified to a different product. Examples of quantities to report as input include Blendstock for Oxygenate Blending (BOB) and Fuel Ethanol blended to produce finished motor gasoline, and kerosene blended with distillate fuel oil.

Report input whether blending or product reclassification takes place due to transfers of products between tanks, through in-line blending systems, or by splash blending in trucks or rail cars.

Report as input any Distillate Fuel Oil to be reclassified to a different Sulphur category as well as any Distillate Fuel Oil, Kerosene, or Kerosene-Type Jet Fuel being reclassified to a different product (see Reclassification of Inventory discussed later in these instructions).

Report gross input for each item listed on the survey form.

Report inputs of selected natural gas plant liquids and liquefied refinery gases (i.e. normal butane, butylene, isobutane, isobutylene, and pentanes plus) on their individual product lines as well as totals on the line for Hydrocarbon gas liquids, TOTAL.

Production During the Month (Refineries and Upgraders only)

Report gross refinery production during the month for each item identified on the survey.

Report the volume of petroleum products produced from processing of crude oil, unfinished oils, liquefied petroleum gases, other hydrocarbons, hydrogen, and oxygenates.

Report the volume of petroleum products produced from blending operations of motor gasoline and aviation blending components.

Report production of renewable fuels (fuel ethanol, biomass-based diesel fuel, other renewable diesel fuel, and other renewable fuels) when the volume of these fuels is increased by blending of petroleum. For example, if a cargo of undenatured fuel ethanol was delivered to your refinery and then denatured at the refinery with BOB for blending with fuel ethanol, then your report on the monthly refined petroleum products survey will show production of fuel ethanol equal to the volume of BOB blended with the fuel ethanol as denaturant.

Exclude from production any renewable fuels coprocessed with petroleum feedstocks. Production of renewable fuels from coprocessing with petroleum should be reported as receipts and inputs. For example, renewable diesel fuel production from animal fat processed through a diesel hydrotreater should be reported as receipts and inputs of other renewable diesel fuel. The volume of the receipt and input of other renewable diesel fuel will equal the volume of output from the hydrotreater that is attributed to animal fat.

Report the production of olefins (Ethylene, propylene, butylene) to include only that portion of liquefied refinery gases that are shipped from the refinery as a finished refinery product (e.g., olefins shipped to petrochemical facilities).

Report the production of aromatics (e.g., benzene, toluene, and xylene) based upon intended use. Aromatics to be used for blending or compounding into finished aviation or motor gasoline should be reported as production of aviation or motor gasoline blending components.

Report aromatics used as petrochemical feedstocks as production of Naphtha less than 205^oC.

Production During the Month (Terminals only)

Report as production any finished product or blending component blended or reclassified from inputs. Examples of production to report include Finished Motor Gasoline blended from input of BOB and Fuel Ethanol, and the increase in distillate fuel oil volume resulting from blending kerosene.

Report gross production for each item listed on the survey form.

Report production whether blending or product reclassification took place due to transfers of products between tanks, through in-line blending systems, or by splash blending in trucks or rail cars.

Report as production any Distillate Fuel Oil, Kerosene, or Kerosene-Type Jet Fuel reclassified from a different product (see Reclassification of Inventory discussed later in these instructions).

Report only production of fuel ethanol at the terminal resulting from blending of denaturant (finished gasoline, motor gasoline blending components, or pentanes plus) with undenatured fuel-grade ethanol.

Total Input and Total Production

When the report is completed correctly, every input cubic metre should have a corresponding production cubic metre. Therefore, total input should equal total production. Small variances may exist due to rounding, measurement, gains, and losses. These variances are reported using total line, quantities reported for the total line balance total input and total production.

Shipments During the Month

Report all shipments, including intracompany shipments to other storage facilities, refineries, chemical plants, or fractionating facilities. Inputs to onsite petrochemical plants should be reported as shipments from your establishment.

Fuel Use During the Month

Report petroleum products used as fuel at your establishment.

Exclude fuel use at petrochemical facilities located at the same site as the refinery.

Losses and Adjustments During Month

Report all non-processing losses (e.g., spills, fire losses, contamination, etc.) by product.

Exclude refinery processing gains and losses as well as stock discrepancies caused by gauging problems.

Reclassification of Inventory

Report a finished product that is reclassified as a different finished product or as an unfinished oil as follows: the quantity of the original product is reported in the "Input" column and the reclassified product is reported in the "Production" column.

For example, if you produce 10,000 cubic metres of kerosene during January and have it in storage at the end of the month, this quantity is to be reported as "Production" of Kerosene on the January report. If during February the intended use of the 10,000 cubic metres of kerosene is changed to Kerosene-Type Jet Fuel, report this reclassification by reporting the 10,000 cubic metres as "Input" of Kerosene and as "Production" of Kerosene-Type Jet Fuel.

Hydrogen

Report receipts, inputs, and fuel use and loss of hydrogen. Include hydrogen produced from hydrogen plants located at refineries (and upgraders) and hydrogen purchased from third-party suppliers.

Exclude hydrogen produced from catalytic reformers from quantities reported for to avoid double counting inputs. Hydrogen input from reformer units is counted indirectly as input of crude oil and unfinished oils.

Exclude feedstock inputs for hydrogen production.

Report Still gas, Special Naphtha, and Unfinished oils, naphtha, and lighter as shipments to a hydrogen plant when these products are used as hydrogen feedstock. Report any feedstock return streams from a hydrogen plant as receipts from the hydrogen plant and inputs at the establishment. Report receipts of return streams using the same product as were used when reporting feedstock shipments to the hydrogen plant.

Oxygenates

Report oxygenates on an individual basis. All other oxygenates includes other aliphatic alcohols and ethers intended for motor gasoline blending.

Report stocks held at oxygenate production facilities, located within or adjacent to the establishment (captive plants).

Report gross inputs of oxygenates. Do not "net out" oxygenate inputs by reporting the difference between oxygenate inputs and production.

Exclude oxygenates as motor gasoline blending components unless they have been commingled with motor gasoline blending components.

Liquefied Gases

Report all mixes of natural gas plant liquids (including unfractionated streams) and liquefied refinery gases by individual components as determined by chemical analysis, (e.g., ethane, propane, normal butane, isobutane, pentanes plus for gas plant liquids, and ethane/ethylene, propane/propylene, normal butane/butylene, and isobutane/isobutylene for liquefied refinery gases).

Report Liquefied Petroleum Gases (LPG) extracted from natural gas liquids streams originating at natural gas processing plants (NGPL's), and received by the establishment for processing into finished products.

Report Liquefied Refinery Gases (LRG) that are fractionated from crude oil or produced from downstream processes, such as catalytic cracking, and result in finished LRG (liquefied gases production that are subsequently stored or shipped as a LRG). The volume of LRG for any class (e.g. Ethane) has to be equal or greater than any breakout volume (e.g. Ethylene).

Report production of polymer grade or chemical grade propylene as propylene. Production volumes reported as propylene will include propylene and up to 8% propane. This is based on a definition of chemical grade propylene made up of at least 92% propylene and up to 8% propane.

Report production of mixed propane and propylene streams that do not meet the specification for polymer grade or chemical grade propylene (including refinery grade propylene) separately as propane and propylene, as determined by chemical analysis, except in cases when you are reasonably certain the mixed propane and propylene stream will be sold as fuel, in which case report the entire mixed stream as propane.

Finished Motor Gasoline

Report finished motor gasoline blended with fuel ethanol.

Gasoline Blending Components

Report naphtha-range hydrocarbons as one of the products broadly classified as motor gasoline blending components in cases where the intended end use is for blending or compounding into finished motor gasoline. Products classified as motor gasoline blending components include blendstock for oxygenate blending (BOB), gasoline treated as blendstock (GTAB) and all "other" motor gasoline blending components.

Report naphtha-range hydrocarbons intended for blending or compounding into finished aviation gasoline in product.

Exclude any naphtha-range hydrocarbons from gasoline blending components if the intended end use is other than blending or compounding into finished motor gasoline or finished aviation gasoline (e.g. naphtha intended for use in solvents or as petrochemical feedstocks).

Exclude the following products from motor gasoline blending components.

• normal butane,
• butylene
• isobutane
• isobutylene
• pentanes plus
• fuel ethanol, and
• ETBE.

While these products may be blended into finished motor gasoline, they are reported under separate product. This applies only to unblended products. After blending, butanes, pentanes plus, fuel ethanol, ETBE, and other materials become part of the volume of gasoline blending components or finished motor gasoline.

Note: Certain gasoline blending components may be received as return streams from chemical plants. In this case, it is very important to maintain consistent classification of product produced and shipped from the refinery and received and input at the refinery. For example, a refinery may ship naphtha-range petrochemical feedstocks to a chemical plant and then receive a return stream from the chemical plant that will be used for motor gasoline blending. In this case, the return stream reported must be classified as receipt and input of petrochemical feedstock and then production of gasoline blending components or finished gasoline.

Distillate Fuel Oil

Report refinery input and production during the month and end-of-month stocks of distillate fuel oil by sulphur content.

• Diesel Fuel Oil: ≤ 15ppm sulphur
• Light Fuel Oil: > 15ppm sulphur

Distillate fuel oil 15ppm sulphur and under plus distillate fuel oil greater than 15ppm sulphur must sum to the total for Distillate Fuel Oil.

Residual Fuel Oil by Percent of Sulphur Content

Report refinery input and production during the month and end-of-month stocks of residual fuel oil by sulphur content. (under 1.00% sulphur and over 1.00% sulphur) must sum to the total for Residual Fuel Oil.

Lubricants

Report only lubricant base oils produced at the refinery. Exclude finished lubricants produced at lube plants. Exclude byproducts of lubricating oil refining such as aromatic extracts derived from solvent extraction or tars derived from deasphalting. Reporting categories include:

• Paraffinic. Includes all grades of bright stock and neutrals with a Viscosity Index >75.
• Naphthenic. Includes all lubricating oil base stocks with a Viscosity Index <75.

Note: The criterion for categorizing lubricants is based solely on the Viscosity Index of the stocks and is independent of crude sources and type of processing used to produce the oils.

Exceptions: Lubricating oil base stocks that have been historically classified as naphthenic or paraffinic by a refiner may continue to be so categorized irrespective of the Viscosity Index criterion (e.g., Unextracted paraffinic oils that would not meet the Viscosity Index test).

Report beginning and ending stocks, receipts and shipments of lubricant base oils. Shipments include lubricant base oils blended to produce finished lubricants as well as lubricant base oils shipped out during the month.

Asphalt

Report beginning and ending stocks, receipts and shipments of base asphalt. Shipments include any base asphalt blended to produce finished asphalt and any base asphalt that is sold or shipped out during the month. Do not report water or emulsifiers that are added to base asphalt to produce finished asphalt.

Petrochemical Feedstocks

• Report petrochemical feedstock. Exclude finished petrochemicals.
• Report deliveries of feedstock to petrochemical units within your refinery, chemical or rubber manufacturing plants as shipments.
• Report return streams of petrochemical feedstocks as a receipt and input of petrochemical feedstocks and as a production in the product category of intended use.
• Exclude natural gas liquids (NGL) or liquefied refinery gases (LRG) as petrochemical feedstock. These products are reported by component as ethane, ethylene, propane, propylene, normal butane, butylene, isobutane, isobutylene, and pentanes plus.

Petroleum Coke

Report marketable petroleum coke in cubic metres. One tonne equals 0.46 cubic metres.

Report catalyst coke in fuel oil equivalent cubic metres. The conversion factor is 41.72 gigajoules per fuel oil equivalent cubic metres (higher heating value).

Still Gas

Report still gas shipped to petrochemical facilities as a shipment, less the amount of such streams returned to the producing refinery. Still gas used as a fuel at the refinery should be reported as a fuel use/loss.

Note: Report still gas in fuel oil equivalent cubic metres. The conversion factor is 41.72 gigajoules per fuel oil equivalent cubic metres (higher heating value).

Provisions Regarding Confidentiality of Information and Data Sharing

Confidentiality

Statistics Canada is prohibited by law from releasing any information it collects which could identify any person, business, or organization, unless consent has been given by the respondent or as permitted by the Statistics Act. Statistics Canada will use the information from this study for statistical and research purposes.

Data-sharing agreements

To reduce respondent burden, Statistics Canada has entered into data-sharing agreements with provincial and territorial statistical agencies and other government organizations, which have agreed to keep the data confidential and use them only for statistical purposes. Statistics Canada will only share data from this study with those organizations that have demonstrated a requirement to use the data.