Preliminary Estimate for 2013 and Intentions for 2014
Unified Enterprise Survey - Annual
Reporting Guide
General Instructions
Please report only for the business unit and activity specified on the label.
A. Organization Identification (page 1)
The pre-printed label on page 1 indicates the most current identification of your organization on our files. Please use the appropriate space below the label to make any changes that would reflect a better description of your operations for this particular report.
B. Type of Ownership (page 1)
Ownership is defined as a government entity, person, group of persons, agency or incorporated body controlling more than 50% of the voting rights
Note: Financial assistance (grants, subsidies, etc.) provided by any level of government to an enterprise and/or institution does not necessarily constitute ownership of that organization.
Partnership and joint venture - regarding partnerships and joint venture activities or projects, report the expenditures reflecting your company’s net interest in such projects or ventures.
Canada lands - for this report, the Canada Lands should be assigned as follows:
- Offshore Newfoundland and Labrador is assigned to Newfoundland and Labrador
- Offshore Nova Scotia is assigned to Nova Scotia
- St-Lawrence except offshore Newfoundland and Labrador and offshore Nova Scotia is assigned to Quebec
- Hudson Bay and Strait is assigned to Ontario
- Offshore Pacific is assigned to British Columbia
- Yukon
- Beaufort Sea and Mackenzie Delta assigned to Northwest Territories
- Sverdup Basin, North Stable Platform and Arctic Fold Belts are assigned to Northwest or Nunavut Territories
The Non-Conventional Sector for oil sands relates to operations as defined in the A.E.U.B. Publication Alberta Active Projects - Oil Sands and Heavy Oil Schemes (Catalogue A.E.U.B. ST-97-44). Effectively, these operations take place in the geographical areas of Cold Lake, Peace River, Athabasca, Wabasca and Lindbergh, etc.
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 survey with those organizations that have demonstrated a requirement to use the data.
Section 11 of the Statistics Act provides for the sharing of information with provincial and territorial statistical agencies that meet certain conditions. These agencies must have the legislative authority to collect the same information, on a mandatory basis, and the legislation must provide substantially the same provisions for confidentiality and penalties for disclosure of confidential information as the Statistics Act. Because these agencies have the legal authority to compel businesses to provide the same information, consent is not requested and businesses may not object to the sharing of the data.
For this survey, there are Section 11 agreements with the provincial and territorial statistical agencies of Newfoundland and Labrador, Nova Scotia, New Brunswick, Quebec, Ontario, Manitoba, Saskatchewan, Alberta, British Columbia, and the Yukon.
The shared data will be limited to information pertaining to business establishments located within the jurisdiction of the respective province or territory.
Section 12 of the Statistics Act provides for the sharing of information with federal, provincial or territorial government organizations. Under Section 12, you may refuse to share your information with any of these organizations by writing a letter of objection to the Chief Statistician and returning it with the completed questionnaire. Please specify the organizations with which you do not want to share your data.
For this survey, there are Section 12 agreements with the statistical agencies of Prince Edward Island, the Northwest Territories and Nunavut as well as Natural Resources Canada, Environment Canada, the Newfoundland and Labrador Department of Mines and Energy, the Nova Scotia Department of Natural Resources, the New Brunswick Department of Natural Resources, the Ontario Ministry of Northern Development and Mines, Manitoba Science, Technology Energy and Mines and the British Columbia Ministry of Energy, Mines and Petroleum Resources, and the Saskatchewan Ministry of the Economy.
For agreements with provincial and territorial government organizations, the shared data will be limited to information pertaining to business establishments located within the jurisdiction of the respective province or territory.
Note that there is no right of refusal with respect to sharing the data with the Saskatchewan Ministry of the Economy for businesses also required to report under The Mineral Resources Act (Saskatchewan). The Saskatchewan Ministry of the Economy will use the information obtained from these businesses in accordance with the provisions of their Act.
Fiscal Year End
For the purpose of this survey, please report information for your 12 month fiscal period for which the Final day occurs on or between April 1, 2013 - March 31, 2014 for 2013 and April 1, 2014 - March 31, 2015 for 2014.
The following are acceptable report periods for 2013:
May 2012 - April 2013 (04/13)
June 2012 - May 2013 (05/13)
July 2012 - June 2013 (06/13)
Aug. 2012 - July 2013 (07/13)
Sept. 2012 - Aug. 2013 (08/13)
Oct. 2012 - Sept. 2013 (09/13)
Nov. 2012 - Oct. 2013 (10/13)
Dec. 2012 - Nov. 2013 (11/13)
Jan. 2013 - Dec. 2013 (12/13)
Feb. 2013 - Jan. 2014 (01/14)
March 2013 - Feb. 2014 (02/14)
April 2013 - March 2014 (03/14)
The following are acceptable report periods for 2014:
May 2013 - April 2014 (04/14)
June 2013 - May 2014 (05/14)
July 2013 - June 2014 (06/14)
Aug. 2013 - July 2014 (07/14)
Sept. 2013 - Aug. 2014 (08/14)
Oct. 2013 - Sept. 2014 (09/14)
Nov. 2013 - Oct. 2014 (10/14)
Dec. 2013 - Nov. 2014 (11/14)
Jan. 2014 - Dec. 2014 (12/14)
Feb. 2014 - Jan. 2015 (01/15)
March 2014 - Feb. 2015 (02/15)
April 2014 - March 2015 (03/15)
Definitions
Note:
Syncrude participants: If you are a participant in the Syncrude project, please exclude your participation when filing this report. Arrangements have been made to collect data for this project on a consolidated report.
Regarding partnerships and joint venture activities or projects: report the expenditures reflecting your company’s net interest in such oil sands projects or ventures. Capital expenditures for the Bi-Provincial Upgrader should be included in the schedule.
1. Oil and gas rights acquisition and retention costs (exclude inter-company sales or transfers) includes:
- Acquisition costs and fees for oil and gas rights (include bonuses, legal fees and filing fees)
- Oil and gas rentention costs
2. Cost of land and lease purchased from other petroleum companies: Purchases from companies that are engaged primarily in petroleum activities.
3. Geological and geophysical expenditures: Include such activities as seismic crew expenses, both company owned and contract. Include camp bulldozing and dirt work, flying crews in and out, seismograph, velocity survey, gravity meter, magnetometer, core drilling, photo geological digital processing, magnetic playback and bottom hole contributions and environmental impact studies and other similar pre-exploration expenditures. All seismic or geological and geophysical expenditures (including stratigraphic tests) should be reported here, whether such activity is deemed exploration or development by the company.
** Exploration and development expenditures: Should be reported gross (whether capitalized or expensed) before deducting any incentive grants.
4. 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 cost 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 blowouts, runaways and in replacing damaged equipment.
5. Development drilling: Drilling within the proven area of an oil 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 wells; and wells still in progress at year end, core analysis, logging, road building and other directly related services. Include also costs incurred in fighting blowouts, 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.
6. Production facilities and pre-mining costs: 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 pipeline 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. Include also, overburden removal and other pre-production expenditures as well as, laboratory work, consultants’ fees, performance evaluations and experimental pilot plants (including any capitalized operating costs).
7. Assets other than production facilities (machinery and equipment): Include automotive, airplane, communication, warehouse, dock, office and miscellaneous equipment not otherwise specified. 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.
8. Enhanced recovery projects: Include only expenditures on facilities in tertiary projects involving steam injection, miscible flooding, etc. Include service wells, both tangible and intangible, including the costs of drilling and equipping injection wells and also the cost of capitalized injection fuel (miscible fluid) costs, but exclude non-recoverable injection fluids charged to current operations.
9. Natural gas processing plants: Report only the capitalized amounts of the plants, including structures, measuring, regulating and related equipment. (Please include straddle plants.)
10. Drilling rigs and supply boats: Expenditures (including progress payments) for the purchase of new drilling rigs (on and offshore) and supply boats. Include also those drilling rigs and supply boats imported into Canada (both new and/or used).
11. Office buildings and other structures: Include office buildings and any other closely related structures not included above.
12. Coal bed methane extraction: Report all expenditures related to coal bed methane extraction.
13. Total: The addition of lines 1 to 12.
Year over year variation of capital expenditures
Complete this section only if this report shows significant changes in Total capital expenditures over previous fiscal period. The intent of this section is to reduce possible further inquiries by clarifying the reason(s) for major changes in the capital expenditures reported.
If there has been a launch of a major project or expansion of an existing project, please provide the nature, location, and (if applicable) the name(s) / title(s) of the project in the comment section of the questionnaire.