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C010654 0-57 ferc:DebitedMember 2021-07-01 2021-07-31 C010654 0-17 2021-09-01 2021-09-30 C010654 0-4 2021-09-01 2021-09-30 C010654 0-58 ferc:NegotiatedRateMember 2021-09-01 2021-09-30 C010654 0-3 2021-01-01 2021-09-30 C010654 ferc:OtherUtilityMember 2021-09-30 C010654 ferc:GasUtilityMember ferc:IntangiblePlantMember 2021-01-01 2021-09-30 C010654 0-48 ferc:CreditedMember 2021-09-01 2021-09-30 C010654 ferc:GasUtilityMember ferc:ProcessingPlantMember 2021-01-01 2021-09-30 C010654 0-13 2021-08-01 2021-08-31 C010654 0-27 2020-01-01 2020-09-30 C010654 2021-07-01 2021-07-31 C010654 0-46 ferc:NegotiatedRateMember 2021-09-01 2021-09-30 C010654 0-57 2021-01-01 2021-09-30 C010654 0-1 2021-01-01 2021-09-30 C010654 0-58 2021-09-01 2021-09-30 C010654 0-10 2021-07-01 2021-07-31 C010654 0-56 ferc:DiscountedRateMember 2021-09-01 2021-09-30 C010654 ferc:DiscountedRateMember 2021-09-01 2021-09-30 C010654 0-48 2021-09-01 2021-09-30 C010654 0-16 2021-01-01 2021-09-30 C010654 0-6 2021-01-01 2021-09-30 C010654 0-11 2021-09-01 2021-09-30 C010654 0-16 2021-08-01 2021-08-31 C010654 0-13 2021-01-01 2021-09-30 C010654 ferc:CreditedMember 2021-08-01 2021-08-31 C010654 2021-06-30 C010654 0-47 ferc:NegotiatedRateMember 2021-07-01 2021-07-31 C010654 0-16 2021-01-01 2021-09-30 C010654 0-4 2021-01-01 2021-09-30 C010654 0-48 ferc:DiscountedRateMember 2021-08-01 2021-08-31 C010654 0-29 0 2021-01-01 2021-09-30 C010654 0-3 2021-09-01 2021-09-30 C010654 ferc:RecourseRateMember 2021-09-01 2021-09-30 C010654 0-7 2021-09-01 2021-09-30 C010654 0-4 2021-09-30 C010654 0-5 2021-07-01 2021-09-30 C010654 ferc:WaivedRateMember 2021-07-01 2021-07-31 C010654 ferc:ElectricUtilityMember 2021-09-30 C010654 0-6 2021-07-01 2021-07-31 C010654 0-12 2021-01-01 2021-09-30 C010654 0-9 2021-08-01 2021-08-31 C010654 0-1 2021-09-30 C010654 0-44 2021-07-01 2021-07-31 C010654 0-44 ferc:NegotiatedRateMember 2021-07-01 2021-07-31 C010654 0-45 ferc:RecourseRateMember 2021-08-01 2021-08-31 C010654 2020-01-01 2020-09-30 C010654 0-47 2021-07-01 2021-07-31 C010654 0-47 ferc:DiscountedRateMember 2021-07-01 2021-07-31 C010654 ferc:GasUtilityMember ferc:ProductionAndGatheringPlantMember 2021-01-01 2021-09-30 C010654 0-1 2021-06-30 C010654 0-57 2021-07-01 2021-07-31 C010654 0-47 ferc:WaivedRateMember 2021-07-01 2021-07-31 C010654 ferc:OtherUtilityMember 2020-01-01 2020-09-30 C010654 ferc:GasUtilityMember ferc:UndergroundGasStoragePlantMember 2021-01-01 2021-09-30 C010654 0-10 2021-01-01 2021-09-30 C010654 0-5 2021-08-01 2021-08-31 C010654 0-56 ferc:WaivedRateMember 2021-08-01 2021-08-31 C010654 0-4 2021-07-01 2021-07-31 C010654 0-8 2021-01-01 2021-09-30 C010654 0-48 ferc:DiscountedRateMember 2021-09-01 2021-09-30 C010654 0-1 2021-07-01 2021-09-30 C010654 0-58 ferc:NegotiatedRateMember 2021-08-01 2021-08-31 C010654 0-56 2021-09-01 2021-09-30 C010654 ferc:GasUtilityMember ferc:ProductionPlantManufacturedGasMember 2021-01-01 2021-09-30 C010654 0-58 2021-08-01 2021-08-31 C010654 0-4 2021-06-30 C010654 0-10 2021-09-01 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2021-09-30 C010654 0-5 2020-01-01 2020-09-30 C010654 0-3 2021-08-01 2021-08-31 C010654 0-30 0 2021-01-01 2021-09-30 C010654 0 2021-01-01 2021-09-30 C010654 ferc:DiscountedRateMember 2021-08-01 2021-08-31 C010654 0-48 ferc:NegotiatedRateMember 2021-08-01 2021-08-31 C010654 0-5 2021-01-01 2021-09-30 C010654 0-12 2021-08-01 2021-08-31 C010654 0-7 2021-09-30 C010654 2021-07-01 2021-09-30 C010654 0-14 2021-07-01 2021-07-31 C010654 0-12 2021-07-01 2021-07-31 C010654 0-7 2021-01-01 2021-09-30 C010654 2021-09-30 C010654 0-15 0 2021-01-01 2021-09-30 C010654 0-4 2021-07-01 2021-07-31 C010654 0-1 2021-09-30 C010654 ferc:GasUtilityMember ferc:OtherStoragePlantMember 2021-01-01 2021-09-30 C010654 ferc:DebitedMember 2021-07-01 2021-07-31 C010654 0-10 2021-01-01 2021-09-30 C010654 0-13 2021-09-01 2021-09-30 C010654 0-56 2021-07-01 2021-07-31 C010654 0-47 2021-01-01 2021-09-30 C010654 ferc:GasUtilityMember ferc:GeneralPlantMember 2021-01-01 2021-09-30 C010654 ferc:NegotiatedRateMember 2021-08-01 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ferc:NegotiatedRateMember 2021-07-01 2021-07-31 C010654 0-47 ferc:CreditedMember 2021-07-01 2021-07-31 C010654 0-48 ferc:WaivedRateMember 2021-08-01 2021-08-31 C010654 ferc:DebitedMember 2021-08-01 2021-08-31 C010654 0-56 ferc:DebitedMember 2021-09-01 2021-09-30 C010654 0-48 ferc:DebitedMember 2021-09-01 2021-09-30 C010654 ferc:GasUtilityMember 2020-01-01 2020-09-30 C010654 0-58 ferc:DiscountedRateMember 2021-09-01 2021-09-30 C010654 0-48 2021-01-01 2021-09-30 C010654 0-48 ferc:WaivedRateMember 2021-09-01 2021-09-30 C010654 0-58 ferc:CreditedMember 2021-09-01 2021-09-30 C010654 0-7 2021-07-01 2021-09-30 C010654 ferc:GasUtilityMember ferc:DistributionPlantMember 2021-01-01 2021-09-30 C010654 0-56 ferc:RecourseRateMember 2021-08-01 2021-08-31 C010654 0-56 2021-01-01 2021-09-30 C010654 0-12 2021-01-01 2021-09-30 C010654 ferc:GasUtilityMember ferc:TransmissionPlantMember 2021-01-01 2021-09-30 C010654 0-10 2020-01-01 2020-09-30 C010654 0-7 2021-07-01 2021-07-31 C010654 0-4 2021-09-01 2021-09-30 C010654 0-58 ferc:RecourseRateMember 2021-08-01 2021-08-31 C010654 ferc:WaivedRateMember 2021-09-01 2021-09-30 C010654 0-6 2021-01-01 2021-09-30 C010654 0-48 ferc:CreditedMember 2021-08-01 2021-08-31 C010654 0-16 0 2021-01-01 2021-09-30 C010654 0-57 ferc:CreditedMember 2021-07-01 2021-07-31 C010654 0-58 ferc:CreditedMember 2021-08-01 2021-08-31 C010654 0-5 2021-09-01 2021-09-30 C010654 0-7 2021-08-01 2021-08-31 C010654 0-44 ferc:CreditedMember 2021-07-01 2021-07-31 C010654 0-3 2021-07-01 2021-07-31 C010654 0-44 ferc:DebitedMember 2021-07-01 2021-07-31 C010654 0-58 2021-01-01 2021-09-30 C010654 0-16 2021-09-01 2021-09-30 C010654 0-15 2021-09-01 2021-09-30 C010654 0-46 2021-01-01 2021-09-30 C010654 ferc:CreditedMember 2021-07-01 2021-07-31 C010654 ferc:GasUtilityMember ferc:CommonPlantGasMember 2021-01-01 2021-09-30 C010654 0-6 2021-09-01 2021-09-30 C010654 0-3 2021-09-01 2021-09-30 C010654 0-47 2020-01-01 2020-09-30 C010654 0-46 ferc:DebitedMember 2021-09-01 2021-09-30 C010654 0-3 2021-06-30 C010654 0-5 2021-01-01 2021-09-30 C010654 0-58 ferc:RecourseRateMember 2021-09-01 2021-09-30 C010654 0-12 2020-01-01 2020-09-30 C010654 0-15 2021-01-01 2021-09-30 C010654 0-14 2021-01-01 2021-09-30 C010654 ferc:NegotiatedRateMember 2021-07-01 2021-07-31 C010654 2021-09-01 2021-09-30 C010654 0-9 2021-09-01 2021-09-30 C010654 0-56 2020-01-01 2020-09-30 C010654 0-5 2021-07-01 2021-07-31 C010654 0-2 2021-01-01 2021-09-30 C010654 0-47 ferc:RecourseRateMember 2021-07-01 2021-07-31 C010654 0-44 ferc:RecourseRateMember 2021-07-01 2021-07-31 C010654 0-44 ferc:WaivedRateMember 2021-07-01 2021-07-31 C010654 2020-12-31 C010654 0-6 2020-01-01 2020-09-30 C010654 0-1 2021-07-01 2021-09-30 C010654 0-58 ferc:WaivedRateMember 2021-08-01 2021-08-31 C010654 0-5 2021-06-30 C010654 ferc:ElectricUtilityMember 2020-01-01 2020-09-30 C010654 0-9 2021-07-01 2021-07-31 C010654 0-11 2021-01-01 2021-09-30 C010654 0-16 2021-07-01 2021-07-31 C010654 0-45 2021-08-01 2021-08-31 C010654 0-58 2021-01-01 2021-09-30 C010654 0-3 2021-07-01 2021-09-30 C010654 ferc:NegotiatedRateMember 2021-09-01 2021-09-30 C010654 0-56 2021-01-01 2021-09-30 C010654 0-14 2021-09-01 2021-09-30 C010654 0-56 ferc:CreditedMember 2021-07-01 2021-07-31 C010654 0-1 2021-01-01 2021-09-30 C010654 0-47 2021-01-01 2021-09-30 C010654 0-56 ferc:NegotiatedRateMember 2021-09-01 2021-09-30 C010654 0-10 2021-08-01 2021-08-31 C010654 0-6 2021-06-30 C010654 0-15 2021-08-01 2021-08-31 C010654 0-45 ferc:NegotiatedRateMember 2021-08-01 2021-08-31 C010654 0-46 2021-09-01 2021-09-30 C010654 0-56 ferc:DiscountedRateMember 2021-07-01 2021-07-31 C010654 0-1 2021-06-30 C010654 0-4 2021-07-01 2021-09-30 C010654 0-12 2021-09-01 2021-09-30 C010654 ferc:GasUtilityMember ferc:BaseLoadLngTerminalingAndProcessingPlantMember 2021-01-01 2021-09-30 C010654 0-8 2021-01-01 2021-09-30 C010654 0-27 2021-01-01 2021-09-30 C010654 0-4 2021-08-01 2021-08-31 C010654 0-7 2021-01-01 2021-09-30 C010654 0-46 ferc:RecourseRateMember 2021-09-01 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THIS FILING IS
Item 1:
An Initial (Original) Submission
OR
Resubmission No.

FERC FINANCIAL REPORT
FERC FORM No. 2: Annual Report of
Major Natural Gas Companies and
Supplemental Form 3-Q: Quarterly
Financial Report

These reports are mandatory under the Natural Gas Act, Sections 10(a), and 16 and 18 CFR Parts 260.1 and 260.300. Failure to report may result in criminal fines, civil penalties, and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of a confidential nature.
Exact Legal Name of Respondent (Company)

Algonquin Gas Transmission, LLC
Year/Period of Report:

End of:
2021
/
Q3


INSTRUCTIONS FOR FILING FERC FORMS 2, 2-A and 3-Q

GENERAL INFORMATION

  1. Purpose

    FERC Forms 2, 2-A, and 3-Q are designed to collect financial and operational information from natural gas companies subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be a non-confidential public use forms.
  2. Who Must Submit

    Each natural gas company whose combined gas transported or stored for a fee exceed 50 million dekatherms in each of the previous three years must submit FERC Form 2 and 3-Q.

    Each natural gas company not meeting the filing threshold for FERC Form 2, but having total gas sales or volume transactions exceeding 200,000 dekatherms in each of the previous three calendar years must submit FERC Form 2-A and 3-Q.

    Newly established entities must use projected data to determine whether they must file the FERC Form 3-Q and FERC Form 2 or 2-A.
  3. What and Where to Submit

    1. Submit Forms 2, 2-A and 3-Q electronically through the submission software at http://www.ferc.gov/docs-filing/eforms/form-2/elec-subm-soft.asp .
    2. The Corporate Officer Certification must be submitted electronically as part of the FERC Form 2 and 3-Q filings.
    3. Submit immediately upon publication, by either eFiling or mailing two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders and any annual financial or statistical report regularly prepared and distributed to bondholders, security analysts, or industry associations. Do not include monthly and quarterly reports. Indicate by checking the appropriate box on Form 2, Page 3, List of Schedules, if the reports to stockholders will be submitted or if no annual report to stockholders is prepared. Unless eFiling the Annual Report to Stockholders, mail these reports to the Secretary of the Commission at:

      Secretary of the Commission
      Federal Energy Regulatory Commission
      888 First Street, NE
      Washington, DC 20426
    4. For the Annual CPA certification, submit with the original submission of this form, a letter or report (not applicable to respondents classified as Class C or Class D prior to January 1, 1984) prepared in conformity with the current standards of reporting which will:
      1. Contain a paragraph attesting to the conformity, in all material respects, of the schedules listed below with the Commission's applicable Uniform Systems of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and
      2. be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 158.10-158.12 for specific qualifications.)

        Reference
        Reference Schedules Pages
        Comparative Balance Sheet 110-113
        Statement of Income 114-117
        Statement of Retained Earnings 118-119
        Statement of Cash Flows 120-121
        Notes to Financial Statements 122-123
      Filers should state in the letter or report, which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist
    5. Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. To further that effort, new selections, “Annual Report to Stockholders” and “CPA Certification Statement,” have been added to the dropdown “pick list” from which companies must choose when eFiling. Further instructions are found on the Commission website at http://www.ferc.gov/help/how-to.asp.
    6. Federal, State and Local Governments and other authorized users may obtain additional blank copies of FERC Form 2 and 2-A free of charge from: http://www.ferc.gov/docs-filing/forms/form-2/form-2.pdf and http://www.ferc.gov/docs-filing/forms/form-2a/form-2a.pdf, respectively. Copies may also be obtained from the Public Reference and Files Maintenance Branch, Federal Energy Regulatory Commission, 888 First Street, NE. Room 2A, Washington, DC 20426 or by calling (202).502-8371
  4. When to Submit:

    FERC Forms 2, 2-A, and 3-Q must be filed by the dates:

    1. FERC Form 2 and 2-A --- by April 18th of the following year (18 C.F.R. §§ 260.1 and 260.2)
    2. FERC Form 3-Q --- Natural gas companies that file a FERC Form 2 must file the FERC Form 3-Q within 60 days after the reporting quarter (18 C.F.R.§ 260.300), and
    3. FERC Form 3-Q --- Natural gas companies that file a FERC Form 2-A must file the FERC Form 3-Q within 70 days after the reporting quarter (18 C.F.R. § 260.300).
  5. Where to Send Comments on Public Reporting Burden.

    The public reporting burden for the Form 2 collection of information is estimated to average 1,623 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the Form 2A collection of information is estimated to average 250 hours per response. The public reporting burden for the Form 3-Q collection of information is estimated to average 167 hours per response.

    Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

  1. Prepare all reports in conformity with the Uniform System of Accounts (USofA) (18 C.F.R. Part 201). Interpret all accounting words and phrases in accordance with the USofA.
  2. Enter in whole numbers (dollars or Dth) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
  3. Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
  4. For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
  5. Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions.
  6. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
  7. For any resubmissions, submit the electronic filing using the form submission only. Please explain the reason for the resubmission in a footnote to the data field.
  8. Footnote and further explain accounts or pages as necessary.
  9. Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
  10. Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
  11. Report all gas volumes in Dth unless the schedule specifically requires the reporting in another unit of measurement.

DEFINITIONS
  1. Btu per cubic foot – The total heating value, expressed in Btu, produced by the combustion, at constant pressure, of the amount of the gas which would occupy a volume of 1 cubic foot at a temperature of 60°F if saturated with water vapor and under a pressure equivalent to that of 30°F, and under standard gravitational force (980.665 cm. per sec) with air of the same temperature and pressure as the gas, when the products of combustion are cooled to the initial temperature of gas and air when the water formed by combustion is condensed to the liquid state (called gross heating value or total heating value).
  2. Commission Authorization -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
  3. Dekatherm – A unit of heating value equivalent to 10 therms or 1,000,000 Btu.
  4. Respondent – The person, corporation, licensee, agency, authority, or other legal entity or instrumentality on whose behalf the report is made.

EXCERPTS FROM THE LAW

Natural Gas Act, 15 U.S.C. 717-717w

"Sec. 10(a). Every natural-gas company shall file with the Commission such annual and other periodic or special reports as the Commission may by rules and regulations or order prescribe as necessary or appropriate to assist the Commission in the proper administration of this act. The Commission may prescribe the manner and form in which such reports shall be made and require from such natural-gas companies specific answers to all questions upon which the Commission may need information. The Commission may require that such reports include, among other things, full information as to assets and liabilities, capitalization, investment and reduction thereof, gross receipts, interest dues and paid, depreciation, amortization, and other reserves, cost of facilities, costs of maintenance and operation of facilities for the production, transportation, delivery, use, or sale of natural gas, costs of renewal and replacement of such facilities, transportation, delivery, use and sale of natural gas..."

"Section 16. The Commission shall have power to perform all and any acts, and to prescribe, issue, make, amend, and rescind such orders, rules, and regulations as it may find necessary or appropriate to carry out the provisions of this act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this act; and may prescribe the form or forms of all statements declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and time within they shall be filed..."

General Penalties

The Commission may assess up to $1 million per day per violation of its rules and regulations. See NGA § 22(a), 15 U.S.C. §717t-1(a).


FERC FORM NO.
2/3-Q

REPORT OF MAJOR NATURAL GAS COMPANIES
IDENTIFICATION
01 Exact Legal Name of Respondent

Algonquin Gas Transmission, LLC
02 Year/ Period of Report


End of:
2021
/
Q3
03 Previous Name and Date of Change (if name changed during year)

Gas R Us
/
01/01/1998
04 Address of Principal Office at End of Year (Street, City, State, Zip Code)

5400 Westheimer Court, Houston Texas 77056-5310
05 Name of Contact Person

Kellye L. Mathis
06 Title of Contact Person

Director of UST Accounting
07 Address of Contact Person (Street, City, State, Zip Code)

5400 Westheimer Court, Houston Texas 77056-5310
08 Telephone of Contact Person, Including Area Code

713-627-4451
09 This Report is An Original / A Resubmission

(1)
An Original

(2)
A Resubmission
10 Date of Report (Mo, Da, Yr)

11/30/2021
QUARTERLY CORPORATE OFFICER CERTIFICATION
The undersigned officer certifies that:
I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.



11 Name

Stephen J. Neyland
12 Title

Vice President - Finance
13 Signature

/s/ Stephen J. Neyland
14 Date Signed

11/30/2021
Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.



Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
List of Schedules (Natural Gas Company)
Enter in column (d) the terms "none," "not applicable," or "NA" as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the responses are "none," "not applicable," or "NA."
Line No.
Title of Schedule
(a)
Reference Page No.
(b)
Date Revised
(c)
Remarks
(d)
ScheduleIdentificationAbstract Identification 1
02-04
ScheduleListOfSchedulesAbstract List of Schedules (Natural Gas Campnay) 2
REV 12-07
GeneralCorporateInformationAndFinancialStatementsAbstract GENERAL CORPORATE INFORMATION AND FINANCIAL STATEMENTS
1
ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year 108
12-96
2
ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet
REV 06-04
ScheduleComparativeBalanceSheetAssetsAndOtherDebitsAbstract Comparative Balance Sheet (Assets And Other Debits) 110
REV 06-04
ScheduleComparativeBalanceSheetLiabilitiesOtherCreditsAbstract Comparative Balance Sheet (Liabilities and Other Credits) 112
REV 06-04
3
ScheduleStatementOfIncomeAbstract Statement of Income for the Year 114
REV 06-04
4
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accumulated Comprehensive Income and Hedging Activities 117
NEW 06-02
5
ScheduleStatementOfRetainedEarningsAbstract Statement of Retained Earnings for the Year 118
REV 06-04
6
ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows 120
REV 06-04
7
ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements 122.1
REV 12-07
BalanceSheetSupportingSchedulesAbstract BALANCE SHEET SUPPORTING SCHEDULES
8
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization, and Depletion 200
12-96
9
ScheduleGasPlantInServiceAndAccumulatedProvisionForDepreciationByFunctionAbstract Gas Plant in Service and Accumulated Provision for Depreciation by Function 210
NEW 06-04
10
ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets 232
REV 12-07
11
ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities 278
REV 12-07
AccessoryElectricEquipmentNuclearProductionAbstract INCOME ACCOUNT SUPPORTING SCHEDULES
12
ScheduleMonthlyQuantityRevenueDataByRateScheduleAbstract Monthly Quantity & Revenue Data 299
NEW 12-08
13
ScheduleNaturalGasCompanyGasRevenuesAndDekathermsAbstract Natural Gas Company- Gas Revenues and Dekatherms 309
NEW 12-97
14
ScheduleGasProductionAndOtherGasSupplyExpensesAbstract Gas Production and Other Gas Supply Expenses 310
NEW 06-04
15
ScheduleNaturalGasStorageTerminalingProcessingServicesAbstract Natural Gas Storage, Terminaling, Processing Services 311
NEW 06-04
16
ScheduleGasCustomerAccountsServiceSalesAdministrativeAndGeneralExpensesAbstract Gas Customer Accounts, Service, Sales, Administrative and General Expenses 312
NEW 06-04
17
ScheduleDepreciationDepletionAndAmortization2QAbstract Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 403.1, 404.1, 404.2, 404.3, 405) (Except Amort of Acqusition Adjustments) 339
NEW 06-04
StatisticalDataAbstract GAS PLANT STATISTICAL DATA
18
ScheduleGasAccountNaturalGasAbstract Gas Account - Natural Gas 520
REV 01-11
19
ScheduleShipperSuppliedGasForTheCurrentQuarterAbstract Shipper Supplied Gas for the Current Quarter 521
REVISED 02-11


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Important Changes During the Year
Give details concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Answer each inquiry. Enter "none" or "not applicable" where applicable. If the answer is given elsewhere in the report, refer to the schedule in which it appears.
  1. Changes in and important additions to franchise rights: Describe the actual consideration and state from whom the franchise rights were acquired. If the franchise rights were acquired without the payment of consideration, state that fact.
  2. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization.
  3. Purchase or sale of an operating unit or system: Briefly describe the property, and the related transactions, and cite Commission authorization, if any was required. Give date journal entries called for by Uniform System of Accounts were submitted to the Commission.
  4. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other conditions. State name of Commission authorizing lease and give reference to such authorization.
  5. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and cite Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc.
  6. Obligations incurred or assumed by respondent as guarantor for the performance by another of any agreement or obligation, including ordinary commercial paper maturing on demand or not later than one year after date of issue: State on behalf of whom the obligation was assumed and amount of the obligation. Cite Commission authorization if any was required.
  7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments.
  8. State the estimated annual effect and nature of any important wage scale changes during the year.
  9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year.
  10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest.
  11. Estimated increase or decrease in annual revenues caused by important rate changes: State effective date and approximate amount of increase or decrease for each revenue classification. State the number of customers affected.
  12. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period.
  13. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.

1. None

 

2. None

 

3. None

 

4. None

 

5. None

6. None

7.  None

8. None

9. None

10. None

11. None

12. Uses the officers of its Managing Member, Spectra Algonquin Holdings, LLC

None



Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Comparative Balance Sheet (Assets And Other Debits)
Line No.
Title of Account
(a)
Reference Page Number
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlant
Utility Plant (101-106, 114)
200-201
1,787,882,020
1,792,364,616
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200-201
1,759,554
1,420,955
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Total of lines 2 and 3)
200-201
1,789,641,574
1,793,785,571
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Provision for Depr., Amort., Depl. (108, 111, 115)
670,943,961
653,011,423
6
UtilityPlantNet
Net Utility Plant (Total of line 4 less 5)
1,118,697,613
1,140,774,148
7
NuclearFuel
Nuclear Fuel (120.1 thru 120.4, and 120.6)
1,000,000
1,000,000
8
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies
(Less) Accum. Provision for Amort., of Nuclear Fuel Assemblies (120.5)
1,000,000
1,000,000
9
NuclearFuelNet
Nuclear Fuel (Total of line 7 less 8)
0
0
10
UtilityPlantAndNuclearFuelNet
Net Utility Plant (Total of lines 6 and 9)
1,118,697,613
1,140,774,148
11
OtherGasPlantAdjustments
Utility Plant Adjustments (116)
122
1,000,000
1,000,000
12
GasStoredBaseGas
Gas Stored-Base Gas (117.1)
220
0
0
13
SystemBalancingGas
System Balancing Gas (117.2)
220
0
0
14
GasStoredInReservoirsAndPipelinesNoncurrent
Gas Stored in Reservoirs and Pipelines-Noncurrent (117.3)
220
0
0
15
GasOwedToSystemGas
Gas Owed to System Gas (117.4)
220
226,964
956,669
16
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
17
NonutilityProperty
Nonutility Property (121)
1,500,509
1,500,509
18
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Provision for Depreciation and Amortization (122)
1,497,918
1,497,782
19
InvestmentInAssociatedCompanies
Investments in Associated Companies (123)
222-223
46,457,318
2,439,529
20
InvestmentInSubsidiaryCompanies
Investments in Subsidiary Companies (123.1)
224-225
168,637,185
170,182,580
22
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
1,000,000
1,000,000
23
OtherInvestments
Other Investments (124)
222-223
47,457,318
3,439,529
24
SinkingFunds
Sinking Funds (125)
1,000,000
1,000,000
25
DepreciationFund
Depreciation Fund (126)
1,000,000
1,000,000
26
AmortizationFundFederal
Amortization Fund - Federal (127)
1,000,000
1,000,000
27
OtherSpecialFunds
Other Special Funds (128)
13,795,634
14,271,407
28
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
1,000,000
1,000,000
29
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
1,000,000
1,000,000
30
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Total of lines 17-20, 22-29)
282,350,046
196,335,772
31
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
32
Cash
Cash (131)
1,000,000
1,000,000
33
SpecialDeposits
Special Deposits (132-134)
1,000,000
1,000,000
34
WorkingFunds
Working Funds (135)
1,000,000
1,000,000
35
TemporaryCashInvestments
Temporary Cash Investments (136)
222-223
47,457,318
3,439,529
36
NotesReceivable
Notes Receivable (141)
1,000,000
1,000,000
37
CustomerAccountsReceivable
Customer Accounts Receivable (142)
33,342,686
33,593,615
38
OtherAccountsReceivable
Other Accounts Receivable (143)
74,555
132,651
39
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Provision for Uncollectible Accounts - Credit (144)
1,000,000
1,000,000
40
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
1,000,000
1,000,000
41
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Associated Companies (146)
174,275
505,909
42
FuelStock
Fuel Stock (151)
1,000,000
1,000,000
43
FuelStockExpensesUndistributed
Fuel Stock Expenses Undistributed (152)
1,000,000
1,000,000
44
ResidualsAndExtractedProducts
Residuals (Elec) and Extracted Products (Gas) (153)
127,723
132,822
45
PlantMaterialsAndOperatingSupplies
Plant Materials and Operating Supplies (154)
5,209,861
5,344,684
46
Merchandise
Merchandise (155)
1,000,000
1,000,000
47
OtherMaterialsAndSupplies
Other Materials and Supplies (156)
1,000,000
1,000,000
48
NuclearMaterialsHeldForSale
Nuclear Materials Held for Sale (157)
1,000,000
1,000,000
49
AllowanceInventoryAndWithheld
Allowances (158.1 and 158.2)
1,000,000
1,000,000
50
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
1,000,000
1,000,000
51
StoresExpenseUndistributed
Stores Expense Undistributed (163)
1,000,000
1,000,000
52
GasStoredCurrent
Gas Stored Underground-Current (164.1)
220
0
0
53
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2 thru 164.3)
220
4,000,000
2,000,000
54
Prepayments
Prepayments (165)
230
9,968,081
8,543,432
55
AdvancesForGas
Advances for Gas (166 thru 167)
1,000,000
1,000,000
56
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
1,000,000
1,000,000
57
RentsReceivable
Rents Receivable (172)
1,000,000
1,000,000
58
AccruedUtilityRevenues
Accrued Utility Revenues (173)
1,000,000
1,000,000
59
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
7,061,188
3,557,818
60
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
1,000,000
1,000,000
61
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
1,000,000
1,000,000
62
DerivativeInstrumentAssetsHedges
Derivative Instrument Assets - Hedges (176)
1,000,000
1,000,000
63
DerivativeInstrumentAssetsHedgesLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
1,000,000
1,000,000
64
CurrentAndAccruedAssets
TOTAL Current and Accrued Assets (Total of lines 32 thru 63)
121,415,687
71,250,460
65
DeferredDebitsAbstract
DEFERRED DEBITS
66
UnamortizedDebtExpense
Unamortized Debt Expense (181)
2,806,937
2,806,937
67
ExtraordinaryPropertyLosses
Extraordinary Property Losses (182.1)
230
2,000
0
68
UnrecoveredPlantAndRegulatoryStudyCosts
Unrecovered Plant and Regulatory Study Costs (182.2)
230
2,000,000
2,000,000
69
OtherRegulatoryAssets
Other Regulatory Assets (182.3)
232
10,276,487
9,194,807
70
PreliminarySurveyAndInvestigationCharges
Preliminary Survey and Investigation Charges (Electric)(183)
1,000,000
1,000,000
71
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges
Preliminary Survey and Investigation Charges (Gas)(183.1 and 183.2)
1,000,000
1,000,000
72
ClearingAccounts
Clearing Accounts (184)
1,000,000
1,000,000
73
TemporaryFacilities
Temporary Facilities (185)
1,000,000
1,000,000
74
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
86,828,663
76,401,871
75
DeferredLossesFromDispositionOfUtilityPlant
Deferred Losses from Disposition of Utility Plant (187)
1,000,000
1,000,000
76
ResearchDevelopmentAndDemonstrationExpenditures
Research, Development, and Demonstration Expend. (188)
1,000,000
1,000,000
77
UnamortizedLossOnReacquiredDebt
Unamortized Loss on Reacquired Debt (189)
1,000,000
1,000,000
78
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234-235
12,203,900
109,054,024
79
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
1,000,000
1,000,000
80
DeferredDebits
TOTAL Deferred Debits (Total of lines 66 thru 79)
122,113,987
207,457,639
81
AssetsAndOtherDebits
TOTAL Assets and Other Debits (Total of lines 10-15,30,64,and 80)
1,645,350,369
1,615,861,350


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Comparative Balance Sheet (Liabilities and Other Credits)
Line No.
Title of Account
(a)
Reference Page Number
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
ProprietaryCapitalAbstract
PROPRIETARY CAPITAL
2
CommonStockIssued
Common Stock Issued (201)
250-251
2,000,000
1,000,000
3
PreferredStockIssued
Preferred Stock Issued (204)
250-251
20,000,000
1,000,000
4
CapitalStockSubscribed
Capital Stock Subscribed (202, 205)
252
1,000,000
1,000,000
5
StockLiabilityForConversion
Stock Liability for Conversion (203, 206)
252
1,000,000
1,000,000
6
PremiumOnCapitalStock
Premium on Capital Stock (207)
252
20,000
1,000,000
7
OtherPaidInCapital
Other Paid-In Capital (208-211)
253
1,038,731,842
999,824,187
8
InstallmentsReceivedOnCapitalStock
Installments Received on Capital Stock (212)
252
20,000
1,000,000
9
DiscountOnCapitalStock
(Less) Discount on Capital Stock (213)
254
2,000,000
1,000,000
10
CapitalStockExpense
(Less) Capital Stock Expense (214)
254
2,000,000
1,000,000
11
RetainedEarnings
Retained Earnings (215, 215.1, 216)
118-119
153,965,437
171,769,527
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118-119
2,653,013
2,330,902
13
ReacquiredCapitalStock
(Less) Reacquired Capital Stock (217)
250-251
1,000,000
1,000,000
14
AccumulatedOtherComprehensiveIncome
Accumulated Other Comprehensive Income (219)
117
6,000,000
6,000,000
15
ProprietaryCapital
TOTAL Proprietary Capital (Total of lines 2 thru 14)
1,220,390,292
1,182,924,616
16
LongTermDebtAbstract
LONG TERM DEBT
17
Bonds
Bonds (221)
256-257
475,000,000
475,000,000
18
ReacquiredBonds
(Less) Reacquired Bonds (222)
256-257
2,000,000
1,000,000
19
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256-257
2,000,000
1,000,000
20
OtherLongTermDebt
Other Long-Term Debt (224)
256-257
2,000,000
1,000,000
21
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
258-259
1,000,000
1,000,000
22
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Dr (226)
258-259
807,853
807,853
23
CurrentPortionOfLongTermDebt
(Less) Current Portion of Long-Term Debt
1,000,000
1,000,000
24
LongTermDebt
TOTAL Long-Term Debt (Total of lines 17 thru 23)
476,192,147
475,192,147
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases-Noncurrent (227)
296,738,107
304,401,330
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
1,000,000
1,000,000
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
1,000,000
1,000,000
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
1,000,000
1,000,000
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
1,000,000
1,000,000
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
1,000,000
1,000,000
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
1,000,000
1,000,000
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
1,000,000
1,000,000
34
AssetRetirementObligations
Asset Retirement Obligations (230)
233,109
257,707
35
OtherNoncurrentLiabilities
TOTAL Other Noncurrent Liabilities (Total of lines 26 thru 34)
303,971,216
311,659,037
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
CurrentPortionOfLongTermDebt
Current Portion of Long-Term Debt
1,000,000
1,000,000
38
NotesPayable
Notes Payable (231)
1,000,000
1,000,000
39
AccountsPayable
Accounts Payable (232)
6,792,902
4,615,489
40
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
1,000,000
1,000,000
41
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
11,308,528
6,562,169
42
CustomerDeposits
Customer Deposits (235)
14,361,060
382,572
43
TaxesAccrued
Taxes Accrued (236)
262-263
49,626,733
49,651,472
44
InterestAccrued
Interest Accrued (237)
6,121,354
6,121,354
45
DividendsDeclared
Dividends Declared (238)
1,000,000
1,000,000
46
MaturedLongTermDebt
Matured Long-Term Debt (239)
1,000,000
1,000,000
47
MaturedInterest
Matured Interest (240)
1,000,000
1,000,000
48
TaxCollectionsPayable
Tax Collections Payable (241)
9
5
49
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
268
6,837,095
2,926,302
50
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
11,419,357
11,316,097
51
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
1,000,000
1,000,000
52
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
1,000,000
1,000,000
53
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
1,000,000
1,000,000
54
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities - Hedges
1,000,000
1,000,000
55
CurrentAndAccruedLiabilities
TOTAL Current and Accrued Liabilities (Total of lines 37 thru 54)
112,467,038
87,575,460
56
DeferredCreditsAbstract
DEFERRED CREDITS
57
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
6,545,168
4,289,850
58
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
1,000,000
1,000,000
59
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
1,000,000
1,000,000
60
OtherDeferredCredits
Other Deferred Credits (253)
269
1,274,177
1,252,265
61
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
34,057,809
32,040,179
62
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reacquired Debt (257)
260
1,000,000
1,000,000
63
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accumulated Deferred Income Taxes - Accelerated Amortization (281)
1,000,000
1,000,000
64
AccumulatedDeferredIncomeTaxesOtherProperty
Accumulated Deferred Income Taxes - Other Property (282)
480,203,202
463,732,770
65
AccumulatedDeferredIncomeTaxesOther
Accumulated Deferred Income Taxes - Other (283)
14,142,933
13,854,489
66
DeferredCredits
TOTAL Deferred Credits (Total of lines 57 thru 65)
540,223,289
519,169,553
67
LiabilitiesAndOtherCredits
TOTAL Liabilities and Other Credits (Total of lines 15,24,35,55,and 66)
2,653,243,982
2,576,520,813


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Statement of Income
Quarterly
  1. Enter in column (d) the balance for the reporting quarter and in column (e) the balance for the same three month period for the prior year.
  2. Report in column (f) the quarter to date amounts for electric utility function; in column (h) the quarter to date amounts for gas utility, and in (j) the quarter to date amounts for other utility function for the current year quarter.
  3. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in (k) the quarter to date amounts for other utility function for the prior year quarter.
  4. If additional columns are needed place them in a footnote.

Annual or Quarterly, if applicable
  1. Do not report fourth quarter data in columns (e) and (f)
  2. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility columnin a similar manner to a utility department. Spread the amount(s) over lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals.
  3. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above.
  4. Report data for lines 8, 10 and 11 for Natural Gas companies using accounts 404.1, 404.2, 404.3, 407.1 and 407.2.
  5. Use page 122 for important notes regarding the statement of income for any account thereof.
  6. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases.
  7. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purches, and a summary of the adjustments made to balance sheet, income, and expense accounts.
  8. If any notes appearing in the report to stokholders are applicable to the Statement of Income, such notes may be included at page 122.
  9. Enter on page 122 a concise explanation of only those changes in accounting mehods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes.
  10. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports.
  11. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.
Title of Account
(a)
Reference Page Number
(b)
Total Current Year to Date Balance for Quarter/Year
(c)
Total Prior Year to Date Balance for Quarter/Year
(d)
Current Three Months Ended Quarterly Only No Fourth Quarter
(e)
Prior Three Months Ended Quarterly Only No Fourth Quarter
(f)
Elec. Utility Current Year to Date (in dollars)
(g)
Elec. Utility Previous Year to Date (in dollars)
(h)
Gas Utiity Current Year to Date (in dollars)
(i)
Gas Utility Previous Year to Date (in dollars)
(j)
Other Utility Current Year to Date (in dollars)
(k)
Other Utility Previous Year to Date (in dollars)
(l)
1
UtilityOperatingIncomeAbstract
UTILITY OPERATING INCOME
2
OperatingRevenues
Gas Operating Revenues (400)
300-301
11,000,000
125,502,224
1,000,000
1,000,000
132,345,657
125,502,224
1,000,000
1,000,000
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
317-325
135,266,112
137,104,354
1,000,000
1,000,000
219,269,112
220,104,354
1,000,000
1,000,000
5
MaintenanceExpense
Maintenance Expenses (402)
317-325
13,733,924
14,241,820
1,000,000
1,000,000
59,733,924
60,241,820
1,000,000
1,000,000
6
DepreciationExpense
Depreciation Expense (403)
336-338
30,098,846
30,717,800
1,000,000
1,000,000
30,098,846
30,717,800
1,000,000
1,000,000
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336-338
366
436
1,000,000
1,000,000
1,000,166
436
1,000,000
1,000,000
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336-338
528,457
414,093
1,000,000
1,000,000
4,400,000
414,093
1,000,000
1,000,000
9
AmortizationOfGasPlantAcquisitionAdjustments
Amortization of Utility Plant Acu. Adjustment (406)
336-338
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
10
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts
Amort. of Prop. Losses, Unrecovered Plant and Reg. Study Costs (407.1)
3,281,566
3,281,566
1,000,000
1,000,000
3,281,566
3,281,566
1,000,000
1,000,000
11
AmortizationOfConversionExpenses
Amortization of Conversion Expenses (407.2)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
12
RegulatoryDebits
Regulatory Debits (407.3)
7,463,807
9,816,173
1,000,000
1,000,000
7,463,807
9,816,173
1,000,000
1,000,000
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
5,258,065
5,894,259
1,000,000
1,000,000
5,258,065
5,894,259
1,000,000
1,000,000
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262-263
18,111,387
20,699,981
1,000,000
1,000,000
18,111,387
20,699,981
1,000,000
1,000,000
15
IncomeTaxesUtilityOperatingIncome
Income Taxes-Federal (409.1)
262-263
12,599,773
14,016,373
1,000,000
1,000,000
12,599,773
14,016,373
1,000,000
1,000,000
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes-Other (409.1)
262-263
3,859,508
2,990,621
1,000,000
1,000,000
3,859,508
2,990,621
1,000,000
1,000,000
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision of Deferred Income Taxes (410.1)
234-235
10,312,302
19,015,966
1,000,000
1,000,000
10,312,302
19,015,966
1,000,000
1,000,000
18
ProvisionForDeferredIncomeTaxesCreditUtilityOperatingIncome
(Less) Provision for Deferred Income Taxes-Credit (411.1)
234-235
1,037,298
20,867,241
1,000,000
1,000,000
1,037,298
20,867,241
1,000,000
1,000,000
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adjustment-Net (411.4)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
20
GainsFromDispositionOfPlant
(Less) Gains from Disposition of Utility Plant (411.6)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
21
LossesFromDispositionOfUtilityPlant
Losses from Disposition of Utility Plant (411.7)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
0
1,000,000
1,000,000
24
AccretionExpense
Accretion Expense (411.10)
20,617
22,357
1,000,000
1,000,000
20,617
22,357
1,000,000
1,000,000
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Total of lines 4 thru 24)
231,981,302
228,560,040
13,000,000
13,000,000
366,855,645
356,560,040
13,000,000
13,000,000
26
NetUtilityOperatingIncome
Net Utility Operating Income (Total of lines 2 less 25) (Carry forward to line 27)
220,981,302
103,057,816
12,000,000
12,000,000
234,509,988
231,057,816
12,000,000
12,000,000
28
OtherIncomeAndDeductionsAbstract
OTHER INCOME AND DEDUCTIONS
29
OtherIncomeAbstract
Other Income
30
NonutilityOperatingIncomeAbstract
Nonutilty Operating Income
31
RevenuesFromMerchandisingJobbingAndContractWork
Revenues From Merchandising, Jobbing and Contract Work (415)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Expense of Merchandising, Job & Contract Work (416)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
692,060
500,628
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
91,124
22,461
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
28,825,663
30,604,861
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
37
InterestAndDividendIncome
Interest and Dividend Income (419)
1,054,910
390,978
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
191,249
51,557
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
1,583,114
962,900
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
92,808
319,664
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
41
OtherIncome
TOTAL Other Income (Total of lines 31 thru 40)
33,348,680
33,808,127
6,000,000
6,000,000
6,000,000
6,000,000
6,000,000
6,000,000
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
45
Donations
Donations (426.1)
340
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
46
LifeInsurance
Life Insurance (426.2)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
47
Penalties
Penalties (426.3)
83,899
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Expenditures for Certain Civic, Political and Related Activities (426.4)
8,762
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
49
OtherDeductions
Other Deductions (426.5)
233,091
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
340
4,325,752
7,000,000
7,000,000
7,000,000
7,000,000
7,000,000
7,000,000
7,000,000
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262-263
7,345
2,432
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262-263
6,106,931
11,260,378
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262-263
1,050,653
962,842
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Income Taxes (410.2)
234-235
1,743,380
246,968
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Credit (411.2)
234-235
998,232
117,778
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
57
InvestmentTaxCreditAdjustmentsNonutilityOperations
Investment Tax Credit Adjustments-Net (411.5)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
58
InvestmentTaxCredits
(Less) Investment Tax Credits (420)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
59
TaxesOnOtherIncomeAndDeductions
TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)
7,910,077
12,354,842
3,000,000
3,000,000
3,000,000
3,000,000
3,000,000
3,000,000
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
21,112,851
14,453,285
4,000,000
4,000,000
4,000,000
4,000,000
4,000,000
4,000,000
61
InterestChargesAbstract
INTEREST CHARGES
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
22,412,500
22,369,271
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
63
AmortizationOfDebtDiscountAndExpense
Amortization of Debt Disc. and Expense (428)
258-259
328,836
316,377
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reacquired Debt (428.1)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
65
AmortizationOfPremiumOnDebtCredit
(Less) Amortization of Premium on Debt-Credit (429)
258-259
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
66
AmortizationOfGainOnReacquiredDebtCredit
(Less) Amortization of Gain on Reacquired Debt-Credit (429.1)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
67
InterestOnDebtToAssociatedCompanies
Interest on Debt to Associated Companies (430)
340
345,044
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
68
OtherInterestExpense
Other Interest Expense (431)
340
204,367
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Credit (432)
62,141
14,872
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
22,228,606
23,670,776
2,000,000
2,000,000
2,000,000
2,000,000
2,000,000
2,000,000
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
222,097,057
112,275,307
18,000,000
18,000,000
240,509,988
237,057,816
18,000,000
18,000,000
72
ExtraordinaryItemsAbstract
EXTRAORDINARY ITEMS
73
ExtraordinaryIncome
Extraordinary Income (434)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
74
ExtraordinaryDeductions
(Less) Extraordinary Deductions (435)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
75
NetExtraordinaryItems
Net Extraordinary Items (Total of line 73 less line 74)
0
0
0
0
0
0
0
0
76
IncomeTaxesExtraordinaryItems
Income Taxes-Federal and Other (409.3)
262-263
0
0
0
0
0
0
0
0
77
ExtraordinaryItemsAfterTaxes
Extraordinary Items after Taxes (line 75 less line 76)
0
0
0
0
0
0
0
0
78
NetIncomeLoss
Net Income (Total of line 71 and 77)
222,097,057
112,275,307
18,000,000
18,000,000
240,509,988
237,057,816
18,000,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Statement of Accumulated Comprehensive Income and Hedging Activities
  1. Report in columns (b) (c) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate.
  2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges.
  3. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote.
Line No.
Item
(a)
Unrealized Gains and Losses on available-for-sale securities
(b)
Minimum Pension liabililty Adjustment (net amount)
(c)
Foreign Currency Hedges
(d)
Other Adjustments
(e)
Other Cash Flow Hedges Interest Rate Swaps
(f)
Other Cash Flow Hedges [Insert Footnote at Line 1 to specify]
(g)
Totals for each category of items recorded in Account 219
(h)
Net Income (Carried Forward from Page 114, Line 78)
(i)
Total Comprehensive Income
(j)
1
Balance of Account 219 at Beginning of Preceding Year
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
6,000,000
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
6,000,000
3
Preceding Quarter/Year to Date Changes in Fair Value
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
6,000,000
4
Total (lines 2 and 3)
0
0
0
0
0
0
0
112,275,307
112,275,307
5
Balance of Account 219 at End of Preceding Quarter/Year
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
6,000,000
6
Balance of Account 219 at Beginning of Current Year
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
6,000,000
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
6,000,000
8
Current Quarter/Year to Date Changes in Fair Value
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
6,000,000
9
Total (lines 7 and 8)
0
0
0
0
0
0
0
222,097,057
222,097,057
10
Balance of Account 219 at End of Current Quarter/Year
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
6,000,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:


End of:
2021
/
Q3
Statement of Retained Earnings
  1. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year.
  2. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b).
  3. State the purpose and amount for each reservation or appropriation of retained earnings.
  4. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order.
  5. Show dividends for each class and series of capital stock.
Line No.
Item
(a)
Contra Primary Account Affected
(b)
Current Quarter/Year Year to Date Balance
(c)
Previous Quarter/Year Year to Date Balance
(d)
UnappropriatedRetainedEarningsAbstract
UNAPPROPRIATED RETAINED EARNINGS
1
UnappropriatedRetainedEarnings
Balance-Beginning of Period
171,769,527
240,761,387
2
ChangesAbstract
Changes (Identify by prescribed retained earnings accounts)
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
3.1
AdjustmentsToRetainedEarningsCredit
Debits to Retained Earnings
(a)
125,921,409
(b)
162,998,181
3.2
AdjustmentsToRetainedEarningsCredit
Credits to Retained Earnings
80,613,767
60,751,443
4
AdjustmentsToRetainedEarningsCredit
Adjustments to Retained Earnings Credit (Debit)
7
AppropriationsOfRetainedEarningsAbstract
Appropriations of Retained Earnings (Account 436)
7.1
AppropriationsOfRetainedEarnings
Appropriation 2
1,000,000
0
8
AppropriationsOfRetainedEarnings
Appropriations of Retained Earnings Amount
9
DividendsDeclaredPreferredStockAbstract
Dividends Declared-Preferred Stock (Account 437)
9.1
DividendsDeclaredPreferredStock
PS
0
0
10
DividendsDeclaredPreferredStock
Dividends Declared-Preferred Stock Amount
11
DividendsDeclaredCommonStockAbstract
Dividends Declared-Common Stock (Account 438)
11.1
DividendsDeclaredCommonStock
CS
0
0
12
DividendsDeclaredCommonStock
Dividends Declared-Common Stock Amount
13
TransfersFromUnappropriatedUndistributedSubsidiaryEarnings
Transfers from Account 216.1, Unappropriated Undistributed Subsidiary Earnings
28,503,552
33,254,878
14
UnappropriatedRetainedEarnings
Balance-End of Period (Total of lines 1, 4, 5, 6, 8, 10, 12, and 13)
153,965,437
735,437,093
15
AppropriatedRetainedEarningsAbstract
APPROPRIATED RETAINED EARNINGS (Account 215)
16
AppropriatedRetainedEarnings
TOTAL Appropriated Retained Earnings (Account 215) (footnote details)
0
0
17
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract
APPROPRIATED RETAINED EARNINGS-AMORTIZATION RESERVE, FEDERAL (Account 215.1)
18
AppropriatedRetainedEarningsAmortizationReserveFederal
TOTAL Appropriated Retained Earnings-Amortization Reserve, Federal (Account 215.1)
0
0
19
AppropriatedRetainedEarningsIncludingReserveAmortization
TOTAL Appropriated Retained Earnings (Accounts 215, 215.1) (Total of lines of 16 and 18)
0
0
20
RetainedEarnings
TOTAL Retained Earnings (Accounts 215, 215.1, 216) (Total of lines 14 and 19)
153,965,437
735,437,093
21
UnappropriatedUndistributedSubsidiaryEarningsAbstract
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account 216.1)
ReportOnlyOnAnAnnualBasisNoQuarterlyAbstract
Report only on an Annual Basis no Quarterly
22
UnappropriatedUndistributedSubsidiaryEarnings
Balance-Beginning of Year (Debit or Credit)
2,330,902
4,980,919
23
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings for Year (Credit) (Account 418.1)
28,825,663
30,604,861
24
DividendsReceived
(Less) Dividends Received (Debit)
28,503,552
33,254,878
25
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
Other Changes (Explain)
25.1
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
Change 123
0
26
UnappropriatedUndistributedSubsidiaryEarnings
Balance-End of Year
2,653,013
0


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:


End of:
2021
/
Q3
FOOTNOTE DATA

(a) Concept: AdjustmentsToRetainedEarningsCredit

Distributions to members:

 

$

42,776,943

(b) Concept: AdjustmentsToRetainedEarningsCredit

Distributions to members:

 

$

30,927,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:


End of:
2021
/
Q3
Statement of Cash Flows
  1. Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc.
  2. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet.
  3. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid.
  4. Investing Activities: Include at Other (line 25) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.
Description (See Instructions for explanation of codes)
(a)
Current Year to Date Quarter/Year
(b)
Previous Year to Date Quarter/Year
(c)
1
NetCashFlowFromOperatingActivitiesAbstract
Net Cash Flow from Operating Activities
2
NetIncomeLoss
Net Income (Line 78(c) on page 114)
222,097,057
112,275,307
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
30,099,212
30,718,236
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of intangible plant
(a)
4,138,859
(s)
4,012,036
6
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
10,020,152
1,722,085
7
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustments (Net)
0
0
8
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
(b)
2,862,711
(t)
474,405
9
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
(c)
139,922
60,861
10
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
0
0
11
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
(d)
43,115,113
(u)
20,900,961
12
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
(e)(f)
1,127,295
1,288,886
13
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
(g)
2,501,002
(v)
1,450,722
14
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
191,249
51,557
15
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
322,011
2,650,017
16
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other Adjustments to Cash Flows from Operating Activities
16.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Change in prepayments
(h)
21,503
(w)
513,925
18
NetCashProvidedByUsedInOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 16)
136,607,566
55,829,154
20
CashFlowsFromInvestmentActivitiesAbstract
Cash Flows from Investment Activities:
21
ConstructionAndAcquisitionOfPlantIncludingLandAbstract
Construction and Acquisition of Plant (including land):
22
GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Gross Additions to Utility Plant (less nuclear fuel)
(i)(j)
21,924,048
(x)(y)
7,935,048
23
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
-0
-0
24
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
-0
-0
25
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
-0
-0
26
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
(k)
191,249
(z)
51,557
27
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other Construction and Acquisition of Plant, Investment Activities
27.1
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription
Change in customer advances for construction
1,399,927
(aa)(ab)
1,889,434
28
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 22 thru 27)
(l)
20,332,872
(ac)
5,994,057
30
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
0
0
31
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
0
0
33
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Investments in and Advances to Associated and Subsidiary Companies
(m)(n)
45,900,760
574,911
34
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies
Contributions and Advances from Associated and Subsidiary Companies
0
0
36
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
6,050,377
7,865,097
38
PurchaseOfInvestmentSecurities
Purchase of Investment Securities (a)
0
39
ProceedsFromSalesOfInvestmentSecurities
Proceeds from Sales of Investment Securities (a)
0
0
40
LoansMadeOrPurchased
Loan Made or Purchased
0
0
41
CollectionsOnLoans
Collections on Loans
0
0
43
NetIncreaseDecreaseInReceivablesInvestingActivities
Net (Increase) Decrease in Receivables
0
8,784
44
NetIncreaseDecreaseInInventoryInvestingActivities
Net (Increase) Decrease in Inventory
0
0
45
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities
Net (Increase) Decrease in Allowances Held for Speculation
0
0
46
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
778,399
514,169
47
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other Adjustments to Cash Flows from Investment Activities:
47.1
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Proceeds from Disposal of Fixed Assets
(o)
4,871,582
(ae)
456,139
49
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 28 thru 47)
54,533,274
2,275,221
51
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
52
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
53
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Proceeds from Issuance of Long-Term Debt (b)
0
0
54
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Proceeds from Issuance of Preferred Stock
0
0
55
ProceedsFromIssuanceOfCommonStockFinancingActivities
Proceeds from Issuance of Common Stock
0
0
56
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Net Increase in Debt (Long Term Advances)
56.1
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Capital Contributions from Member
(p)
15,000,000
(af)
1,900,000
56.2
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Proceeds from Promissory Note with Affiliate
367,895
(ag)
76,912
57
NetIncreaseInShortTermDebt
Net Increase in Short-term Debt (c)
0
0
59
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total of lines 53 thru 58)
15,367,895
1,976,912
61
PaymentsForRetirementAbstract
Payments for Retirement
62
PaymentsForRetirementOfLongTermDebtFinancingActivities
Payments for Retirement of Long-Term Debt (b)
-0
-0
63
PaymentsForRetirementOfPreferredStockFinancingActivities
Payments for Retirement of Preferred Stock
-0
-0
64
PaymentsForRetirementOfCommonStockFinancingActivities
Payments for Retirement of Common Stock
-0
-0
65
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other Retirements
65.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Distributions to Member
(q)(r)
155,763,442
152,054,590
66
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
-0
-0
67
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other Adjustments to Financing Cash Flows
68
DividendsOnPreferredStock
Dividends on Preferred Stock
0
0
69
DividendsOnCommonStock
Dividends on Common Stock
0
0
70
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 59 thru 69)
140,395,547
150,077,678
73
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract
Net Increase (Decrease) in Cash and Cash Equivalents
74
NetIncreaseDecreaseInCashAndCashEquivalents
(Total of line 18, 49 and 71)
331,536,387
203,631,611
76
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
10,158,385
0
78
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
341,694,772


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:


End of:
2021
/
Q3
FOOTNOTE DATA

(a) Concept: NoncashAdjustmentsToCashFlowsFromOperatingActivities

Debt, discount and expense

 

$

24,787

Regulatory liabilities

 

 

 

(1,805,707)

Utility plant

 

 

 

 

2,307

Total

 

 

 

$

(1,778,613)

(b) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
Original value: 890887
(c) Concept: NetIncreaseDecreaseInInventoryOperatingActivities
Original value: -1983
(d) Concept: NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities

Significant non-cash transactions:

 

 

 

Estimated cash out imbalance

 

 

(237,317)

(e) Concept: NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities

Other regulatory assets - fuel tracker

$

(3,280,128)

 

 

 

 

 

 

Significant non-cash transactions:

 

 

 

Estimated cash out Imbalance

 

$

783,166

(f) Concept: NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Original value: -3280128
(g) Concept: NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities

Other regulatory liabilities - fuel tracker

$

(38,506,078)

Other current liabilities - other

 

 

1,126,614

Estimated cash out imbalance

 

$

(37,379,464)

(h) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities

Other current assets - other

 

$

(1,424,649)

Other deferred charges and liabilities (net)

 

162,445

Total

 

 

 

$

(1,262,204)

(i) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Original value: -29305728
(j) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities

Significant non-cash transactions:

 

 

 

CWIP accruals

 

 

$

4,090,081

CWIP retainage

 

 

 

(1,085,130)

(k) Concept: AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
Original value: -3105101
(l) Concept: CashOutflowsForPlant
Original value: -26200627
(m) Concept: InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies

Significant non-cash transactions:

 

 

 

Contribution of intercompany advance receivable

$

37,712,924

(n) Concept: InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Original value: 37712924
(o) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities

Contributions in aid of construction

 

$

3,898,131

Restricted funds related to certain construction projects

 

1,393,958

Total

 

 

 

$

5,292,089

(p) Concept: OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities

Capital contributions from members

$

1,194,731

(q) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Original value: -42776943
(r) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities

Distributions to members

 

$

(42,776,943)

(s) Concept: NoncashAdjustmentsToCashFlowsFromOperatingActivities

Debt, discount and expense

 

$

24,787

Utility plant

 

 

 

 

1,161

Total

 

 

 

$

25,948

(t) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
Original value: -5758538
(u) Concept: NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities

Significant non-cash transactions:

 

 

 

Deemed contribution of tax accrued

$

11,251,095

Estimated cash out imbalance

 

 

51,631

(v) Concept: NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities

Other regulatory liabilities - fuel tracker

$

(13,606,228)

Other regulatory liabilities - other

 

 

112,268

Total

 

 

 

$

(13,493,960)

 

 

 

 

 

 

Significant non-cash transactions:

 

 

 

Estimated cash out Imbalance

 

$

2,290,059

(w) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities

Other current assets - other

 

$

(1,502,389)

Other deferred charges and liabilities (net)

 

623,717

Total

 

 

 

$

(878,672)

(x) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Original value: -92420116
(y) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities

Significant non-cash transactions:

 

 

 

CWIP accruals

 

 

$

12,703,686

CWIP retainage

 

 

 

(10,237,678)

(z) Concept: AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
Original value: -3388361
(aa) Concept: OtherConstructionAndAcquisitionOfPlantInvestmentActivities

Prepaid option for land purchase

 

$

50,000

(ab) Concept: OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Original value: 50000
(ac) Concept: CashOutflowsForPlant
Original value: -88981755
(ad) Concept: PurchaseOfInvestmentSecurities
Original value: -67620678
(ae) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities

Contributions in aid of construction

 

$

8,623,000

Restricted funds related to certain construction projects

 

2,033,424

Total

 

 

 

$

10,656,424

(af) Concept: OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities

Capital contributions from members

$

32,595,091

(ag) Concept: OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities

Distributions to members

 

$

(30,927,000)


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Notes to Financial Statements
  1. Provide important disclosures regarding the Balance Sheet, Statement of Income for the Year, Statement of Retained Earnings for the Year, and Statement of Cash Flow, or any account thereof. Classify the disclosures according to each financial statement, providing a subheading for each statement except where a disclosure is applicable to more than one statement. The disclosures must be on the same subject matters and in the same level of detail that would be required if the respondent issued general purpose financial statements to the public or shareholders.
  2. Furnish details as to any significant contingent assets or liabilities existing at year end, and briefly explain any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or a claim for refund of income taxes of a material amount initiated by the utility. Also, briefly explain any dividends in arrears on cumulative preferred stock.
  3. Furnish details on the respondent's pension plans, post-retirement benefits other than pensions (PBOP) plans, and post-employment benefit plans as required by instruction no. 1 and, in addition, disclose for each individual plan the current year's cash contributions. Furnish details on the accounting for the plans and any changes in the method of accounting for them. Include details on the accounting for transition obligations or assets, gains or losses, the amounts deferred and the expected recovery periods. Also, disclose any current year's plan or trust curtailments, terminations, transfers, or reversions of assets. Entities that participate in multiemployer postretirement benefit plans (e.g. parent company sponsored pension plans) disclose in addition to the required disclosures for the consolidated plan, (1) the amount of cost recognized in the respondent’s financial statements for each plan for the period presented, and (2) the basis for determining the respondent’s share of the total plan costs.
  4. Furnish details on the respondent’s asset retirement obligations (ARO) as required by instruction no. 1 and, in addition, disclose the amounts recovered through rates to settle such obligations. Identify any mechanism or account in which recovered funds are being placed (i.e. trust funds, insurance policies, surety bonds). Furnish details on the accounting for the asset retirement obligations and any changes in the measurement or method of accounting for the obligations. Include details on the accounting for settlement of the obligations and any gains or losses expected or incurred on the settlement.
  5. Provide a list of all environmental credits received during the reporting period.
  6. Provide a summary of revenues and expenses for each tracked cost and special surcharge.
  7. Where Account 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these item. See General Instruction 17 of the Uniform System of Accounts.
  8. Explain concisely any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
  9. Disclose details on any significant financial changes during the reporting year to the respondent or the respondent's consolidated group that directly affect the respondent's gas pipeline operations, including: sales, transfers or mergers of affiliates, investments in new partnerships, sales of gas pipeline facilities or the sale of ownership interests in the gas pipeline to limited partnerships, investments in related industries (i.e., production, gathering), major pipeline investments, acquisitions by the parent corporation(s), and distributions of capital.
  10. Explain concisely unsettled rate proceedings where a contingency exists such that the company may need to refund a material amount to the utility's customers or that the utility may receive a material refund with respect to power or gas purchases. State for each year affected the gross revenues or costs to which the contingency relates and the tax effects and explain the major factors that affect the rights of the utility to retain such revenues or to recover amounts paid with respect to power and gas purchases.
  11. Explain concisely significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and summarize the adjustments made to balance sheet, income, and expense accounts.
  12. Explain concisely only those significant changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also give the approximate dollar effect of such changes.
  13. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
  14. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
  15. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.

NOTES TO FINANCIAL STATEMENTS

For the Three Months Ended March 31, 2018

 

 

These interim financial statements should be read in conjunction with the financial statements and notes thereto contained in the Form 2 of Algonquin Gas Transmission, LLC (AGT), for the year ended December 31, 2017. These financial statements are unaudited, but in management’s opinion, reflect all normal recurring adjustments that are necessary for a fair presentation of financial position, results of operations and cash flows for the period presented. The results as presented for this interim period are not necessarily indicative of results to be achieved for the full year. Certain information and notes which would substantially duplicate the disclosures contained in the most recent FERC Form 2 have been omitted. 



Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization and Depletion
Line No.
Item
(a)
Total Company For the Current Quarter/Year
(b)
Electric
(c)
Gas
(d)
Other (Specify)
(e)
Common
(f)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlantInServiceAbstract
In Service
3
UtilityPlantInServiceClassified
Plant in Service (Classified)
1,481,724,557
1,000,000
1,481,724,557
1,000,000
1,000,000
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
308,157,463
1,000,000
308,157,463
1,000,000
1,000,000
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
308,157,463
1,000,000
308,157,463
1,000,000
1,000,000
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
8
UtilityPlantInServiceClassifiedAndUnclassified
TOTAL Utility Plant (Total of lines 3 thru 7)
1,481,724,557
1,000,000
1,481,724,557
1,000,000
1,000,000
9
UtilityPlantLeasedToOthers
Leased to Others
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
10
UtilityPlantHeldForFutureUse
Held for Future Use
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
11
ConstructionWorkInProgress
Construction Work in Progress
1,759,554
1,000,000
237,179,387
1,000,000
1,000,000
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
306,157,463
1,000,000
1,000,000
1,000,000
1,000,000
13
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Total of lines 8 thru 12)
1,789,641,574
1,000,000
1,719,903,944
1,000,000
1,000,000
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
670,943,961
0
670,943,961
0
0
15
UtilityPlantNet
Net Utility Plant (Total of lines 13 and 14)
1,118,697,613
1,000,000
1,048,959,983
1,000,000
1,000,000
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
666,246,313
1,000,000
666,246,313
1,000,000
1,000,000
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
4,697,648
1,000,000
4,697,648
1,000,000
1,000,000
22
DepreciationAmortizationAndDepletionUtilityPlantInService
TOTAL In Service (Total of lines 18 thru 21)
670,943,961
0
670,943,961
0
0
23
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract
Leased to Others
24
DepreciationUtilityPlantLeasedToOthers
Depreciation
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
25
AmortizationAndDepletionUtilityPlantLeasedToOthers
Amortization and Depletion
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
26
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers
TOTAL Leased to Others (Total of lines 24 and 25)
0
0
0
0
0
27
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract
Held for Future Use
28
DepreciationUtilityPlantHeldForFutureUse
Depreciation
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
29
AmortizationUtilityPlantHeldForFutureUse
Amortization
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
30
DepreciationAndAmortizationUtilityPlantHeldForFutureUse
TOTAL Held for Future Use (Total of lines 28 and 29)
0
0
0
0
0
31
AbandonmentOfLeases
Abandonment of Leases (Natural Gas)
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
32
AmortizationOfPlantAcquisitionAdjustment
Amortization of Plant Acquisition Adjustment
1,000,000
1,000,000
1,000,000
1,000,000
1,000,000
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
TOTAL Accum. Provisions (Should agree with line 14 above)(Total of lines 22, 26, 30, 31, and 32)
670,943,961
0
670,943,961
0
0


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Gas Plant in Service and Accumulated Provision for Depreciation by Function
  1. Report below the original cost of plant in service by function. In addition to Account 101, include Account 102, and Account 106. Report in column (b) the original cost of plant in service and in column(c) the accumulated provision for depreciation and amortization by function.
Line No.
Item
(a)
Plant in Service Balance at End of Quarter
(b)
Accumulated Depreciation And Amortization Balance at End of Quarter
(c)
1
Intangible Plant
1,000,000
1,000,000
2
Productions-Manufactured Gas
1,000,000
1,000,000
3
Production and Gathering-Natural Gas
1,000,000
1,000,000
4
Products Extraction-Natural Gas
1,000,000
1,000,000
5
Underground Gas Storage
1,000,000
1,000,000
6
Other Storage Plant
1,000,000
1,000,000
7
Base Load LNG Terminaling and Processing Plant
1,000,000
1,000,000
8
Transmission
1,000,000
1,000,000
9
Distribution
1,000,000
1,000,000
10
General
1,000,000
1,000,000
11
TOTAL (total of lines 1 thru 10)
10,000,000
10,000,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Other Regulatory Assets (Account 182.3)
  1. Report below the details called for concerning other regulatory assets which are created through the ratemaking actions of regulatory agencies (and not includable in other accounts).
  2. For regulatory assets being amortized, show period of amortization in column (b).
  3. Minor items (5% of the Balance at End of Year for Account 182.3 or amounts less than $250,000, whichever is less) may be grouped by classes.
  4. Report separately any "Deferred Regulatory Commission Expenses" that are also reported on pages 350-351, Regulatory Commission Expenses.
  5. Provide in column (c), for each line item, the regulatory citation where authorization for the regulatory asset has been granted (e.g. Commission Order, state commission order, court decision).
Line No.
DescriptionAndPurposeOfOtherRegulatoryAssets
Description and Purpose of Other Regulatory Assets
(a)
AmortizationPeriodOtherRegulatoryAssets
Amortization Period
(b)
CitationAuthorizationForOtherRegulatoryAssets
Regulatory Citation
(c)
OtherRegulatoryAssets
Balance at Beginning Current Quarter/Year
(d)
IncreaseDecreaseInOtherRegulatoryAssets
Debits
(e)
OtherRegulatoryAssetsWrittenOffAccountCharged
Written off During Quarter/Year Account Charged
(f)
OtherRegulatoryAssetsWrittenOffRecovered
Written off During Period Amount Recovered
(g)
OtherRegulatoryAssetsWrittenOffDeemedUnrecoverable
Written off During Period Amount Deemed Unrecoverable
(h)
OtherRegulatoryAssets
Balance at End of Current Quarter/Year
(i)
1
(a)
Income Tax Gross-Up on AFUDC Equity
Amortized over remaining life of assets
Recorded pursuant to Docket No. AI93-5-000 issued on April 23, 1993 (Accounting for Income Taxes)
7,574,720
71,913
272,691
100
7,373,842
2
(b)
FERC Annual Charge Adjustment
Amortized over twelve months
Recorded pursuant to 18 CFR 154.402(a) and 18 CFR 382.202
856,773
1,165,222
1,148,077
100
873,818
3
(c)
Asset Retirement Obligation
0
Recorded pursuant to Docket No. RM02-7-000 (Order No. 631) issued on April 9, 2003
256,324
20,983
45,215
100
231,992
4
(d)
Fuel Tracker
0
Recorded pursuant to Docket No. RP07-666. Remaining balance at end of current filing period will be recovered through adjustments to future period fuel retention rates
506,990
1,814,269
524,324
100
1,796,835
40
TOTAL
9,194,807
3,072,387
1,990,307
400
10,276,487


FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Docket No. CP04-67-000 issued June 2, 2004.

(b) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Docket No. RM02-7-000, Order No. 631 issued April 9, 2003.

(c) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

ASC 980-710-25, "Accounting for the Effects of Certain Types of Regulation" contains discussion of the regulatory accounting implications of recording accrued vacation under ASC 710-10-25.

(d) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Docket No. AI93-5-001 issued on April 23, 1993 (Accounting for Income Taxes).


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Other Regulatory Liabilities (Account 254)
  1. Report below the details called for concerning other regulatory liabilities which are created through the ratemaking actions of regulatory agencies (and not includable in other amounts).
  2. For regulatory liabilities being amortized, show period of amortization in column (a).
  3. Minor items (5% of the Balance at End of Year for Account 254 or amounts less than $250,000, whichever is less) may be grouped by classes.
  4. Provide in a footnote, for each line item, the regulatory citation where the respondent was directed to refund the regulatory liability (e.g. Commission Order, state commission order, court decision).
Line No.
DescriptionAndPurposeOfOtherRegulatoryLiabilities
Description and Purpose of Other Regulatory Liabilities
(a)
OtherRegulatoryLiabilities
Balance at Beginning of Current Quarter/Year
(b)
OtherRegulatoryLiabilityAccountOffsettingCredits
Written off during Quarter/Period Account Credited
(c)
OtherRegulatoryLiabilityWrittenOffRefunded
Written off During Period Amount Refunded
(d)
OtherRegulatoryLiabilityWrittenOffDeemedNonRefundable
Written off During Period Amount Deemed Non-Refundable
(e)
OtherRegulatoryLiabilityAdditions
Credits
(f)
OtherRegulatoryLiabilities
Balance at End of Current Quarter/Year
(g)
1
(a)
Revenue Sharing
35,525
0
0
852,179
887,704
2
(b)
Fuel Tracker
618,352
5,938,231
100
7,587,739
2,267,760
3
(c)
Cashout Penalties
2,034
29,107
100
28,422
1,249
4
(d)
Def. Income Tax Rate Adjust. (Amortized over 30.8 years beg. January 1, 2018)
31,384,268
1,037,298
554,126
30,901,096
45
Total
32,040,179
7,004,636
200
9,022,466
34,057,809


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Docket No. RM95-4-000 Order 581 issued September 28, 2015.

(b) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Docket No. RP15-1318-000 issued November 5, 2015.

(c) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Relates to the establishment of a regulatory liability as a result of the U.S. tax reform legislation dated December 22, 2017.

(d) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Algonquin Gas Transmission estimates that the Deferred Income Tax Adjustment Gross-up would not be included in the development of jurisdictional rates.


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Monthly Quantity & Revenue Data by Rate Schedule
  1. Reference to account numbers in the USofA is provided in parentheses beside applicable data. Quantities must not be adjusted for discounts.
  2. Total Quantities and Revenues in whole numbers.
  3. Report revenues and quantities of gas by rate schedule. Where transportation services are bundled with storage services, reflect only transportation Dth. When reporting storage, report Dth of gas withdrawn from storage and revenues by rate schedule.
  4. Revenues in Column (c) include transition costs from upstream pipelines. Revenue (Other) in Column (e) includes reservation charges received by the pipeline plus usage charges, less revenues reflected in Columns (c) and (d). Include in Column (e), revenue for Accounts 490-495.
  5. Enter footnotes as appropriate.
Line No.
Item
(a)
Month 1 Quantity
(b)
Month 1 Revenue Costs and Take-or-Pay
(c)
Month 1 Revenue (GRI & ACA)
(d)
Month 1 Revenue (Other)
(e)
Month 1 Revenue (Total)
(f)
Month 2 Quantity
(g)
Month 2 Revenue Costs and Take-or-Pay
(h)
Month 2 Revenue (GRI & ACA)
(i)
Month 2 Revenue (Other)
(j)
Month 2 Revenue (Total)
(k)
Month 3 Quantity
(l)
Month 3 Revenue Costs and Take-or-Pay
(m)
Month 3 Revenue (GRI & ACA)
(n)
Month 3 Revenue (Other)
(o)
Month 3 Revenue (Total)
(p)
1
Total Sales (480-488)
0
0
0
967
967
0
0
0
2,679
2,679
0
0
0
505
505
2
Transportation of Gas for Others (489.2 and 489..3)
3
APAL-1
801
801
4
CS-1
106,202
106,202
106,120
106,120
106,545
106,545
5
HUB-1
199,250
100
259
2,909
3,268
1,678
100
2
30
68
29,059
100
38
392
530
6
NNT-1
4,564,379
100
5,934
6,372,231
6,378,265
6,096,561
100
7,925
6,644,199
6,652,224
10,237,801
100
13,309
6,707,211
6,720,620
7
NNT-2
40,057
0
52
20,072
20,124
68,051
0
88
34,100
34,188
108,263
0
141
52,092
52,233
8
PAL-HP
9
PAL-1
0
0
0
76,612
76,612
0
0
0
91,833
91,833
0
0
0
212,366
212,366
10
SS-1
0
0
0
270,866
270,866
0
0
0
154,519
154,519
0
0
0
116,604
116,604
11
TF-1
52,074,975
0
67,697
14,929,413
14,997,110
54,458,203
0
70,796
16,277,618
16,348,414
78,333,598
0
101,834
17,009,061
17,110,895
12
TF-4
72,343
0
94
25,001
25,095
130,712
0
170
43,164
43,334
220,836
0
287
124,370
124,657
13
TF-HP
15,849,636
0
20,605
3,118,277
3,138,882
21,186,911
0
27,543
3,166,578
3,194,121
31,043,676
0
40,357
3,700,680
3,741,037
14
TI-1
269,903
0
351
133,776
134,127
597,745
0
777
230,266
231,043
1,202,186
0
1,563
266,396
267,959
15
TI-HP
3,294,913
0
4,283
164,173
168,456
2,707,953
0
3,520
216,342
219,862
1,500,902
0
1,951
223,538
225,489
16
TSB-T
420,931
0
547
2,927,553
2,928,100
1,325,987
0
1,724
2,940,354
2,942,078
876,693
0
1,140
2,965,237
2,966,377
17
TSB-Y
13,045
0
17
1,162,581
1,162,598
17,407
0
23
1,162,665
1,162,688
1,535,828
0
1,996
1,200,741
1,202,737
18
AFTCLNE
63
Total Transportation (Other than Gathering)
76,799,432
200
99,839
29,309,666
29,409,705
86,587,852
200
112,564
31,067,728
31,180,492
125,088,842
200
162,616
32,686,034
32,848,850
64
Storage (489.4)
65
ABC 1
100
100
100
26,135
26,335
100
100
100
22,295
22,495
100
100
100
23,040
23,240
66
DEF 2
100
100
100
11,536
11,736
100
100
100
6,776
6,976
100
100
100
2,418
2,618
90
Total Storage
200
0
0
0
0
200
0
0
0
0
200
200
200
52,291
51,891
91
Gathering (489.1)
92
Gathering-Firm
100
100
100
100
300
100
100
100
100
300
100
100
100
100
300
93
Gathering-Interruptible
100
100
100
100
300
100
100
100
100
300
100
100
100
100
300
94
Total Gathering (489.1)
200
0
0
0
600
200
0
0
0
600
200
200
200
200
600
95
Additional Revenues
96
Products Sales and Extraction (490-492)
100
100
100
132,521
132,721
100
100
100
93,607
93,807
100
100
100
257,709
257,909
97
Rents (493-494)
100
100
100
16,667
16,867
100
100
100
16,666
16,866
100
100
100
16,667
16,867
98
(495) Other Gas Revenues
100
0
0
100,000
100,000
100
0
0
0
0
100
100
100
44,677
44,477
99
(496) (Less) Provision for Rate Refunds
200
0
0
0
0
200
0
0
0
0
200
200
200
200
600
100
Total Additional Revenues
100
200
200
249,188
249,588
100
200
200
285,003
110,673
100
100
100
229,499
229,699
101
Total Operating Revenues (Total of Lines 1,63,90,94 & 100)
76,799,432
0
106,150
44,402,211
29,660,860
86,587,852
0
86,576
43,811,879
31,294,444
125,088,842
0
93,150
43,845,691
33,027,763


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Natural Gas Company- Gas Revenues and Dekatherms
  1. Report below in columns (b), (d) and (f) natural gas operating revenues for each prescribed account year to date.
  2. In column (f) report the quantity of Dekatherms sold of natural gas year to date.
Line No.
Title of Account
(a)
Total Operating Revenues Year to Date Current Qtr
(b)
Dekatherms of Natural Gas Year to Date Current Qtr
(c)
1 ResidentialSalesAbstract (480) Residential Sales
1,000,000
1,000,000
2 CommercialAndIndustrialSalesAbstract (481) Commercial and Industrial Sales
1,000,000
1,000,000
3 OtherSalesToPublicAuthoritiesAbstract (482) Other Sales to Public Authorities
1,000,000
1,000,000
4 SalesForResaleAbstract (483) Sales for Resale
1,000,000
1,000,000
5 InterdepartmentalSalesAbstract (484) Interdepartmental Sales
1,000,000
1,000,000
6 SalesOfGasNotInlcudingIntracompanyTransfersAbstract Total Sales (Lines 1 to 5)
5,000,000
5,000,000
7 IntracompanyTransfersAbstract (485) Intracompany Transfers
1,000,000
8 ForfeitedDiscountsAbstract (487) Forfeited Discounts
1,000,000
9 MiscellaneousServiceRevenuesAbstract (488) Miscellaneous Service Revenues
1,000,000
10 RevenuesFromTransportationOfGasOfOthersThroughGatheringFacilitiesAbstract (489.1) Revenues from Transportation of Gas of Others Through Gathering Facilities
1,000,000
1,000,000
11 RevenuesFromTransportationOfGasOfOthersThroughTransmissionFacilitiesAbstract (489.2) Revenues from Transportation of Gas of Others Through Transmission Facilities
1,000,000
1,000,000
12 RevenuesFromTransportationOfGasOfOthersThroughDistributionFacilitiesAbstract (489.3) Revenues from Transportation of Gas of Others Through Distribution Facilities
1,000,000
1,000,000
13 RevenuesFromStoringGasOfOthersAbstract (489.4) Revenues from Storing Gas of Others
1,000,000
1,000,000
14 SalesOfProductsExtractedFromNaturalGasAbstract (490) Sales of Prod. Ext. from Natural Gas
1,000,000
15 RevenuesFromNaturalGasProcessedByOthersAbstract (491) Revenues from Natural Gas Proc. by Others
1,000,000
16 IncidentalGasolineAndOilSalesAbstract (492) Incidental Gasoline and Oil Sales
1,000,000
17 RentFromGasPropertyAbstract (493) Rent from Gas Property
1,000,000
18 InterdepartmentalRentsAbstract (494) Interdepartmental Rents
1,000,000
19 OtherGasRevenuesAbstract (495) Other Gas Revenues
0
20 OperatingRevenuesBeforeProvisionForRateRefundsAbstract Subtotal:
12,000,000
21 ProvisionForRateRefundsAbstract (496) (Less) Provision for Rate Refunds
1,000,000
22 OperatingRevenuesAbstract TOTAL
11,000,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Gas Production and Other Gas Supply Expenses

Report the amount of gas production and other gas supply expenses year to date.

Line No.
Account
(a)
Year to Date
(b)
1
ProductionExpensesAbstract Production Expenses
2
ManufacturedGasProductionAbstract Manufactured Gas Production
3
ManufacturedGasProduction Total Manufactured Gas Production (700-742)
1,000,000
4
NaturalGasProductionAndGatheringPlantAbstract Natural Gas Production and Gathering
5
ProductionOperationExpense (750-760) Operation
1,000,000
6
ProductionMaintenanceExpense (761-769) Maintenance
1,000,000
7
NaturalGasProductionAndGatheringPlantExpense Total Natural Gas Production and Gathering (lines 5 and 6)
2,000,000
8
ProductionExtractionAbstract Production Extraction
9
ProductsExtractionOperationExpense (770-783) Operation
1,000,000
10
ProductsExtractionMaintenanceExpense (784-791) Maintenance
1,000,000
11
ProductsExtractionExpense Total Production Extraction (lines 9 and 10)
2,000,000
12
ExplorationAndDevelopment (795-798) Exploration and Development Expenses
1,000,000
13
OtherGasSupplyExpensesAbstract Other Gas Supply Expenses
14
OtherGasSupplyExpensesOperationAbstract Operation
15
NaturalGasWellHeadPurchases (800) Natural Gas Well Head Purchases
1,000,000
16
NaturalGasWellHeadPurchasesIntracompanyTransfers (800.1) Natural Gas Well Head Purchases, Intra company Transfers
1,000,000
17
NaturalGasFieldLinePurchases (801) Natural Gas Field Line Purchases
1,000,000
18
NaturalGasGasolinePlantOutletPurchases (802) Natural Gasoline Plant Outlet Purchases
1,000,000
19
NaturalGasTransmissionLinePurchases (803) Natural Gas Transmission Line Purchases
1,000,000
20
NaturalGasCityGatePurchases (804) Natural Gas City Gate Purchases
1,000,000
21
LiquefiedNaturalGasPurchases (804.1) Liquefied Natural Gas Purchases
1,000,000
22
OtherGasPurchases (805) Other Gas Purchases
1,000,000
23
PurchasedGasCostAdjustments (805.1) (Less) Purchase Gas Cost Adjustments
1,000,000
24
PurchasedGasOperationExpenses Total Purchased Gas (lines 15 through 23)
7,000,000
25
ExchangeGas (806) Exchange Gas
1,000,000
26
PurchasedGasExpensesAbstract Purchased Gas Expenses
27
WellExpensePurchasedGas (807.1) Well Expense - Purchased Gas
1,000,000
28
OperationOfPurchasedGasMeasuringStations (807.2) Operation of Purchased Gas Measuring Stations
1,000,000
29
MaintenanceOfPurchasedGasMeasuringStations (807.3) Maintenance of Purchased Gas Measuring Stations
1,000,000
30
PurchasedGasCalculationsExpenses (807.4) Purchased Gas Calculations Expenses
1,000,000
31
OtherPurchasedGasExpenses (807.5) Other Purchased Gas Expenses
1,000,000
32
PurchasedGasExpenses Total Purchased Gas Expenses (lines 27 thru 31)
5,000,000
33
GasWithdrawnFromStorageDebt (808.1) Gas Withdrawn from Storage-Debit
1,000,000
34
GasDeliveredToStorageCredit (808.2) (Less) Gas Delivered to Storage - Credit
1,000,000
35
WithdrawalsOfLiquefiedNaturalGasHeldForProcessingDebit (809.1) Withdrawals of Liquefield Natural Gas for Processing - Debit
1,000,000
36
DeliveriesOfNaturalGasForProcessingCredit (809.2) (Less) Deliveries of Natural Gas Processing - Credit
1,000,000
37
GasUsedInUtilityOperationAbstract Gas Used in Utility Operation - Credit
38
GasUsedForCompressorStationFuelCredit (810) Gas Used for Compressor Station Fuel - Credit
1,000,000
39
GasUsedForProductsExtractionCredit (811) Gas Used for Products Extraction - Credit
1,000,000
40
GasUsedForOtherUtilityOperationsCredit (812) Gas Used for Other Utility Operations - Credit
1,000,000
41
GasUsedInUtilityOperationCredit Total Gas Used in Utility Operations - Credit (Lines 38 thru 40)
3,000,000
42
OtherGasSupplyExpenses (813) Other Gas Supply Expense
1,000,000
43
OtherGasSupplyExpensesOperation Total Other Gas Supply Expenses (Lines 24, 25, 32, 33, thru 36, 42, less 41)
13,000,000
44
ProductionExpenses Total Production Expenses (Lines 3,7,11,12, and 43)
19,000,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Natural Gas Storage, Terminaling, Processing Services

Report the amount of natural gas storage, terminaling, processing, transmission and distribution expenses year to date.

Line No.
Account
(a)
Year to Date Quarter
(b)
1
NaturalGasStorageTerminalingAndProcessingExpensesAbstract NATURAL GAS STORAGE, TERMINALING AND PROCESSING EXPENSES
2
UndergroundStorageExpensesAbstract UNDERGROUND STORAGE EXPENSES
3
UndergroundStorageOperationExpenses (814-826) Operations
1,000,000
4
UndergroundStorageMaintenanceExpenses (830-837) Maintenance
1,000,000
5
UndergroundStorageExpenses Total Underground Storage Expenses (Lines 3 and 4)
2,000,000
6
OtherStorageExpensesAbstract OTHER STORAGE EXPENSES
7
OtherStorageOperationExpenses (840-842.3) Operations
1,000,000
8
OtherStorageMaintenanceExpenses (843.1-843.9) Maintenance
1,000,000
9
OtherStorageExpenses Total Other Storage Expenses (lines 7 and 8)
2,000,000
10
LiquifiedNaturalGasTerminalingAndProcessingExpensesAbstract LIQUEFIED NATURAL GAS TERMINALING AND PROCESSING
11
LiquifiedNaturalGasTerminalingAndProcessingOperationExpenses (844.1-846.2) Operations
1,000,000
12
LiquifiedNaturalGasTerminalingAndProcessingMaintenanceExpenses (847.1-847.8) Maintenance
1,000,000
13
LiquifiedNaturalGasTerminalingAndProcessingExpenses Total Liquefied Natural Gas Terminaling and Processing (Lines 11 and 12)
2,000,000
14
TransmissionExpensesAbstract TRANSMISSION EXPENSES
15
TransmissionExpensesOperationAbstract Transmission Operation Expenses
16
OperationSupervisionAndEngineeringGasTransmissionExpenses (850) Operation Supervision and Engineering
1,000,000
17
SystemControlAndLoadDispatchingGas (851) System Control and Load Dispatching
1,000,000
18
CommunicationSystemExpenses (852) Communication System Expenses
1,000,000
19
CompressorStationLaborAndExpensesTransmissionExpenses (853) Compressor Station Labor and Expenses
1,000,000
20
GasForCompressorStationFuel (854) Gas for Compressor Station Fuel
1,000,000
21
OtherFuelAndPowerForCompressorStations (855) Other Fuel and Power for Compressor Stations
1,000,000
22
MainsExpenses (856) Mains Expenses
1,000,000
23
MeasuringAndRegulatingStationExpensesTransmissionExpenses (857) Measuring and Regulating Station Expenses
1,000,000
24
TransmissionAndCompressionOfGasByOthers (858) Transmission and Compression of Gas by Others
1,000,000
25
OtherExpensesGasTransmission (859) Other Expenses
1,000,000
26
RentsGasTransmissionExpense (860) Rents
1,000,000
27
TransmissionOperationExpense Total Transmission Operation Expenses (Lines 16 through 26)
11,000,000
28
TransmissionExpensesMaintenanceAbstract Transmission Maintenance Expenses
29
MaintenanceSupervisionAndEngineeringGasTransmissionExpenses (861) Maintenance Supervision and Engineering
1,000,000
30
MaintenanceOfStructuresAndImprovementsTransmissionExpenses (862) Maintenance of Structures and Improvements
1,000,000
31
MaintenanceOfMainsTransmissionExpenses (863) Maintenance of Mains
1,000,000
32
MaintenanceOfCompressorStationEquipmentTransmissionExpenses (864) Maintenance of Compressor Station Equipment
1,000,000
33
MaintenanceOfMeasuringAndRegulatingStationEquipment (865) Maintenance of Measuring and Regulating Equipment
1,000,000
34
MaintenanceOfCommunicationEquipmentGasTransmission (866) Maintenance of Communication Equipment
1,000,000
35
MaintenanceOfOtherEquipmentTransmissionExpenses (867) Maintenance of Other Equipment
1,000,000
36
TransmissionMaintenanceExpensesGas Total Transmission Maintenance Expenses (Lines 29 through 35)
7,000,000
37
TransmissionExpenses Total Transmission Expenses (lines 27 and 36)
18,000,000
38
DistributionExpensesAbstract DISTRIBUTION EXPENSES
39
DistributionOperationExpensesGas (870-881) Operation Expenses
1,000,000
40
DistributionMaintenanceExpenseGas (885-894) Maintenance
1,000,000
41
DistributionExpenses Total Distribution Expenses (Lines 39 and 40)
2,000,000
42
OperationAndMaintenanceExpensesIncludingNaturalGasStorageTerminalingAndProcessingExpensesTransmissionExpensesDistributionExpenses Total (lines 5,9,13,37 and 41)
26,000,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Gas Customer Accounts, Service, Sales, Administrative and General Expenses

Report the amount of expenses for customer accounts, service, sales, and administrative and general expenses year to date.

Line No.
Account
(a)
Year to Date Quarter
(b)
1
CustomerAccountExpenses (901-905) Customer Accounts Expenses
1,000,000
2
CustomerServiceAndInformationalExpenses (907-910) Customer Service and Information Expenses
1,000,000
3
SalesExpenses (911-916) Sales Expenses
1,000,000
4
AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
5
AdministrativeAndGeneralExpensesOperationAbstract Operations
6
AdministrativeAndGeneralSalaries 920 Administrative and General Salaries
1,000,000
7
OfficeSuppliesAndExpenses 921 Office Supplies and Expenses
1,000,000
8
AdministrativeExpensesTransferredCredit (Less) 922 Administrative Expenses Transferred-Credit
1,000,000
9
OutsideServicesEmployed 923 Outside Services Employed
1,000,000
10
PropertyInsurance 924 Property Insurance
1,000,000
11
InjuriesAndDamages 925 Injuries and Damages
1,000,000
12
EmployeePensionsAndBenefits 926 Employee Pensions and Benefits
1,000,000
13
FranchiseRequirements 927 Franchise Requirements
1,000,000
14
RegulatoryCommissionExpenses 928 Regulatory Commission Expenses
1,000,000
15
DuplicateChargesCredit (Less) 929 Duplicate Charges-Credit
1,000,000
16
GeneralAdvertisingExpenses 930.1 General Advertising Expenses
1,000,000
17
MiscellaneousGeneralExpenses 930.2 Miscellaneous General Expenses
1,000,000
18
RentsAdministrativeAndGeneralExpense 931 Rents
1,000,000
19
AdministrativeAndGeneralOperationExpense TOTAL Operation (Total of lines 6 through 18)
9,000,000
20
MaintenanceAbstract Maintenance
21
MaintenanceOfGeneralPlant 932 Maintenance of General Plant
1,000,000
22
AdministrativeAndGeneralExpenses TOTAL Administrative and General Expenses (Total of lines 19 and 21)
10,000,000


Name of Respondent:


Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:


11/30/2021
Year/Period of Report:


End of:
2021
/
Q3
Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 403.1, 404.1, 404.2, 404.3, 405) (Except Amort of Acqusition Adjustments)
  1. Report the year to date amounts of depreciation expense, asset retirement cost depreciation, depletion and amortization, except amortization of acquisition adjustments for the accounts indicated and classified according to the plant functional groups described.
Line No.
Functional Classification
(a)
Depreciation Expense (Account 403)
(b)
Depreciation Expense for Asset Retirement Costs (Account 403.1)
(c)
Amortization and Depletion of Other Gas Plant (Accounts 404.1, 404.2 and 404.3)
(d)
Amortization of Other Gas Plant (Account 405)
(e)
Total (b to e)
(f)
1
Intangible Plant
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
2
Production Plant, Manufacturing Plant
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
3
Production and Gathering Plant - Natural Gas
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
4
Products Extraction - Natural Gas
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
5
Underground Gas Storage Plant
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
6
Other Storage Plant
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
7
Base Load LNG Terminaling and Processing Plant
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
8
Processing Plant
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
9
Transmission Plant
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
10
Distribution Plant
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
11
General Plant
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
12
Common Plant
1,000,000
1,000,000
1,000,000
1,000,000
4,000,000
13
Total
12,000,000
12,000,000
12,000,000
12,000,000
48,000,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Gas Account - Natural Gas
  1. The purpose of this schedule is to account for the quantity of natural gas received and delivered by the respondent.
  2. Natural gas means either natural gas unmixed or any mixture of natural and manufactured gas.
  3. Enter in column (c) the year to date Dth as reported in the schedules indicated for the items of receipts and deliveries.
  4. Enter in column (d) the respective quarter’s Dth as reported in the schedules indicated for the items of receipts and deliveries.
  5. Indicate in a footnote the quantities of bundled sales and transportation gas and specify the line on which such quantities are listed.
  6. If the respondent operates two or more systems which are not interconnected, submit separate pages for this purpose.
  7. Indicate by footnote the quantities of gas not subject to Commission regulation which did not incur FERC regulatory costs by showing (1) the local distribution volumes another jurisdictional pipeline delivered to the local distribution company portion of the reporting pipeline (2) the quantities that the reporting pipeline transported or sold through its local distribution facilities or intrastate facilities and which the reporting pipeline received through gathering facilities or intrastate facilities, but not through any of the interstate portion of the reporting pipeline, and (3) the gathering line quantities that were not destined for interstate market or that were not transported through any interstate portion of the reporting pipeline.
  8. Indicate in a footnote the specific gas purchase expense account(s) and related to which the aggregate volumes reported on line No. 3 relate.
  9. Indicate in a footnote (1) the system supply quantities of gas that are stored by the reporting pipeline, during the reporting year and also reported as sales,transportation and compression volumes by the reporting pipeline during the same reporting year, (2) the system supply quantities of gas that are stored by the reporting pipeline during the reporting year which the reporting pipeline intends to sell or transport in a future reporting year, and (3) contract storage quantities.
  10. Also indicate the volumes of pipeline production field sales that are included in both the company's total sales figure and the company;s total transportation figure. Add additional information as necessary to the footnotes.
Line No.
Item
(a)
Ref. Page No. of (FERC Form Nos. 2/2-A)
(b)
Total Amount of Dth Year to Date
(c)
Current Three Months Ended Amount of Dth Quarterly Only
(d)
1
NameOfSystem
Name of System
Gas System 123
2
QuantityOfNaturalGasReceivedByUtilityAbstract
GAS RECEIVED
3
QuantityOfNaturalGasReceivedByUtilityGasPurchases
Gas Purchases (Accounts 800-805)
437,275
4
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForGathering
Gas of Others Received for Gathering (Account 489.1)
303
100,000
5
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForTransmission
Gas of Others Received for Transmission (Account 489.2)
305
1,029,278,410
6
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForDistribution
Gas of Others Received for Distribution (Account 489.3)
301
100,000
7
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForContractStorage
Gas of Others Received for Contract Storage (Account 489.4)
307
76,131
8
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForProductionExtractionProcessing
Gas of Others Received for Production/Extraction/Processing (Account 490 and 491)
100,000
9
QuantityOfNaturalGasReceivedByUtilityExchangedGasReceivedFromOthers
Exchanged Gas Received from Others (Account 806)
328
100,000
10
QuantityOfNaturalGasReceivedByUtilityGasReceivedAsImbalances
Gas Received as Imbalances (Account 806)
328
3,048,824
11
QuantityOfNaturalGasReceivedByUtilityReceiptsOfUtilitysGasTransportedByOthers
Receipts of Respondent's Gas Transported by Others (Account 858)
332
78,982,763
12
QuantityOfNaturalGasReceivedByUtilityOtherGasWithdrawnFromStorage
Other Gas Withdrawn from Storage (Explain)
101,705,959
13
QuantityOfNaturalGasReceivedByUtilityGasReceivedFromShippersAsCompressorStationFuel
Gas Received from Shippers as Compressor Station Fuel
4,483,478
14
QuantityOfNaturalGasReceivedByUtilityGasReceivedFromShippersAsLostAndUnaccountedFor
Gas Received from Shippers as Lost and Unaccounted for
1,171,970
15
QuantityOfNaturalGasReceivedByUtilityOther
Other Receipts (Specify) (footnote details)
15.1
QuantityOfNaturalGasReceivedByUtilityOther
Gas Received from Mystery Company
1,000,000
15.2
QuantityOfNaturalGasReceivedByUtilityOther
Receipt from Shippers as Good Gesture
0
16
QuantityOfNaturalGasReceivedByUtility
Total Receipts (Total of lines 3 thru 15)
1,220,584,810
17
QuantityOfNaturalGasDeliveredByUtilityAbstract
GAS DELIVERED
18
QuantityOfNaturalGasDeliveredByUtilityGasSales
Gas Sales (Accounts 480-484)
100,000
19
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasGatheredForOthers
Deliveries of Gas Gathered for Others (Account 489.1)
303
100,000
20
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasTransportedForOthers
Deliveries of Gas Transported for Others (Account 489.2)
305
(a)
1,029,278,410
21
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasDistributedForOthers
Deliveries of Gas Distributed for Others (Account 489.3)
301
100,000
22
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfContractStorageGas
Deliveries of Contract Storage Gas (Account 489.4)
307
100,000
23
QuantityOfNaturalGasDeliveredByUtilityGasOfOthersDeliveredForProductionExtractionProcessing
Gas of Others Delivered for Production/Extraction/Processing (Account 490 and 491)
100,000
24
QuantityOfNaturalGasDeliveredByUtilityExchangeGasDeliveredToOthers
Exchange Gas Delivered to Others (Account 806)
328
100,000
25
QuantityOfNaturalGasDeliveredByUtilityGasDeliveredAsImbalances
Gas Delivered as Imbalances (Account 806)
328
3,065,277
26
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasToOthersForTransportation
Deliveries of Gas to Others for Transportation (Account 858)
332
78,982,763
27
QuantityOfNaturalGasDeliveredByUtilityOtherGasDeliveredToStorage
Other Gas Delivered to Storage (Explain)
97,723,038
28
QuantityOfNaturalGasDeliveredByUtilityGasUsedForCompressorStationFuel
Gas Used for Compressor Station Fuel
509
3,573,400
29
GasUsedForOtherDeliveriesAndGasUsedForOtherOperations
Other Deliveries and Gas Used for Other Operations
29.1
GasUsedForOtherDeliveriesAndGasUsedForOtherOperations
Delivery from Unknown Company
5,669,203
29.2
GasUsedForOtherDeliveriesAndGasUsedForOtherOperations
Gas Used for Fires
0
30
QuantityOfNaturalGasDeliveredByUtility
Total Deliveries (Total of lines 18 thru 29)
1,218,892,091
31
GasLossesAndGasUnaccountedForGasAccountAbstract
GAS LOSSES AND GAS UNACCOUNTED FOR
32
GasAccountGasLossesAndGasUnaccountedForGasAccount
Gas Losses and Gas Unaccounted For
816,588
33
DeliveriesGasLossesAndUnaccountedForGasAccountAbstract
TOTALS
34
DeliveriesGasLossesAndUnaccountedForGasAccount
Total Deliveries, Gas Losses & Unaccounted For (Total of lines 30 and 32)
1,219,708,679


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
FOOTNOTE DATA

(a) Concept: QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasTransportedForOthers

219,908,907 Dths are the only volumes subject to ACA surcharges.


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Shipper Supplied Gas for the Current Quarter
  1. Report monthly (1) shipper supplied gas for the current quarter and gas consumed in pipeline operations, (2) the disposition of any excess, the accounting recognition given to such disposition and the specific account(s) charged or credited, and (3) the source of gas used to meet any deficiency, the accounting recognition given to the gas used to meet the deficiency, including the accounting basis of the gas and the specific account(s) charged or credited.
  2. On lines 7, 14, 22 and 30 report only the dekatherms of gas provided by shippers under tariff terms and conditions for gathering , production/ extraction/processing, transmission, distribution and storage service and the use of that gas for compressor fuel, other operational purposes and lost and unaccounted for. The dekatherms must be broken out by functional categories on Lines 2-6, 9-13, 16-21 and 24-29. The dekatherms must be reported in column (d) unless the company has discounted or negotiated rates which should be reported in columns (b) and (c).
  3. On lines 7, 14, 22 and 30 report only the dollar amounts of gas provided by shippers under tariff terms and conditions for gathering, production/ extraction/processing, transmission, distribution and storage service and the use of that gas for compressor fuel, other operational purposes and lost and unaccounted for. The dollar amounts must be broken out by functional categories on Lines 2-6, 9-13, 16-21 and 23-29. The dollar amounts must be reported in column (h) unless the company has discounted or negotiated rates which should be reported in columns (f) and (g). The accounting should disclose the account(s) debited and credited in columns (m) and (n).
  4. Indicate in a footnote the basis for valuing the gas reported in Columns (f), (g) and (h).
  5. Report in columns (j), (k) and (l) the amount of fuel waived, discounted or reduced as part of a negotiated rate agreement.
  6. On lines 32-37 report the dekatherms and dollar value of the excess or deficiency in shipper supplied gas broken out by functional category and whether recourse rate, discounted or negotiated rate.
  7. On lines 39 through 51 report the dekatherms, the dollar amount and the account(s) credited in Column (o) for the dispositions of gas listed in column (a).
  8. On lines 53 through 65 report the dekatherms, the dollar amount and the account(s) debited in Column (n) for the sources of gas reported in column (a).
  9. On lines 66 and 67, report forwardhaul and backhaul volume in Dths of throughput.
  10. Where appropriate, provide a full explanation of the allocation process used in reported numbers in a footnote.
Month 1
Amount Collected (Dollars) Volume (in Dth) Not Collected
Line No.
Item
(a)
Discounted rate Dth
(b)
Negotiated Rate Dth
(c)
Recourse Rate Dth
(d)
Total Dth
(e)
Discounted Rate, Amount
(f)
Negotiated Rate Amount
(g)
Recourse rate Amount
(h)
Total Amount
(i)
Waived Dth
(j)
Discounted Dth
(k)
Negotiated Dth
(l)
Total Dth
(m)
Account(s) Debited
(n)
Account(s) Credited
(o)
1
SHIPPER SUPPLIED GAS (LINES 13 AND 14 , PAGE 520)
2
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
3
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
4
Transmission
100,000
100,000
100,000
(a)
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
5
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
6
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
7
Total Shipper Supplied Gas
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,500,000
LESS GAS USED FOR COMPRESSOR STATION FUEL (LINE 28, PAGE 520)
9
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
10
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
11
Transmission
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
12
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
13
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
14
Total gas used in compressors
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,500,000
15
LESS GAS USED FOR OTHER DELIVERIES AND GAS USED FOR OTHER OPERATIONS (LINE 29, PAGE 520) (Footnote)
16
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
17
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
18
Transmission
100,000
100,000
100,000
(b)
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
19
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
20
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
21
Other Deliveries (specify) (footnote details)
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
22
Total Gas Used For Other Deliveries And Gas Used For Other Operations
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
23
LESS GAS LOST AND UNACCOUNTED FOR (LINE 32, PAGE 520)
24
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
25
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
26
Transmission
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
27
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
28
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
29
Other Deliveries (specify) (footnote details)
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
30
Total Gas Lost And Unaccounted For
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
30.1
NET EXCESS OR (DEFICIENCY)
31
Other Losses
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
32
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
33
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
34
Transmission
100,000
100,000
100,000
(c)
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
35
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
36
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
37
Total Net Excess Or (Deficiency)
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
38
DISPOSITION OF EXCESS GAS:
39
Gas sold to others
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
40
Gas used to meet imbalances
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
41
Gas added to system gas
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
42
Gas returned to shippers
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
299,400
43.1
Other Disposition 1
100
100
100
300
100
100
100
300
100
100
100
300
43.2
Other Disposition 2
100
100
100
300
100
100
100
300
100
100
100
300
51
Total Disposition Of Excess Gas
400,200
400,200
400,200
1,200,600
400,200
400,200
400,200
1,200,600
400,000
400,000
400,000
1,200,000
52
GAS ACQUIRED TO MEET DEFICIENCY:
53
System gas
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
54
Purchased gas
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
55.1
Other Acquired 1
100
100
100
300
100
100
100
300
100
100
200
55.2
Other Acquired 2
100
100
100
300
100
100
100
300
100
100
200
65
Total Gas Acquired To Meet Deficiency
200,200
200,200
200,200
600,600
200,200
200,200
200,200
600,600
200,000
200,000
200,000
600,000

SEPARATION OF FORWARDHAUL AND BACKHAUL THROUGHPUT
Line No.
Item
(a)
Quarter
Dth (b)
66
Forwardhaul Volume in Dths for the Quarter
3,400,000
67
Backhaul Volume in Dths for the Quarter
3,400,000
68
TOTAL (Lines 66 and 67)
6,800,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
FOOTNOTE DATA

(a) Concept: ShipperSuppliedGasTransmission

Fuel quantities requiring an allocation are assigned to the rate categories on the basis of the stated fuel rates as referenced in Order No. 710-C, at paragraph 9. Specifically, within each functional category, the fuel quantities in lines 8 - 30 are prorated to the rate categories based on the ration of the Shipper Supplied quantities in lines 1 - 7 for each rate category to the total Shopper Supplied quantity for such functional category.

 

Disposition of Excess Gas and Gas Acquired to Meet Deficiency quantities in lines 38 - 65 are prorated to the rate categories based on the ration of the Excess or Deficiency quantities for each rate category to the total Excess or Deficiency quantity in line 37.

(b) Concept: GasUsedForOtherDeliveriesAndGasUsedForOtherOperationsTransmission

M&R Fuel

 

7,654

O&M Gas Loss

2,245

Warehouse fuel

101

 

 

10,000

(c) Concept: ShipperSuppliedGasNetExcessOrDeficiencyTransmission

Since we administer the cost of gas used for fuel by means of a tracking mechanism, values are assigned pursuant to the requirements under our tariff provisions to the net excess or deficiency which results from shipper supplied gas as well as the disposition of the excesses and the sources of deficiencies.


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Shipper Supplied Gas for the Current Quarter
  1. Report monthly (1) shipper supplied gas for the current quarter and gas consumed in pipeline operations, (2) the disposition of any excess, the accounting recognition given to such disposition and the specific account(s) charged or credited, and (3) the source of gas used to meet any deficiency, the accounting recognition given to the gas used to meet the deficiency, including the accounting basis of the gas and the specific account(s) charged or credited.
  2. On lines 7, 14, 22 and 30 report only the dekatherms of gas provided by shippers under tariff terms and conditions for gathering , production/ extraction/processing, transmission, distribution and storage service and the use of that gas for compressor fuel, other operational purposes and lost and unaccounted for. The dekatherms must be broken out by functional categories on Lines 2-6, 9-13, 16-21 and 24-29. The dekatherms must be reported in column (d) unless the company has discounted or negotiated rates which should be reported in columns (b) and (c).
  3. On lines 7, 14, 22 and 30 report only the dollar amounts of gas provided by shippers under tariff terms and conditions for gathering, production/ extraction/processing, transmission, distribution and storage service and the use of that gas for compressor fuel, other operational purposes and lost and unaccounted for. The dollar amounts must be broken out by functional categories on Lines 2-6, 9-13, 16-21 and 23-29. The dollar amounts must be reported in column (h) unless the company has discounted or negotiated rates which should be reported in columns (f) and (g). The accounting should disclose the account(s) debited and credited in columns (m) and (n).
  4. Indicate in a footnote the basis for valuing the gas reported in Columns (f), (g) and (h).
  5. Report in columns (j), (k) and (l) the amount of fuel waived, discounted or reduced as part of a negotiated rate agreement.
  6. On lines 32-37 report the dekatherms and dollar value of the excess or deficiency in shipper supplied gas broken out by functional category and whether recourse rate, discounted or negotiated rate.
  7. On lines 39 through 51 report the dekatherms, the dollar amount and the account(s) credited in Column (o) for the dispositions of gas listed in column (a).
  8. On lines 53 through 65 report the dekatherms, the dollar amount and the account(s) debited in Column (n) for the sources of gas reported in column (a).
  9. On lines 66 and 67, report forwardhaul and backhaul volume in Dths of throughput.
  10. Where appropriate, provide a full explanation of the allocation process used in reported numbers in a footnote.
Month 2
Amount Collected (Dollars) Volume (in Dth) Not Collected
Line No.
Item
(a)
Discounted rate Dth
(b)
Negotiated Rate Dth
(c)
Recourse Rate Dth
(d)
Total Dth
(e)
Discounted Rate, Amount
(f)
Negotiated Rate Amount
(g)
Recourse rate Amount
(h)
Total Amount
(i)
Waived Dth
(j)
Discounted Dth
(k)
Negotiated Dth
(l)
Total Dth
(m)
Account(s) Debited
(n)
Account(s) Credited
(o)
1
SHIPPER SUPPLIED GAS (LINES 13 AND 14 , PAGE 520)
2
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
99,400
100,000
100,000
299,400
3
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
4
Transmission
100,000
100,000
100,000
(a)
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
5
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
6
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
7
Total Shipper Supplied Gas
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,500,000
499,400
500,000
500,000
1,499,400
8
LESS GAS USED FOR COMPRESSOR STATION FUEL (LINE 28, PAGE 520)
9
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
10
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
11
Transmission
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
12
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
13
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
14
Total gas used in compressors
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,499,400
15
LESS GAS USED FOR OTHER DELIVERIES AND GAS USED FOR OTHER OPERATIONS (LINE 29, PAGE 520) (Footnote)
16
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
17
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
18
Transmission
100,000
100,000
100,000
(b)
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
19
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
20
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
21
Other Deliveries (specify) (footnote details)
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
22
Total Gas Used For Other Deliveries And Gas Used For Other Operations
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
23
LESS GAS LOST AND UNACCOUNTED FOR (LINE 32, PAGE 520)
24
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
25
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
26
Transmission
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
27
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
28
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
29
Other Deliveries (specify) (footnote details)
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
30
Total Gas Lost And Unaccounted For
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
30.1
NET EXCESS OR (DEFICIENCY)
31
Other Losses
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
32
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
33
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
34
Transmission
100,000
100,000
100,000
(c)
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
35
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
36
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
37
Total Net Excess Or (Deficiency)
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
600,000
38
DISPOSITION OF EXCESS GAS:
39
Gas sold to others
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
40
Gas used to meet imbalances
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
41
Gas added to system gas
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
42
Gas returned to shippers
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
43.1
Other 123
100
100
100
300
100
100
100
300
100
100
100
300
43.2
Other 321
100
100
100
300
100
100
100
300
100
100
100
300
51
Total Disposition Of Excess Gas
400,200
400,200
400,200
1,200,600
400,200
400,200
400,200
1,200,600
400,000
400,000
400,000
1,200,000
52
GAS ACQUIRED TO MEET DEFICIENCY:
53
System gas
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
54
Purchased gas
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
55.1
Other 789
100
100
100
300
100
100
100
300
200
999
100
999
55.2
Other 456
100
100
100
300
100
100
100
300
100
100
100
200
65
Total Gas Acquired To Meet Deficiency
200,200
200,200
200,200
600,600
200,200
200,200
200,200
600,600
200,000
200,000
200,000
600,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
FOOTNOTE DATA

(a) Concept: ShipperSuppliedGasTransmission

Fuel quantities requiring an allocation are assigned to the rate categories on the basis of the stated fuel rates as referenced in Order No. 710-C, at paragraph 9. Specifically, within each functional category, the fuel quantities in lines 8 - 30 are prorated to the rate categories based on the ration of the Shipper Supplied quantities in lines 1 - 7 for each rate category to the total Shopper Supplied quantity for such functional category.

 

Disposition of Excess Gas and Gas Acquired to Meet Deficiency quantities in lines 38 - 65 are prorated to the rate categories based on the ration of the Excess or Deficiency quantities for each rate category to the total Excess or Deficiency quantity in line 37.

(b) Concept: GasUsedForOtherDeliveriesAndGasUsedForOtherOperationsTransmission

M&R Fuel

 

6,355

O&M Gas Loss

1,607

Warehouse fuel

82

 

 

8,044

(c) Concept: ShipperSuppliedGasNetExcessOrDeficiencyTransmission

Since we administer the cost of gas used for fuel by means of a tracking mechanism, values are assigned pursuant to the requirements under our tariff provisions to the net excess or deficiency which results from shipper supplied gas as well as the disposition of the excesses and the sources of deficiencies.


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
Shipper Supplied Gas for the Current Quarter
  1. Report monthly (1) shipper supplied gas for the current quarter and gas consumed in pipeline operations, (2) the disposition of any excess, the accounting recognition given to such disposition and the specific account(s) charged or credited, and (3) the source of gas used to meet any deficiency, the accounting recognition given to the gas used to meet the deficiency, including the accounting basis of the gas and the specific account(s) charged or credited.
  2. On lines 7, 14, 22 and 30 report only the dekatherms of gas provided by shippers under tariff terms and conditions for gathering , production/ extraction/processing, transmission, distribution and storage service and the use of that gas for compressor fuel, other operational purposes and lost and unaccounted for. The dekatherms must be broken out by functional categories on Lines 2-6, 9-13, 16-21 and 24-29. The dekatherms must be reported in column (d) unless the company has discounted or negotiated rates which should be reported in columns (b) and (c).
  3. On lines 7, 14, 22 and 30 report only the dollar amounts of gas provided by shippers under tariff terms and conditions for gathering, production/ extraction/processing, transmission, distribution and storage service and the use of that gas for compressor fuel, other operational purposes and lost and unaccounted for. The dollar amounts must be broken out by functional categories on Lines 2-6, 9-13, 16-21 and 23-29. The dollar amounts must be reported in column (h) unless the company has discounted or negotiated rates which should be reported in columns (f) and (g). The accounting should disclose the account(s) debited and credited in columns (m) and (n).
  4. Indicate in a footnote the basis for valuing the gas reported in Columns (f), (g) and (h).
  5. Report in columns (j), (k) and (l) the amount of fuel waived, discounted or reduced as part of a negotiated rate agreement.
  6. On lines 32-37 report the dekatherms and dollar value of the excess or deficiency in shipper supplied gas broken out by functional category and whether recourse rate, discounted or negotiated rate.
  7. On lines 39 through 51 report the dekatherms, the dollar amount and the account(s) credited in Column (o) for the dispositions of gas listed in column (a).
  8. On lines 53 through 65 report the dekatherms, the dollar amount and the account(s) debited in Column (n) for the sources of gas reported in column (a).
  9. On lines 66 and 67, report forwardhaul and backhaul volume in Dths of throughput.
  10. Where appropriate, provide a full explanation of the allocation process used in reported numbers in a footnote.
Month 3
Amount Collected (Dollars) Volume (in Dth) Not Collected
Line No.
Item
(a)
Discounted rate Dth
(b)
Negotiated Rate Dth
(c)
Recourse Rate Dth
(d)
Total Dth
(e)
Discounted Rate, Amount
(f)
Negotiated Rate Amount
(g)
Recourse rate Amount
(h)
Total Amount
(i)
Waived Dth
(j)
Discounted Dth
(k)
Negotiated Dth
(l)
Total Dth
(m)
Account(s) Debited
(n)
Account(s) Credited
(o)
1
SHIPPER SUPPLIED GAS (LINES 13 AND 14 , PAGE 520)
2
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
299,400
3
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
4
Transmission
100,000
100,000
100,000
(a)
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
5
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
6
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
7
Total Shipper Supplied Gas
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,499,400
8
LESS GAS USED FOR COMPRESSOR STATION FUEL (LINE 28, PAGE 520)
9
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
10
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
11
Transmission
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
12
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
13
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
14
Total gas used in compressors
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,500,000
500,000
500,000
500,000
1,500,000
15
LESS GAS USED FOR OTHER DELIVERIES AND GAS USED FOR OTHER OPERATIONS (LINE 29, PAGE 520) (Footnote)
16
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
17
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
18
Transmission
100,000
100,000
100,000
(b)
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
19
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
20
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
21
Other Deliveries (specify) (footnote details)
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
22
Total Gas Used For Other Deliveries And Gas Used For Other Operations
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
23
LESS GAS LOST AND UNACCOUNTED FOR (LINE 32, PAGE 520)
24
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
25
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
26
Transmission
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
27
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
28
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
29
Other Deliveries (specify) (footnote details)
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
30
Total Gas Lost And Unaccounted For
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
30.1
NET EXCESS OR (DEFICIENCY)
31
Other Losses
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
32
Gathering
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
33
Production/Extraction/Processing
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
34
Transmission
100,000
100,000
100,000
(c)
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
35
Distribution
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
36
Storage
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
37
Total Net Excess Or (Deficiency)
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
600,000
600,000
600,000
1,800,000
38
DISPOSITION OF EXCESS GAS:
39
Gas sold to others
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
40
Gas used to meet imbalances
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
41
Gas added to system gas
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
42
Gas returned to shippers
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
43.1
Other 567
100
100
100
300
100
100
100
300
100
100
100
300
43.2
Other 287
100
100
100
300
100
100
100
300
100
100
100
300
51
Total Disposition Of Excess Gas
400,200
400,200
400,200
1,200,600
400,200
400,200
400,200
1,200,600
400,000
400,000
400,000
1,200,000
52
GAS ACQUIRED TO MEET DEFICIENCY:
53
System gas
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
54
Purchased gas
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
100,000
100,000
100,000
300,000
55.1
Other 726
100
100
100
300
100
100
100
300
0
100
100
200
55.2
Other 472
100
100
100
300
100
100
100
300
0
100
100
200
65
Total Gas Acquired To Meet Deficiency
200,200
200,200
200,200
600,600
200,200
200,200
200,200
600,600
200,000
200,000
200,000
600,000


Name of Respondent:

Algonquin Gas Transmission, LLC
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/30/2021
Year/Period of Report:

End of:
2021
/
Q3
FOOTNOTE DATA

(a) Concept: ShipperSuppliedGasTransmission

Fuel quantities requiring an allocation are assigned to the rate categories on the basis of the stated fuel rates as referenced in Order No. 710-C, at paragraph 9. Specifically, within each functional category, the fuel quantities in lines 8 - 30 are prorated to the rate categories based on the ration of the Shipper Supplied quantities in lines 1 - 7 for each rate category to the total Shopper Supplied quantity for such functional category.

 

Disposition of Excess Gas and Gas Acquired to Meet Deficiency quantities in lines 38 - 65 are prorated to the rate categories based on the ration of the Excess or Deficiency quantities for each rate category to the total Excess or Deficiency quantity in line 37.

(b) Concept: GasUsedForOtherDeliveriesAndGasUsedForOtherOperationsTransmission

M&R Fuel

 

2,549

O&M Gas Loss

1,083

Warehouse fuel

-

 

 

3,632

(c) Concept: ShipperSuppliedGasNetExcessOrDeficiencyTransmission

Since we administer the cost of gas used for fuel by means of a tracking mechanism, values are assigned pursuant to the requirements under our tariff provisions to the net excess or deficiency which results from shipper supplied gas as well as the disposition of the excesses and the sources of deficiencies.

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