46495/80510182.3/40712182.3/40725516274756O58651Questar Southern Trails Pipeline Company is a wholly owned subsidiary of QPC Holding Company.2Michele Cardiff3VP Controller & Chief Accounting Officer1928701 E. Cary Street Richmond, VA 232192254/407UTC0010863254/4071998-10-16Other Receipts (Specify) (footnote details)4815529Other Deliveries and Gas Used for Other Operations C001086 ferc:GasUtilityMember 2018-01-01 2018-09-30 C001086 0-16 2017-01-01 2017-09-30 C001086 0-4 2018-06-30 C001086 2018-09-30 C001086 0-2 2018-01-01 2018-09-30 C001086 Questar Southern Trails Pipeline Company-0 2018-01-01 2018-09-30 C001086 0-27 2017-01-01 2017-09-30 C001086 ferc:CreditedMember 2018-09-01 2018-09-30 C001086 2017-01-01 2017-09-30 C001086 2018-09-01 2018-09-30 C001086 0-2 2018-09-30 C001086 0-6 2018-01-01 2018-09-30 C001086 0-5 2017-01-01 2017-09-30 C001086 0-1 2018-06-30 C001086 ferc:DebitedMember 2018-07-01 2018-07-31 C001086 0-16 2018-01-01 2018-09-30 C001086 0-47 2018-01-01 2018-09-30 C001086 2018-01-01 2018-09-30 C001086 2017-12-31 C001086 0-10 2018-01-01 2018-09-30 C001086 0-29 Questar Southern Trails Pipeline Company -0 2018-01-01 2018-09-30 C001086 0-2 2018-07-01 2018-09-30 C001086 0-27 2018-01-01 2018-09-30 C001086 0-3 2018-01-01 2018-09-30 C001086 0-2 2018-01-01 2018-09-30 C001086 0-25 2018-01-01 2018-09-30 C001086 ferc:CreditedMember 2018-08-01 2018-08-31 C001086 0-56 2017-01-01 2017-09-30 C001086 0-58 2018-01-01 2018-09-30 C001086 0-1 2018-09-30 C001086 0-12 2018-01-01 2018-09-30 C001086 ferc:GasUtilityMember 2017-01-01 2017-09-30 C001086 ferc:DebitedMember 2018-08-01 2018-08-31 C001086 ferc:CreditedMember 2018-07-01 2018-07-31 C001086 2018-06-30 C001086 0-1 2018-01-01 2018-09-30 C001086 2017-09-30 C001086 0-3 2018-06-30 C001086 ferc:GeneralPlantMember ferc:GasUtilityMember 2018-01-01 2018-09-30 C001086 ferc:IntangiblePlantMember ferc:GasUtilityMember 2018-01-01 2018-09-30 C001086 ferc:RecourseRateMember 2018-09-01 2018-09-30 C001086 ferc:DebitedMember 2018-09-01 2018-09-30 C001086 0-1 2018-07-01 2018-09-30 C001086 ferc:RecourseRateMember 2018-08-01 2018-08-31 C001086 2017-07-01 2017-09-30 C001086 0-65 2018-01-01 2018-09-30 C001086 0-56 2018-01-01 2018-09-30 C001086 0-1 2018-01-01 2018-09-30 C001086 0-3 2018-07-01 2018-09-30 C001086 2018-07-01 2018-07-31 C001086 0-2 2018-07-01 2018-09-30 C001086 Questar Southern Trails Pipeline Company-0 2018-07-01 2018-09-30 C001086 0-6 2017-01-01 2017-09-30 C001086 ferc:RecourseRateMember 2018-07-01 2018-07-31 C001086 2018-07-01 2018-09-30 C001086 0-5 2018-01-01 2018-09-30 C001086 0-3 2018-01-01 2018-09-30 C001086 0-4 2018-07-01 2018-09-30 C001086 0-65 2017-01-01 2017-09-30 C001086 0-4 2018-01-01 2018-09-30 C001086 0-3 2018-09-30 C001086 2018-08-01 2018-08-31 C001086 0-4 2018-09-30 C001086 2016-12-31 C001086 0-4 2018-01-01 2018-09-30 C001086 ferc:TransmissionPlantMember ferc:GasUtilityMember 2018-01-01 2018-09-30 C001086 0-1 2018-06-30 C001086 0-1 2018-07-01 2018-09-30 C001086 Questar Southern Trails Pipeline Company -0 0-15 2018-01-01 2018-09-30 C001086 0-5 2018-01-01 2018-09-30 C001086 0-1 2018-09-30 C001086 0-2 2018-06-30 C001086 0-8 2018-01-01 2018-09-30 C001086 0-3 2018-07-01 2018-09-30 iso4217:USD ferc:dth pure
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)

Questar Southern Trails Pipeline Company
Year/Period of Report:

End of:
2018
/
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 form 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

Questar Southern Trails Pipeline Company
02 Year/ Period of Report


End of:
2018
/
Q3
03 Previous Name and Date of Change (if name changed during year)

/
04 Address of Principal Office at End of Year (Street, City, State, Zip Code)

333 South State Street, Salt Lake City, Utah 84111
05 Name of Contact Person

William Scott Breeding
06 Title of Contact Person

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

701 E. Cary Street - 16th Floor - Richmond, VA 23219
08 Telephone of Contact Person, Including Area Code

804-775-5513
09 This Report is An Original / A Resubmission

(1)
An Original

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

11/20/2018
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

Michele Cardiff
12 Title

VP Controller & Chief Accounting Officer
13 Signature

Michele Cardiff
14 Date Signed

11/20/2018
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:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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. On March 1, 2018, Questar Southern Trails Pipeline Company implemented its annual merit increase.

The projected annualized impact to the salaries/wages of Questar Southern Trails Pipeline employees

is $9,027.

 


9. Status of materially important legal proceedings

 

On December 22, 2017, Questar Southern Trails Pipeline Company (Southern Trails) filed with the

Federal Energy Regulatory Commission, in Docket CP18-39-000, an Abbreviated Application for

Order Authorizing Abandonment for the abandonment of its Natural Gas Act Section 7(c) certificate of

public convenience and necessity, its Part 284 blanket certificate to provide open access

transportation, including all jurisdictional services, and its blanket certificate issued under Part 157,

subpart f, and abandonment of all certified facilities dedicated to providing the jurisdictional services.

On May 9, 2018, FERC granted Southern Trails’ request for abandonment, subject to certain

customary conditions as described further in the FERC order of approval.

 

10. None

11. None

12. The following changes in company officers became effective in July 2018:

Appointments:

Scott C. Miller Vice President – Financial Management

Kristy R. Babcock Assistant Treasurer

 

13. None

 



Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
121,130,583
120,944,016
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200-201
184,012
200,788
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Total of lines 2 and 3)
200-201
121,314,595
121,144,804
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Provision for Depr., Amort., Depl. (108, 111, 115)
55,449,519
52,759,162
6
UtilityPlantNet
Net Utility Plant (Total of line 4 less 5)
65,865,076
68,385,642
7
NuclearFuel
Nuclear Fuel (120.1 thru 120.4, and 120.6)
8
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies
(Less) Accum. Provision for Amort., of Nuclear Fuel Assemblies (120.5)
9
NuclearFuelNet
Nuclear Fuel (Total of line 7 less 8)
10
UtilityPlantAndNuclearFuelNet
Net Utility Plant (Total of lines 6 and 9)
65,865,076
68,385,642
11
OtherGasPlantAdjustments
Utility Plant Adjustments (116)
122
12
GasStoredBaseGas
Gas Stored-Base Gas (117.1)
220
13
SystemBalancingGas
System Balancing Gas (117.2)
220
14
GasStoredInReservoirsAndPipelinesNoncurrent
Gas Stored in Reservoirs and Pipelines-Noncurrent (117.3)
220
15
GasOwedToSystemGas
Gas Owed to System Gas (117.4)
220
16
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
17
NonutilityProperty
Nonutility Property (121)
18
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Provision for Depreciation and Amortization (122)
19
InvestmentInAssociatedCompanies
Investments in Associated Companies (123)
222-223
20
InvestmentInSubsidiaryCompanies
Investments in Subsidiary Companies (123.1)
224-225
22
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
23
OtherInvestments
Other Investments (124)
222-223
24
SinkingFunds
Sinking Funds (125)
25
DepreciationFund
Depreciation Fund (126)
26
AmortizationFundFederal
Amortization Fund - Federal (127)
27
OtherSpecialFunds
Other Special Funds (128)
28
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
29
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
30
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Total of lines 17-20, 22-29)
31
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
32
Cash
Cash (131)
386,653
1,714,585
33
SpecialDeposits
Special Deposits (132-134)
34
WorkingFunds
Working Funds (135)
5,000
35
TemporaryCashInvestments
Temporary Cash Investments (136)
222-223
36
NotesReceivable
Notes Receivable (141)
37
CustomerAccountsReceivable
Customer Accounts Receivable (142)
21,949
131,602
38
OtherAccountsReceivable
Other Accounts Receivable (143)
39
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Provision for Uncollectible Accounts - Credit (144)
40
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
41
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Associated Companies (146)
30,534
2,929,976
42
FuelStock
Fuel Stock (151)
43
FuelStockExpensesUndistributed
Fuel Stock Expenses Undistributed (152)
44
ResidualsAndExtractedProducts
Residuals (Elec) and Extracted Products (Gas) (153)
45
PlantMaterialsAndOperatingSupplies
Plant Materials and Operating Supplies (154)
46
Merchandise
Merchandise (155)
47
OtherMaterialsAndSupplies
Other Materials and Supplies (156)
48
NuclearMaterialsHeldForSale
Nuclear Materials Held for Sale (157)
49
AllowanceInventoryAndWithheld
Allowances (158.1 and 158.2)
50
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
51
StoresExpenseUndistributed
Stores Expense Undistributed (163)
52
GasStoredCurrent
Gas Stored Underground-Current (164.1)
220
53
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2 thru 164.3)
220
54
Prepayments
Prepayments (165)
230
172,329
2,164,867
55
AdvancesForGas
Advances for Gas (166 thru 167)
56
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
666,267
57
RentsReceivable
Rents Receivable (172)
58
AccruedUtilityRevenues
Accrued Utility Revenues (173)
59
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
70,040
175,426
60
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
61
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
62
DerivativeInstrumentAssetsHedges
Derivative Instrument Assets - Hedges (176)
63
DerivativeInstrumentAssetsHedgesLongTerm
(Less) Long-Term Portion of Derivative Instrument Assests - Hedges (176)
64
CurrentAndAccruedAssets
TOTAL Current and Accrued Assets (Total of lines 32 thru 63)
1,347,772
7,121,456
65
DeferredDebitsAbstract
DEFERRED DEBITS
66
UnamortizedDebtExpense
Unamortized Debt Expense (181)
67
ExtraordinaryPropertyLosses
Extraordinary Property Losses (182.1)
230
68
UnrecoveredPlantAndRegulatoryStudyCosts
Unrecovered Plant and Regulatory Study Costs (182.2)
230
69
OtherRegulatoryAssets
Other Regulatory Assets (182.3)
232
24,983
20,764
70
PreliminarySurveyAndInvestigationCharges
Preliminary Survey and Investigation Charges (Electric)(183)
71
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges
Preliminary Survey and Investigation Charges (Gas)(183.1 and 183.2)
72
ClearingAccounts
Clearing Accounts (184)
73
TemporaryFacilities
Temporary Facilities (185)
74
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
1,568,889
75
DeferredLossesFromDispositionOfUtilityPlant
Deferred Losses from Disposition of Utility Plant (187)
76
ResearchDevelopmentAndDemonstrationExpenditures
Research, Development, and Demonstration Expend. (188)
77
UnamortizedLossOnReacquiredDebt
Unamortized Loss on Reacquired Debt (189)
78
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234-235
8,686,242
8,716,449
79
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
80
DeferredDebits
TOTAL Deferred Debits (Total of lines 66 thru 79)
10,280,114
8,737,213
81
AssetsAndOtherDebits
TOTAL Assets and Other Debits (Total of lines 10-15,30,64,and 80)
77,492,962
84,244,311


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
1
1
3
PreferredStockIssued
Preferred Stock Issued (204)
250-251
4
CapitalStockSubscribed
Capital Stock Subscribed (202, 205)
252
5
StockLiabilityForConversion
Stock Liability for Conversion (203, 206)
252
6
PremiumOnCapitalStock
Premium on Capital Stock (207)
252
7
OtherPaidInCapital
Other Paid-In Capital (208-211)
253
72,292,305
72,292,305
8
InstallmentsReceivedOnCapitalStock
Installments Received on Capital Stock (212)
252
9
DiscountOnCapitalStock
(Less) Discount on Capital Stock (213)
254
10
CapitalStockExpense
(Less) Capital Stock Expense (214)
254
11
RetainedEarnings
Retained Earnings (215, 215.1, 216)
118-119
89,809,573
83,730,954
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118-119
13
ReacquiredCapitalStock
(Less) Reacquired Capital Stock (217)
250-251
14
AccumulatedOtherComprehensiveIncome
Accumulated Other Comprehensive Income (219)
117
15
ProprietaryCapital
TOTAL Proprietary Capital (Total of lines 2 thru 14)
17,517,267
11,438,648
16
LongTermDebtAbstract
LONG TERM DEBT
17
Bonds
Bonds (221)
256-257
18
ReacquiredBonds
(Less) Reacquired Bonds (222)
256-257
19
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256-257
57,898,000
46,400,000
20
OtherLongTermDebt
Other Long-Term Debt (224)
256-257
21
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
258-259
22
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Dr (226)
258-259
23
CurrentPortionOfLongTermDebt
(Less) Current Portion of Long-Term Debt
24
LongTermDebt
TOTAL Long-Term Debt (Total of lines 17 thru 23)
57,898,000
46,400,000
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases-Noncurrent (227)
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
17,572
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
34
AssetRetirementObligations
Asset Retirement Obligations (230)
306,920
293,074
35
OtherNoncurrentLiabilities
TOTAL Other Noncurrent Liabilities (Total of lines 26 thru 34)
324,492
293,074
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
CurrentPortionOfLongTermDebt
Current Portion of Long-Term Debt
38
NotesPayable
Notes Payable (231)
39
AccountsPayable
Accounts Payable (232)
18,046,978
16,550,135
40
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
41
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
173,966
417,010
42
CustomerDeposits
Customer Deposits (235)
207,127
205,172
43
TaxesAccrued
Taxes Accrued (236)
262-263
12,380,848
533
44
InterestAccrued
Interest Accrued (237)
45
DividendsDeclared
Dividends Declared (238)
46
MaturedLongTermDebt
Matured Long-Term Debt (239)
47
MaturedInterest
Matured Interest (240)
48
TaxCollectionsPayable
Tax Collections Payable (241)
7,811
6,793
49
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
268
223,678
140,594
50
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
51
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
52
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
53
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
54
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities - Hedges
55
CurrentAndAccruedLiabilities
TOTAL Current and Accrued Liabilities (Total of lines 37 thru 54)
6,278,712
17,319,171
56
DeferredCreditsAbstract
DEFERRED CREDITS
57
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
58
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
59
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
60
OtherDeferredCredits
Other Deferred Credits (253)
269
146,806
40,524
61
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
11,761,505
11,783,853
62
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reacquired Debt (257)
260
63
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accumulated Deferred Income Taxes - Accelerated Amortization (281)
64
AccumulatedDeferredIncomeTaxesOtherProperty
Accumulated Deferred Income Taxes - Other Property (282)
18,384,732
19,078,006
65
AccumulatedDeferredIncomeTaxesOther
Accumulated Deferred Income Taxes - Other (283)
215,982
768,331
66
DeferredCredits
TOTAL Deferred Credits (Total of lines 57 thru 65)
30,509,025
31,670,714
67
LiabilitiesAndOtherCredits
TOTAL Liabilities and Other Credits (Total of lines 15,24,35,55,and 66)
77,492,962
84,244,311


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
102,001
2,341,879
33,810
624,425
102,001
2,341,879
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
317-325
4,276,633
4,892,474
1,340,198
1,501,118
4,276,633
4,892,474
5
MaintenanceExpense
Maintenance Expenses (402)
317-325
572,052
928,592
109,591
185,625
572,052
928,592
6
DepreciationExpense
Depreciation Expense (403)
336-338
2,713,173
2,720,374
899,019
902,721
2,713,173
2,720,374
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336-338
1,187
477
191
159
1,187
477
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336-338
1,819
1,226
62
919
1,819
1,226
9
AmortizationOfGasPlantAcquisitionAdjustments
Amortization of Utility Plant Acu. Adjustment (406)
336-338
10
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts
Amort. of Prop. Losses, Unrecovered Plant and Reg. Study Costs (407.1)
11
AmortizationOfConversionExpenses
Amortization of Conversion Expenses (407.2)
12
RegulatoryDebits
Regulatory Debits (407.3)
79,632
120,136
26,230
81,881
79,632
120,136
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
83,725
104,530
83,725
104,530
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262-263
379,678
410,323
115,253
129,295
379,678
410,323
15
IncomeTaxesUtilityOperatingIncome
Income Taxes-Federal (409.1)
262-263
879,568
11,686,514
260,351
10,802,646
879,568
11,686,514
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes-Other (409.1)
262-263
509,590
1,931,805
145,774
1,785,990
509,590
1,931,805
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision of Deferred Income Taxes (410.1)
234-235
434,836
10,958,768
149,320
11,792,397
434,836
10,958,768
18
ProvisionForDeferredIncomeTaxesCreditUtilityOperatingIncome
(Less) Provision for Deferred Income Taxes-Credit (411.1)
234-235
1,647,600
572,981
1,647,600
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adjustment-Net (411.4)
20
GainsFromDispositionOfPlant
(Less) Gains from Disposition of Utility Plant (411.6)
21
LossesFromDispositionOfUtilityPlant
Losses from Disposition of Utility Plant (411.7)
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
24
AccretionExpense
Accretion Expense (411.10)
13,847
11,737
4,686
3,912
13,847
11,737
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Total of lines 4 thru 24)
5,350,000
6,321,258
1,665,444
2,009,391
5,350,000
6,321,258
26
NetUtilityOperatingIncome
Net Utility Operating Income (Total of lines 2 less 25) (Carry forward to line 27)
5,247,999
3,979,379
1,631,634
1,384,966
5,247,999
3,979,379
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)
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Expense of Merchandising, Job & Contract Work (416)
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
386
1,026
1,609
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
386
1,026
1,609
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
37
InterestAndDividendIncome
Interest and Dividend Income (419)
4,240
24
1,028
10
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
21,572
13,683
41
OtherIncome
TOTAL Other Income (Total of lines 31 thru 40)
4,240
21,596
1,028
13,693
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
45
Donations
Donations (426.1)
340
124
121
46
LifeInsurance
Life Insurance (426.2)
47
Penalties
Penalties (426.3)
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Expenditures for Certain Civic, Political and Related Activities (426.4)
49
OtherDeductions
Other Deductions (426.5)
6,676
187,446
6,676
128,543
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
340
6,800
187,446
6,797
128,543
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262-263
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262-263
486
1,364
1,470
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262-263
286
864
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Income Taxes (410.2)
234-235
9,532
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Credit (411.2)
234-235
2,002
57
InvestmentTaxCreditAdjustmentsNonutilityOperations
Investment Tax Credit Adjustments-Net (411.5)
58
InvestmentTaxCredits
(Less) Investment Tax Credits (420)
59
TaxesOnOtherIncomeAndDeductions
TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)
6,758
1,364
2,334
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
9,318
164,486
5,491
114,850
61
InterestChargesAbstract
INTEREST CHARGES
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
63
AmortizationOfDebtDiscountAndExpense
Amortization of Debt Disc. and Expense (428)
258-259
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reacquired Debt (428.1)
65
AmortizationOfPremiumOnDebtCredit
(Less) Amortization of Premium on Debt-Credit (429)
258-259
66
AmortizationOfGainOnReacquiredDebtCredit
(Less) Amortization of Gain on Reacquired Debt-Credit (429.1)
67
InterestOnDebtToAssociatedCompanies
Interest on Debt to Associated Companies (430)
340
810,945
535,578
332,681
207,863
68
OtherInterestExpense
Other Interest Expense (431)
340
10,357
1,291
2,447
530
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Credit (432)
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
821,302
536,869
335,128
208,393
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
6,078,619
4,680,734
1,972,253
1,708,209
72
ExtraordinaryItemsAbstract
EXTRAORDINARY ITEMS
73
ExtraordinaryIncome
Extraordinary Income (434)
74
ExtraordinaryDeductions
(Less) Extraordinary Deductions (435)
75
NetExtraordinaryItems
Net Extraordinary Items (Total of line 73 less line 74)
76
IncomeTaxesExtraordinaryItems
Income Taxes-Federal and Other (409.3)
262-263
77
ExtraordinaryItemsAfterTaxes
Extraordinary Items after Taxes (line 75 less line 76)
78
NetIncomeLoss
Net Income (Total of line 71 and 77)
6,078,619
4,680,734
1,972,253
1,708,209


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3
Preceding Quarter/Year to Date Changes in Fair Value
4
Total (lines 2 and 3)
4,680,734
5
Balance of Account 219 at End of Preceding Quarter/Year
6
Balance of Account 219 at Beginning of Current Year
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8
Current Quarter/Year to Date Changes in Fair Value
9
Total (lines 7 and 8)
6,078,619
10
Balance of Account 219 at End of Current Quarter/Year


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:


End of:
2018
/
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
83,730,954
63,586,421
2
ChangesAbstract
Changes (Identify by prescribed retained earnings accounts)
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
3.1
AdjustmentsToRetainedEarningsCredit
TOTAL Credits to Retained Earnings (Account 439) (footnote details)
3.2
AdjustmentsToRetainedEarningsCredit
TOTAL Debits to Retained Earnings (Account 439) (footnote details)
3.3
AdjustmentsToRetainedEarningsCredit
Balance Transferred from Income (Acct 433 less Acct 418.1)
6,078,619
4,680,734
4
AdjustmentsToRetainedEarningsCredit
Adjustments to Retained Earnings Credit (Debit)
7
AppropriationsOfRetainedEarningsAbstract
Appropriations of Retained Earnings (Account 436)
7.1
AppropriationsOfRetainedEarnings
TOTAL Appropriations of Retained Earnings (Account 436) (footnote details)
8
AppropriationsOfRetainedEarnings
Appropriations of Retained Earnings Amount
9
DividendsDeclaredPreferredStockAbstract
Dividends Declared-Preferred Stock (Account 437)
9.1
DividendsDeclaredPreferredStock
TOTAL Dividends Declared-Preferred Stock (Account 437) (footnote details)
10
DividendsDeclaredPreferredStock
Dividends Declared-Preferred Stock Amount
11
DividendsDeclaredCommonStockAbstract
Dividends Declared-Common Stock (Account 438)
11.1
DividendsDeclaredCommonStock
TOTAL Dividends Declared-Common Stock (Account 438) (footnote details)
12
DividendsDeclaredCommonStock
Dividends Declared-Common Stock Amount
13
TransfersFromUnappropriatedUndistributedSubsidiaryEarnings
Transfers from Account 216.1, Unappropriated Undistributed Subsidiary Earnings
14
UnappropriatedRetainedEarnings
Balance-End of Period (Total of lines 1, 4, 5, 6, 8, 10, 12, and 13)
89,809,573
68,267,155
15
AppropriatedRetainedEarningsAbstract
APPROPRIATED RETAINED EARNINGS (Account 215)
16
AppropriatedRetainedEarnings
TOTAL Appropriated Retained Earnings (Account 215) (footnote details)
17
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract
APPROPRIATED RETAINED EARNINGS-AMORTIZATION RESERVE, FEDERAL (Account 215.1)
18
AppropriatedRetainedEarningsAmortizationReserveFederal
TOTAL Appropriated Retained Earnings-Amortization Reserve, Federal (Account 215.1)
19
AppropriatedRetainedEarningsIncludingReserveAmortization
TOTAL Appropriated Retained Earnings (Accounts 215, 215.1) (Total of lines of 16 and 18)
20
RetainedEarnings
TOTAL Retained Earnings (Accounts 215, 215.1, 216) (Total of lines 14 and 19)
89,809,573
68,267,155
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)
23
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings for Year (Credit) (Account 418.1)
24
DividendsReceived
(Less) Dividends Received (Debit)
25
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
Other Changes (Explain)
25.1
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
Other Changes (Explain)
26
UnappropriatedUndistributedSubsidiaryEarnings
Balance-End of Year


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:


End of:
2018
/
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)
6,078,619
4,680,734
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
2,711,986
2,755,800
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of (Specify) (footnote details)
(a)
1,819
1,226
6
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
1,205,234
10,958,768
7
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustments (Net)
8
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
(b)
599,228
(j)
11,991,122
9
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
10
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
11
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
9,431,495
207,747
12
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
(c)
4,219
(k)
282,180
13
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
32,531
10,607
14
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
15
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
16
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other Adjustments to Cash Flows from Operating Activities
16.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other (footnote details):
(d)
1,999,828
2,041,083
18
NetCashProvidedByUsedInOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 16)
12,637,693
978,805
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)
(e)
193,239
(l)
105,361
23
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
24
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
25
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
26
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
27
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other Construction and Acquisition of Plant, Investment Activities
27.1
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription
Other (footnote details):
(m)(n)
102,080
28
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 22 thru 27)
(f)
193,239
(o)
207,441
30
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
31
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
21,572
33
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Investments in and Advances to Associated and Subsidiary Companies
34
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies
Contributions and Advances from Associated and Subsidiary Companies
36
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
38
PurchaseOfInvestmentSecurities
Purchase of Investment Securities (a)
39
ProceedsFromSalesOfInvestmentSecurities
Proceeds from Sales of Investment Securities (a)
40
LoansMadeOrPurchased
Loan Made or Purchased
41
CollectionsOnLoans
Collections on Loans
43
NetIncreaseDecreaseInReceivablesInvestingActivities
Net (Increase) Decrease in Receivables
44
NetIncreaseDecreaseInInventoryInvestingActivities
Net (Increase) Decrease in Inventory
45
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities
Net (Increase) Decrease in Allowances Held for Speculation
46
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
47
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other Adjustments to Cash Flows from Investment Activities:
47.1
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Other (footnote details):
49
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 28 thru 47)
193,239
185,869
51
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
52
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
53
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Proceeds from Issuance of Long-Term Debt (b)
54
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Proceeds from Issuance of Preferred Stock
55
ProceedsFromIssuanceOfCommonStockFinancingActivities
Proceeds from Issuance of Common Stock
56
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Net Increase in Debt (Long Term Advances)
56.1
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (footnote details): Paid-In Capital
(g)
17,838,000
3,500,000
56.2
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (footnote details):
57
NetIncreaseInShortTermDebt
Net Increase in Short-term Debt (c)
59
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total of lines 53 thru 58)
17,838,000
3,500,000
61
PaymentsForRetirementAbstract
Payments for Retirement
62
PaymentsForRetirementOfLongTermDebtFinancingActivities
Payments for Retirement of Long-Term Debt (b)
63
PaymentsForRetirementOfPreferredStockFinancingActivities
Payments for Retirement of Preferred Stock
64
PaymentsForRetirementOfCommonStockFinancingActivities
Payments for Retirement of Common Stock
65
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other Retirements
65.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Other (footnote details):
(h)(i)
6,340,000
(p)
2,000,000
66
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
67
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other Adjustments to Financing Cash Flows
68
DividendsOnPreferredStock
Dividends on Preferred Stock
69
DividendsOnCommonStock
Dividends on Common Stock
70
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 59 thru 69)
11,498,000
1,500,000
73
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract
Net Increase (Decrease) in Cash and Cash Equivalents
74
NetIncreaseDecreaseInCashAndCashEquivalents
(Total of line 18, 49 and 71)
1,332,932
335,326
76
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
1,719,585
5,000
78
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
386,653
340,326


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:


End of:
2018
/
Q3
FOOTNOTE DATA

(a) Concept: NoncashAdjustmentsToCashFlowsFromOperatingActivities

 

 

Nine Months Ended September 30,

Account

Description

2018

 

2017

404.3

Amortization of Intangible Plant

$ 1,819

 

$ 1,226

 

 

 

 

(b) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
Original value: -599228
(c) Concept: NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Original value: -4219
(d) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities

 

 

Nine Months Ended September 30,

Account

Description

2018

 

2017

421.1

Gain or Loss on Sale of Assets

$ -

 

$ (21,572)

165

Prepayments

1,992,538

 

2,008,581

174

Miscellaneous Current and Accrued Assets

41,470

 

(20,326)

184

Clearing

-

 

13,848

186

Misc Deferred Debits

(61,029)

 

-

411.10

Accretion

13,847

 

11,738

235

Customer Deposits

1,955

 

4,044

253

Miscellaneous Deferred Credits

11,047

 

44,770

 

 

$ 1,999,828

 

$ 2,041,083

 

 

 

 

(e) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Original value: -193239
(f) Concept: CashOutflowsForPlant
Original value: -193239
(g) Concept: OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities

 

 

Nine Months Ended September 30,

Account

Description

2018

 

2017

223

Advances from QPC Holding Company

$ 17,838,000

 

$ 3,500,000

(h) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Original value: -6340000
(i) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities

 

 

Nine Months Ended September 30,

Account

Description

2018

 

2017

223

Repayment of Advances from QPC Holding Company

$ (6,340,000)

 

$ (2,000,000)

(j) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
Original value: -11991122
(k) Concept: NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Original value: -282180
(l) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Original value: -105361
(m) Concept: OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Original value: -102080
(n) Concept: OtherConstructionAndAcquisitionOfPlantInvestmentActivities

 

 

Nine Months Ended September 30,

Account

Description

2018

 

2017

108

Intercompany Transfers-Out

$ -

 

$ (86,144)

108

Dismantling

-

 

(15,936)

 

 

$ -

 

$ (102,080)

 

 

 

 

(o) Concept: CashOutflowsForPlant
Original value: -207441
(p) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Original value: -2000000

Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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.

Basis of Presentation of Interim Financial Statements

 

Questar Southern Trails Pipeline Company’s (Southern Trails) unaudited financial statements are prepared in accordance with the requirements of the Federal Energy Regulatory Commission (FERC) as set forth in the Uniform System of Accounts (USofA) and published accounting releases which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America (GAAP). Refer to Southern Trails’ FERC Form No. 2A for the year ended December 31, 2017, for principal differences between FERC and GAAP. Due to the adoption of Accounting Standard Codification 606, Revenue from Contracts with Customers, effective January 1, 2018, no differences between FERC and GAAP exist related to the value of fuel retained and booked as previously described in Southern Trails’ December 2017 FERC Form No. 2 for the year ended December 31, 2017.

 


Statement of Cash Flows

Nine Months Ended September 30,

(millions)

 

2018

 

2017

Supplemental Disclosure

 

 

 

 

Cash paid during the period for interest *

$

1.4

$

0.5

Cash paid during the period for income taxes

 

17.3

 

1.7

Cash received during the period for income taxes

 

7.5

 

-

 

* Includes $0.7 million of interest paid to the Internal Revenue Service

 

Note 1. Significant Accounting Policies

 

As permitted by FERC rules, these unaudited financial statements exclude certain footnote disclosures normally included in annual audited financial statements prepared in accordance with the USofA. These unaudited financial statements should be read in conjunction with the financial statements and notes in Southern Trails’ FERC Form No. 2A for the year ended December 31, 2017.

 

In the opinion of management, the unaudited financial statements contain all adjustments, including normal recurring accruals, necessary to present fairly Southern Trails’ financial position at September 30, 2018, its results of operations for the three and nine months ended September 30, 2018 and 2017, and its cash flows for the nine months ended September 30, 2018 and 2017. Such adjustments are normal and recurring in nature unless otherwise noted.

 

Southern Trails makes certain estimates and assumptions in preparing its financial statements. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses for the periods presented. Actual results may differ from those estimates.

 

The results of operations and cash flows for the interim periods are not necessarily indicative of the results that may be expected for the full year. The straight-fixed-variable rate design, which allows for recovery of substantially all fixed costs in demand or reservation charges, reduces the earnings impact of volume changes on gas transportation operations.

 

Impairment of Long-Lived Assets

In the third quarter of 2013, Southern Trails recorded a noncash GAAP impairment of its entire investment in the eastern segment of the pipeline of $80.6 million, or $52.4 million after income taxes. The impairment of the eastern segment has not been reflected in this filing in accordance with FERC guidance. An additional noncash impairment was recorded in the third quarter of 2016 for both GAAP and FERC related to the western segment of $23.3 million, or $14.2 million after income taxes (FERC basis). The western segment of Southern Trails Pipeline extends 96 miles from Whitewater to Long Beach, CA and was never placed into gas service.

At September 30, 2018, the remaining net book value of utility plant was approximately $65.9 million. The difference between Southern Trails’ FERC based Equity and GAAP based Equity at September 30, 2018 is reconciled as follows:

 

(millions)

Common Stock and Paid-in Capital

Retained Earnings

Total Equity

September 30, 2018 FERC Based Equity

$ 72.3

$ (89.8)

$ (17.5)

Reconciling items (pre-tax):

 

 

 

Asset impairment

 

(80.6)

(80.6)

Reduction in depreciation expense

 

18.3

18.3

Plant expenditures charged to operating expense

 

(3.6)

(3.6)

Income tax benefit

 

26.6

26.6

September 30, 2018 GAAP Based Equity

$ 72.3

$ (129.1)

$ (56.8)

 

In November 2017, Southern Trails entered into an agreement to sell a portion of its eastern segment to the Navajo Tribal Utility Authority (NTUA) in exchange for Southern Trails making various payments to or on behalf of NTUA of approximately $16.7 million, which are considered costs to sell the assets. These payments primarily relate to the post-closing termination of specified existing right-of-way agreements, one-time transaction payment to NTUA and the cost of system improvements necessary to ready the assets for use by NTUA as a distribution system. In December 2017, Southern Trails recognized a charge and accompanying contingent liability of $16.7 million in accounts 426.5 – Other Deductions and 232 – Accounts Payable, respectively.

 

In December 2017, Southern Trails filed with FERC an application seeking authority to abandon its entire pipeline, in part by sale to NTUA and the remainder to be abandoned in place. The sale to NTUA will close upon receipt of all necessary regulatory consents, including FERC’s approval of Southern Trail’s abandonment filing, which was issued by the Commission on May 9, 2018, subject to certain customary conditions described further in the FERC order. When all the necessary approvals are received, Southern Trails will recognize an impairment loss for any remaining net book value at that time.



Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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)
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
8
UtilityPlantInServiceClassifiedAndUnclassified
TOTAL Utility Plant (Total of lines 3 thru 7)
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
11
ConstructionWorkInProgress
Construction Work in Progress
184,012
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
13
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Total of lines 8 thru 12)
121,314,595
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
55,449,519
15
UtilityPlantNet
Net Utility Plant (Total of lines 13 and 14)
65,865,076
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
22
DepreciationAmortizationAndDepletionUtilityPlantInService
TOTAL In Service (Total of lines 18 thru 21)
23
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract
Leased to Others
24
DepreciationUtilityPlantLeasedToOthers
Depreciation
25
AmortizationAndDepletionUtilityPlantLeasedToOthers
Amortization and Depletion
26
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers
TOTAL Leased to Others (Total of lines 24 and 25)
27
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract
Held for Future Use
28
DepreciationUtilityPlantHeldForFutureUse
Depreciation
29
AmortizationUtilityPlantHeldForFutureUse
Amortization
30
DepreciationAndAmortizationUtilityPlantHeldForFutureUse
TOTAL Held for Future Use (Total of lines 28 and 29)
31
AbandonmentOfLeases
Abandonment of Leases (Natural Gas)
32
AmortizationOfPlantAcquisitionAdjustment
Amortization of Plant Acquisition Adjustment
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
TOTAL Accum. Provisions (Should agree with line 14 above)(Total of lines 22, 26, 30, 31, and 32)
55,449,519


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
17,576
16,756
2
Productions-Manufactured Gas
3
Production and Gathering-Natural Gas
4
Products Extraction-Natural Gas
5
Underground Gas Storage
6
Other Storage Plant
7
Base Load LNG Terminaling and Processing Plant
8
Transmission
120,291,066
54,568,792
9
Distribution
10
General
821,941
863,971
11
TOTAL (total of lines 1 thru 10)
121,130,583
55,449,519


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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)
Annual Charge Adjustment - per: Oct-Sep
6,921
24,983
6,921
24,983
2
(b)
Fuel Gas Reimbursement - Current
37,651
37,651
3
(c)
Fuel Gas Amortization - per: Jul-Jun
28,767
28,767
40
TOTAL
6,921
91,401
73,339
24,983


FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Docket RP13-1186

(b) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Docket RP18-840

(c) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Docket RP18-840


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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)
Transmission Cash Out
28,811
1,273
27,538
2
(b)
Fuel Gas Reimbursement - Current
53,631
91,907
22,755
(e)
15,521
3
(c)
Fuel Gas Amortization - per: Jul-Jun
26,856
13,350
125,767
85,561
4
(d)
Income Taxes Refundable Through Future Rates
11,646,353
17,574
11,663,927
45
Total
11,701,939
106,530
166,096
11,761,505


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
Q3
FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Docket RP02-318

(b) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Docket RP18-840

(c) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Docket RP18-840

(d) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Account 254 predominately reflects Questar Southern Trails Pipeline Company's estimate of amounts probable of refund to customers for excess deferred income taxes (EDIT) resulting from the reduction in the corporate income tax rate to 21% under the 2017 Tax Reform Act. Refer to Southern Trails Pipeline Company’s FERC Form No.2-A Note 4 to the financial statements for the year ended December 31, 2017.

(e) Concept: OtherRegulatoryLiabilities

Balance was reclassified from Account 182.3 to net with the Fuel Gas Amortization balance for reporting purposes.


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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)
2
Transportation of Gas for Others (489.2 and 489..3)
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
Total Transportation (Other than Gathering)
64
Storage (489.4)
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
Total Storage
91
Gathering (489.1)
92
Gathering-Firm
93
Gathering-Interruptible
94
Total Gathering (489.1)
95
Additional Revenues
96
Products Sales and Extraction (490-492)
97
Rents (493-494)
98
(495) Other Gas Revenues
99
(496) (Less) Provision for Rate Refunds
100
Total Additional Revenues
101
Total Operating Revenues (Total of Lines 1,63,90,94 & 100)


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
2 CommercialAndIndustrialSalesAbstract (481) Commercial and Industrial Sales
3 OtherSalesToPublicAuthoritiesAbstract (482) Other Sales to Public Authorities
4 SalesForResaleAbstract (483) Sales for Resale
5 InterdepartmentalSalesAbstract (484) Interdepartmental Sales
6 SalesOfGasNotInlcudingIntracompanyTransfersAbstract Total Sales (Lines 1 to 5)
7 IntracompanyTransfersAbstract (485) Intracompany Transfers
8 ForfeitedDiscountsAbstract (487) Forfeited Discounts
9 MiscellaneousServiceRevenuesAbstract (488) Miscellaneous Service Revenues
10 RevenuesFromTransportationOfGasOfOthersThroughGatheringFacilitiesAbstract (489.1) Revenues from Transportation of Gas of Others Through Gathering Facilities
11 RevenuesFromTransportationOfGasOfOthersThroughTransmissionFacilitiesAbstract (489.2) Revenues from Transportation of Gas of Others Through Transmission Facilities
102,001
85,406
12 RevenuesFromTransportationOfGasOfOthersThroughDistributionFacilitiesAbstract (489.3) Revenues from Transportation of Gas of Others Through Distribution Facilities
13 RevenuesFromStoringGasOfOthersAbstract (489.4) Revenues from Storing Gas of Others
14 SalesOfProductsExtractedFromNaturalGasAbstract (490) Sales of Prod. Ext. from Natural Gas
15 RevenuesFromNaturalGasProcessedByOthersAbstract (491) Revenues from Natural Gas Proc. by Others
16 IncidentalGasolineAndOilSalesAbstract (492) Incidental Gasoline and Oil Sales
17 RentFromGasPropertyAbstract (493) Rent from Gas Property
18 InterdepartmentalRentsAbstract (494) Interdepartmental Rents
19 OtherGasRevenuesAbstract (495) Other Gas Revenues
20 OperatingRevenuesBeforeProvisionForRateRefundsAbstract Subtotal:
102,001
21 ProvisionForRateRefundsAbstract (496) (Less) Provision for Rate Refunds
22 OperatingRevenuesAbstract TOTAL
102,001


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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)
4
NaturalGasProductionAndGatheringPlantAbstract Natural Gas Production and Gathering
5
ProductionOperationExpense (750-760) Operation
6
ProductionMaintenanceExpense (761-769) Maintenance
7
NaturalGasProductionAndGatheringPlantExpense Total Natural Gas Production and Gathering (lines 5 and 6)
8
ProductionExtractionAbstract Production Extraction
9
ProductsExtractionOperationExpense (770-783) Operation
10
ProductsExtractionMaintenanceExpense (784-791) Maintenance
11
ProductsExtractionExpense Total Production Extraction (lines 9 and 10)
12
ExplorationAndDevelopment (795-798) Exploration and Development Expenses
13
OtherGasSupplyExpensesAbstract Other Gas Supply Expenses
14
OtherGasSupplyExpensesOperationAbstract Operation
15
NaturalGasWellHeadPurchases (800) Natural Gas Well Head Purchases
16
NaturalGasWellHeadPurchasesIntracompanyTransfers (800.1) Natural Gas Well Head Purchases, Intra company Transfers
17
NaturalGasFieldLinePurchases (801) Natural Gas Field Line Purchases
18
NaturalGasGasolinePlantOutletPurchases (802) Natural Gasoline Plant Outlet Purchases
19
NaturalGasTransmissionLinePurchases (803) Natural Gas Transmission Line Purchases
20
NaturalGasCityGatePurchases (804) Natural Gas City Gate Purchases
21
LiquefiedNaturalGasPurchases (804.1) Liquefied Natural Gas Purchases
22
OtherGasPurchases (805) Other Gas Purchases
23
PurchasedGasCostAdjustments (805.1) (Less) Purchase Gas Cost Adjustments
24
PurchasedGasOperationExpenses Total Purchased Gas (lines 15 through 23)
25
ExchangeGas (806) Exchange Gas
4,094
26
PurchasedGasExpensesAbstract Purchased Gas Expenses
27
WellExpensePurchasedGas (807.1) Well Expense - Purchased Gas
28
OperationOfPurchasedGasMeasuringStations (807.2) Operation of Purchased Gas Measuring Stations
29
MaintenanceOfPurchasedGasMeasuringStations (807.3) Maintenance of Purchased Gas Measuring Stations
30
PurchasedGasCalculationsExpenses (807.4) Purchased Gas Calculations Expenses
31
OtherPurchasedGasExpenses (807.5) Other Purchased Gas Expenses
32
PurchasedGasExpenses Total Purchased Gas Expenses (lines 27 thru 31)
33
GasWithdrawnFromStorageDebt (808.1) Gas Withdrawn from Storage-Debit
34
GasDeliveredToStorageCredit (808.2) (Less) Gas Delivered to Storage - Credit
35
WithdrawalsOfLiquefiedNaturalGasHeldForProcessingDebit (809.1) Withdrawals of Liquefield Natural Gas for Processing - Debit
36
DeliveriesOfNaturalGasForProcessingCredit (809.2) (Less) Deliveries of Natural Gas Processing - Credit
37
GasUsedInUtilityOperationAbstract Gas Used in Utility Operation - Credit
38
GasUsedForCompressorStationFuelCredit (810) Gas Used for Compressor Station Fuel - Credit
15,550
39
GasUsedForProductsExtractionCredit (811) Gas Used for Products Extraction - Credit
40
GasUsedForOtherUtilityOperationsCredit (812) Gas Used for Other Utility Operations - Credit
2,363
41
GasUsedInUtilityOperationCredit Total Gas Used in Utility Operations - Credit (Lines 38 thru 40)
17,913
42
OtherGasSupplyExpenses (813) Other Gas Supply Expense
6,352
43
OtherGasSupplyExpensesOperation Total Other Gas Supply Expenses (Lines 24, 25, 32, 33, thru 36, 42, less 41)
20,171
44
ProductionExpenses Total Production Expenses (Lines 3,7,11,12, and 43)
20,171


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
4
UndergroundStorageMaintenanceExpenses (830-837) Maintenance
5
UndergroundStorageExpenses Total Underground Storage Expenses (Lines 3 and 4)
6
OtherStorageExpensesAbstract OTHER STORAGE EXPENSES
7
OtherStorageOperationExpenses (840-842.3) Operations
8
OtherStorageMaintenanceExpenses (843.1-843.9) Maintenance
9
OtherStorageExpenses Total Other Storage Expenses (lines 7 and 8)
10
LiquifiedNaturalGasTerminalingAndProcessingExpensesAbstract LIQUEFIED NATURAL GAS TERMINALING AND PROCESSING
11
LiquifiedNaturalGasTerminalingAndProcessingOperationExpenses (844.1-846.2) Operations
12
LiquifiedNaturalGasTerminalingAndProcessingMaintenanceExpenses (847.1-847.8) Maintenance
13
LiquifiedNaturalGasTerminalingAndProcessingExpenses Total Liquefied Natural Gas Terminaling and Processing (Lines 11 and 12)
14
TransmissionExpensesAbstract TRANSMISSION EXPENSES
15
TransmissionExpensesOperationAbstract Transmission Operation Expenses
16
OperationSupervisionAndEngineeringGasTransmissionExpenses (850) Operation Supervision and Engineering
303,466
17
SystemControlAndLoadDispatchingGas (851) System Control and Load Dispatching
119,141
18
CommunicationSystemExpenses (852) Communication System Expenses
19
CompressorStationLaborAndExpensesTransmissionExpenses (853) Compressor Station Labor and Expenses
75,764
20
GasForCompressorStationFuel (854) Gas for Compressor Station Fuel
15,550
21
OtherFuelAndPowerForCompressorStations (855) Other Fuel and Power for Compressor Stations
22
MainsExpenses (856) Mains Expenses
755,676
23
MeasuringAndRegulatingStationExpensesTransmissionExpenses (857) Measuring and Regulating Station Expenses
55,410
24
TransmissionAndCompressionOfGasByOthers (858) Transmission and Compression of Gas by Others
25
OtherExpensesGasTransmission (859) Other Expenses
77,160
26
RentsGasTransmissionExpense (860) Rents
2,314,067
27
TransmissionOperationExpense Total Transmission Operation Expenses (Lines 16 through 26)
3,716,234
28
TransmissionExpensesMaintenanceAbstract Transmission Maintenance Expenses
29
MaintenanceSupervisionAndEngineeringGasTransmissionExpenses (861) Maintenance Supervision and Engineering
189,446
30
MaintenanceOfStructuresAndImprovementsTransmissionExpenses (862) Maintenance of Structures and Improvements
31
MaintenanceOfMainsTransmissionExpenses (863) Maintenance of Mains
328,426
32
MaintenanceOfCompressorStationEquipmentTransmissionExpenses (864) Maintenance of Compressor Station Equipment
3,142
33
MaintenanceOfMeasuringAndRegulatingStationEquipment (865) Maintenance of Measuring and Regulating Equipment
43,092
34
MaintenanceOfCommunicationEquipmentGasTransmission (866) Maintenance of Communication Equipment
35
MaintenanceOfOtherEquipmentTransmissionExpenses (867) Maintenance of Other Equipment
36
TransmissionMaintenanceExpensesGas Total Transmission Maintenance Expenses (Lines 29 through 35)
564,106
37
TransmissionExpenses Total Transmission Expenses (lines 27 and 36)
4,280,340
38
DistributionExpensesAbstract DISTRIBUTION EXPENSES
39
DistributionOperationExpensesGas (870-881) Operation Expenses
40
DistributionMaintenanceExpenseGas (885-894) Maintenance
41
DistributionExpenses Total Distribution Expenses (Lines 39 and 40)
42
OperationAndMaintenanceExpensesIncludingNaturalGasStorageTerminalingAndProcessingExpensesTransmissionExpensesDistributionExpenses Total (lines 5,9,13,37 and 41)
4,280,340


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
2
CustomerServiceAndInformationalExpenses (907-910) Customer Service and Information Expenses
3
SalesExpenses (911-916) Sales Expenses
4
AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
5
AdministrativeAndGeneralExpensesOperationAbstract Operations
6
AdministrativeAndGeneralSalaries 920 Administrative and General Salaries
119,450
7
OfficeSuppliesAndExpenses 921 Office Supplies and Expenses
127,341
8
AdministrativeExpensesTransferredCredit (Less) 922 Administrative Expenses Transferred-Credit
9
OutsideServicesEmployed 923 Outside Services Employed
121,977
10
PropertyInsurance 924 Property Insurance
9,135
11
InjuriesAndDamages 925 Injuries and Damages
6,055
12
EmployeePensionsAndBenefits 926 Employee Pensions and Benefits
111,982
13
FranchiseRequirements 927 Franchise Requirements
14
RegulatoryCommissionExpenses 928 Regulatory Commission Expenses
20,764
15
DuplicateChargesCredit (Less) 929 Duplicate Charges-Credit
16
GeneralAdvertisingExpenses 930.1 General Advertising Expenses
2
17
MiscellaneousGeneralExpenses 930.2 Miscellaneous General Expenses
63,786
18
RentsAdministrativeAndGeneralExpense 931 Rents
78
19
AdministrativeAndGeneralOperationExpense TOTAL Operation (Total of lines 6 through 18)
580,570
20
MaintenanceAbstract Maintenance
21
MaintenanceOfGeneralPlant 932 Maintenance of General Plant
7,946
22
AdministrativeAndGeneralExpenses TOTAL Administrative and General Expenses (Total of lines 19 and 21)
588,516


Name of Respondent:


Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:


11/20/2018
Year/Period of Report:


End of:
2018
/
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
1,819
1,819
2
Production Plant, Manufacturing Plant
3
Production and Gathering Plant - Natural Gas
4
Products Extraction - Natural Gas
5
Underground Gas Storage Plant
6
Other Storage Plant
7
Base Load LNG Terminaling and Processing Plant
8
Processing Plant
9
Transmission Plant
2,703,198
1,187
2,702,011
10
Distribution Plant
11
General Plant
9,975
9,975
12
Common Plant
13
Total
2,713,173
1,187
1,819
2,713,805


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
(a)
Questar Southern Trails Pipeline Company
2
QuantityOfNaturalGasReceivedByUtilityAbstract
GAS RECEIVED
3
QuantityOfNaturalGasReceivedByUtilityGasPurchases
Gas Purchases (Accounts 800-805)
4
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForGathering
Gas of Others Received for Gathering (Account 489.1)
303
5
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForTransmission
Gas of Others Received for Transmission (Account 489.2)
305
85,406
12,209
6
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForDistribution
Gas of Others Received for Distribution (Account 489.3)
301
7
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForContractStorage
Gas of Others Received for Contract Storage (Account 489.4)
307
8
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForProductionExtractionProcessing
Gas of Others Received for Production/Extraction/Processing (Account 490 and 491)
9
QuantityOfNaturalGasReceivedByUtilityExchangedGasReceivedFromOthers
Exchanged Gas Received from Others (Account 806)
328
10
QuantityOfNaturalGasReceivedByUtilityGasReceivedAsImbalances
Gas Received as Imbalances (Account 806)
328
46,826
11
QuantityOfNaturalGasReceivedByUtilityReceiptsOfUtilitysGasTransportedByOthers
Receipts of Respondent's Gas Transported by Others (Account 858)
332
12
QuantityOfNaturalGasReceivedByUtilityOtherGasWithdrawnFromStorage
Other Gas Withdrawn from Storage (Explain)
13
QuantityOfNaturalGasReceivedByUtilityGasReceivedFromShippersAsCompressorStationFuel
Gas Received from Shippers as Compressor Station Fuel
5,697
182
14
QuantityOfNaturalGasReceivedByUtilityGasReceivedFromShippersAsLostAndUnaccountedFor
Gas Received from Shippers as Lost and Unaccounted for
15
QuantityOfNaturalGasReceivedByUtilityOther
Other Receipts (Specify) (footnote details)
16
QuantityOfNaturalGasReceivedByUtility
Total Receipts (Total of lines 3 thru 15)
137,929
12,391
17
QuantityOfNaturalGasDeliveredByUtilityAbstract
GAS DELIVERED
18
QuantityOfNaturalGasDeliveredByUtilityGasSales
Gas Sales (Accounts 480-484)
19
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasGatheredForOthers
Deliveries of Gas Gathered for Others (Account 489.1)
303
20
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasTransportedForOthers
Deliveries of Gas Transported for Others (Account 489.2)
305
85,406
12,209
21
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasDistributedForOthers
Deliveries of Gas Distributed for Others (Account 489.3)
301
22
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfContractStorageGas
Deliveries of Contract Storage Gas (Account 489.4)
307
23
QuantityOfNaturalGasDeliveredByUtilityGasOfOthersDeliveredForProductionExtractionProcessing
Gas of Others Delivered for Production/Extraction/Processing (Account 490 and 491)
24
QuantityOfNaturalGasDeliveredByUtilityExchangeGasDeliveredToOthers
Exchange Gas Delivered to Others (Account 806)
328
25
QuantityOfNaturalGasDeliveredByUtilityGasDeliveredAsImbalances
Gas Delivered as Imbalances (Account 806)
328
36,647
11,935
26
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasToOthersForTransportation
Deliveries of Gas to Others for Transportation (Account 858)
332
27
QuantityOfNaturalGasDeliveredByUtilityOtherGasDeliveredToStorage
Other Gas Delivered to Storage (Explain)
28
QuantityOfNaturalGasDeliveredByUtilityGasUsedForCompressorStationFuel
Gas Used for Compressor Station Fuel
509
6,429
73
29
GasUsedForOtherDeliveriesAndGasUsedForOtherOperations
Other Deliveries and Gas Used for Other Operations
(b)
4,128
1,376
30
QuantityOfNaturalGasDeliveredByUtility
Total Deliveries (Total of lines 18 thru 29)
132,610
25,593
31
GasLossesAndGasUnaccountedForGasAccountAbstract
GAS LOSSES AND GAS UNACCOUNTED FOR
32
GasAccountGasLossesAndGasUnaccountedForGasAccount
Gas Losses and Gas Unaccounted For
5,319
13,202
33
DeliveriesGasLossesAndUnaccountedForGasAccountAbstract
TOTALS
34
DeliveriesGasLossesAndUnaccountedForGasAccount
Total Deliveries, Gas Losses & Unaccounted For (Total of lines 30 and 32)
137,929
12,391


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
Q3
FOOTNOTE DATA

(a) Concept: NameOfSystem

Footnote to Instruction 5:

Questar Southern Trails Pipeline Company does not bundle sales and transportation services.

 

Footnote to Instruction 7:

All quantities of gas were subject to Commission regulation.

 

Footnote to Instruction 9:

Questar Southern Trails Pipeline Company does not have gas storage.

(b) Concept: GasUsedForOtherDeliveriesAndGasUsedForOtherOperations

Other Deliveries Includes M&R and Mains Fuel. Applies to column (d) also.


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
3
Production/Extraction/Processing
4
Transmission
60
(a)
60
128
(d)
128
5
Distribution
6
Storage
7
Total Shipper Supplied Gas
60
60
128
128
LESS GAS USED FOR COMPRESSOR STATION FUEL (LINE 28, PAGE 520)
9
Gathering
10
Production/Extraction/Processing
11
Transmission
16
16
34
34
12
Distribution
13
Storage
14
Total gas used in compressors
16
16
34
34
15
LESS GAS USED FOR OTHER DELIVERIES AND GAS USED FOR OTHER OPERATIONS (LINE 29, PAGE 520) (Footnote)
16
Gathering
17
Production/Extraction/Processing
18
Transmission
454
(b)
454
967
967
19
Distribution
20
Storage
21
Other Deliveries (specify) (footnote details)
22
Total Gas Used For Other Deliveries And Gas Used For Other Operations
454
454
967
967
23
LESS GAS LOST AND UNACCOUNTED FOR (LINE 32, PAGE 520)
24
Gathering
25
Production/Extraction/Processing
26
Transmission
4,626
4,626
9,853
9,853
27
Distribution
28
Storage
29
Other Deliveries (specify) (footnote details)
30
Total Gas Lost And Unaccounted For
4,626
4,626
9,853
9,853
30.1
NET EXCESS OR (DEFICIENCY)
31
Other Losses
32
Gathering
33
Production/Extraction/Processing
34
Transmission
4,216
(c)
4,216
8,980
8,980
35
Distribution
36
Storage
37
Total Net Excess Or (Deficiency)
4,216
4,216
8,980
8,980
38
DISPOSITION OF EXCESS GAS:
39
Gas sold to others
40
Gas used to meet imbalances
41
Gas added to system gas
42
Gas returned to shippers
4,216
4,216
8,980
8,980
43.1
43.2
43.3
43.4
43.5
43.6
43.7
43.8
51
Total Disposition Of Excess Gas
4,216
4,216
8,980
8,980
52
GAS ACQUIRED TO MEET DEFICIENCY:
53
System gas
54
Purchased gas
55.1
55.2
55.3
55.4
55.5
55.6
55.7
55.8
55.9
55.10
65
Total Gas Acquired To Meet Deficiency

SEPARATION OF FORWARDHAUL AND BACKHAUL THROUGHPUT
Line No.
Item
(a)
Quarter
Dth (b)
66
Forwardhaul Volume in Dths for the Quarter
12,209
67
Backhaul Volume in Dths for the Quarter
68
TOTAL (Lines 66 and 67)
12,209


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
Q3
FOOTNOTE DATA

(a) Concept: ShipperSuppliedGasTransmission

Allocation method was based on throughput. Applies to lines 11, 18, and 26 also.

(b) Concept: GasUsedForOtherDeliveriesAndGasUsedForOtherOperationsTransmission

Gas used for M&R Fuel and Mains Fuel. Applies to all other columns on this line.

(c) Concept: ShipperSuppliedGasNetExcessOrDeficiencyTransmission

“Net excess or (deficiency)” balances are refunded or collected in-kind through Questar Southern Trails Pipeline

Company’s Fuel Reimbursement provision (§30) of the General Terms and Conditions of Questar Southern Trails

Pipeline Company's FERC Gas Tariff, Original Volume No. 1. Applies to columns (s) and (gg) also.

(d) Concept: AmountCollectedShipperSuppliedGasTransmission

Shipper Supplied Gas, Gas Consumed in Pipeline Operations, and Net Excess or (Deficiency) balances are valued based

on the Inside FERC First of Month posting for San Juan Basin delivered into El Paso Natural Gas Company for the month

following gas flow. Applies to lines 11, 18, and 26 also.

(e) Concept: AccountsDebitedOrCreditedShipperSuppliedGasTransmission

In accordance with FERC Order No. 581, Shipper Supplied Gas is not directly charged to an account. Any excess or

deficiency in net Shipper Supplied Gas (line 37) is recorded as “Other Regulatory Assets/Liabilities” (Accounts 182.3 /

254)with offsetting entries booked to “Regulatory Debits/Credits”, (Accounts 407.3 / .4). Applies to columns (o), (bb), (cc), (pp), and (qq) also.


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
3
Production/Extraction/Processing
4
Transmission
62
62
144
144
5
Distribution
6
Storage
7
Total Shipper Supplied Gas
62
62
144
144
8
LESS GAS USED FOR COMPRESSOR STATION FUEL (LINE 28, PAGE 520)
9
Gathering
10
Production/Extraction/Processing
11
Transmission
19
19
44
44
12
Distribution
13
Storage
14
Total gas used in compressors
19
19
44
44
15
LESS GAS USED FOR OTHER DELIVERIES AND GAS USED FOR OTHER OPERATIONS (LINE 29, PAGE 520) (Footnote)
16
Gathering
17
Production/Extraction/Processing
18
Transmission
461
461
1,074
1,074
19
Distribution
20
Storage
21
Other Deliveries (specify) (footnote details)
22
Total Gas Used For Other Deliveries And Gas Used For Other Operations
461
461
1,074
1,074
23
LESS GAS LOST AND UNACCOUNTED FOR (LINE 32, PAGE 520)
24
Gathering
25
Production/Extraction/Processing
26
Transmission
4,049
4,049
9,434
9,434
27
Distribution
28
Storage
29
Other Deliveries (specify) (footnote details)
30
Total Gas Lost And Unaccounted For
4,049
4,049
9,434
9,434
30.1
NET EXCESS OR (DEFICIENCY)
31
Other Losses
32
Gathering
33
Production/Extraction/Processing
34
Transmission
3,631
3,631
8,460
8,460
35
Distribution
36
Storage
37
Total Net Excess Or (Deficiency)
3,631
3,631
8,460
8,460
38
DISPOSITION OF EXCESS GAS:
39
Gas sold to others
40
Gas used to meet imbalances
41
Gas added to system gas
42
Gas returned to shippers
3,631
3,631
8,460
8,460
43.1
43.2
43.3
43.4
43.5
43.6
43.7
43.8
51
Total Disposition Of Excess Gas
3,631
3,631
8,460
8,460
52
GAS ACQUIRED TO MEET DEFICIENCY:
53
System gas
54
Purchased gas
55.1
55.2
55.3
55.4
55.5
55.6
55.7
55.8
55.9
55.10
65
Total Gas Acquired To Meet Deficiency


Name of Respondent:

Questar Southern Trails Pipeline Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

11/20/2018
Year/Period of Report:

End of:
2018
/
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
3
Production/Extraction/Processing
4
Transmission
60
60
129
129
5
Distribution
6
Storage
7
Total Shipper Supplied Gas
60
60
129
129
8
LESS GAS USED FOR COMPRESSOR STATION FUEL (LINE 28, PAGE 520)
9
Gathering
10
Production/Extraction/Processing
11
Transmission
38
38
82
82
12
Distribution
13
Storage
14
Total gas used in compressors
38
38
82
82
15
LESS GAS USED FOR OTHER DELIVERIES AND GAS USED FOR OTHER OPERATIONS (LINE 29, PAGE 520) (Footnote)
16
Gathering
17
Production/Extraction/Processing
18
Transmission
461
461
991
991
19
Distribution
20
Storage
21
Other Deliveries (specify) (footnote details)
22
Total Gas Used For Other Deliveries And Gas Used For Other Operations
461
461
991
991
23
LESS GAS LOST AND UNACCOUNTED FOR (LINE 32, PAGE 520)
24
Gathering
25
Production/Extraction/Processing
26
Transmission
4,527
4,527
9,733
9,733
27
Distribution
28
Storage
29
Other Deliveries (specify) (footnote details)
30
Total Gas Lost And Unaccounted For
4,527
4,527
9,733
9,733
30.1
NET EXCESS OR (DEFICIENCY)
31
Other Losses
32
Gathering
33
Production/Extraction/Processing
34
Transmission
4,088
4,088
8,789
8,789
35
Distribution
36
Storage
37
Total Net Excess Or (Deficiency)
4,088
4,088
8,789
8,789
38
DISPOSITION OF EXCESS GAS:
39
Gas sold to others
40
Gas used to meet imbalances
41
Gas added to system gas
42
Gas returned to shippers
4,088
4,088
8,789
8,789
43.1
43.2
43.3
43.4
43.5
43.6
43.7
43.8
51
Total Disposition Of Excess Gas
4,088
4,088
8,789
8,789
52
GAS ACQUIRED TO MEET DEFICIENCY:
53
System gas
54
Purchased gas
55.1
55.2
55.3
55.4
55.5
55.6
55.7
55.8
55.9
55.10
65
Total Gas Acquired To Meet Deficiency

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