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2017-01-01 2017-03-31 C000591 0-6 2018-01-01 2018-03-31 C000591 0-5 2018-01-01 2018-03-31 C000591 2017-03-31 C000591 2018-02-01 2018-02-28 C000591 0-12 2018-03-01 2018-03-31 C000591 ferc:RecourseRateMember 2018-03-01 2018-03-31 C000591 0-5 2018-01-01 2018-03-31 C000591 0-1 2017-12-31 C000591 0-11 2018-02-01 2018-02-28 C000591 0-3 2018-01-01 2018-03-31 C000591 0-15 0 2018-01-01 2018-03-31 C000591 0-12 2018-01-01 2018-03-31 C000591 ferc:NegotiatedRateMember 2018-02-01 2018-02-28 C000591 0-8 2018-03-01 2018-03-31 C000591 0-70 2018-01-01 2018-01-31 C000591 ferc:DiscountedRateMember 2018-03-01 2018-03-31 C000591 ferc:RecourseRateMember 2018-01-01 2018-01-31 C000591 0-4 2018-03-01 2018-03-31 C000591 0-5 2018-01-01 2018-03-31 C000591 ferc:GasUtilityMember 2018-01-01 2018-03-31 C000591 2018-01-01 2018-01-31 C000591 0-5 2018-01-01 2018-01-31 C000591 0-71 2018-01-01 2018-03-31 C000591 0-71 2018-03-01 2018-03-31 C000591 ferc:RecourseRateMember 2018-02-01 2018-02-28 C000591 0-68 2018-03-01 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2018-01-01 2018-03-31 C000591 0-58 2018-01-01 2018-03-31 pure iso4217:USD ferc:dth
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)

Gulf South Pipeline Company, LP
Year/Period of Report:

End of:
2018
/
Q1


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

Gulf South Pipeline Company, LP
02 Year/ Period of Report


End of:
2018
/
Q1
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)

9 Greenway Plaza, Suite 2800, Houston, Texas 77046 - 0905
05 Name of Contact Person

Steven A. Barkauskas
06 Title of Contact Person

Senior VP, CAO & Controller
07 Address of Contact Person (Street, City, State, Zip Code)

9 Greenway Plaza, Suite 2800, Houston, Texas 77046 - 0905
08 Telephone of Contact Person, Including Area Code

713-479-8000
09 This Report is An Original / A Resubmission

(1)
An Original

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

05/30/2018
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

Steven A. Barkauskas
12 Title

Senior VP, CAO & Controller
13 Signature

/s/ Steven A. Barkauskas
14 Date Signed

05/30/2018
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:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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.

Item 1-4: None

 

Item 5: Gulf South placed into service the first phase of the Coastal Bend Header on February 1, 2018 (Docket No. CP15-517). The facilities placed into service include the 66 mile header, a portion of the Wilson Compressor Station, and installation of six of the seven meter stations. This first phase will provide capacity of approximately 0.7 Bcf/d under interim service contracts with service under long-term firm transportation contracts commencing no later than February 1, 2019. The second phase of the project is expected to be placed into service and provide interim service on November 1, 2018, with long-term firm contracts for this phase of the project commencing on May 1, 2019. The associated capacity for the second phase is approximately 0.7 Bcf/d, for a total project capacity of approximately 1.4 Bcf/d.

Item 6-11: None

 

Item 12: Officers changed during the reporting period:

 

Appointment: Carrie Lee Assistant Secretary

Tony G. Rizk Vice President Technical Services

Resignation:  David N. Goodwin Vice President Technical Services

Allison (McLean) Longoria Vice President Human Resources

Julie Mondelli Regional Vice President-BFS & Southwest Region

Item 13: None



Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
4,976,803,784
4,824,047,159
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200-201
238,264,526
328,666,666
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Total of lines 2 and 3)
200-201
5,215,068,310
5,152,713,825
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Provision for Depr., Amort., Depl. (108, 111, 115)
1,794,853,133
1,773,723,024
6
UtilityPlantNet
Net Utility Plant (Total of line 4 less 5)
3,420,215,177
3,378,990,801
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)
3,420,215,177
3,378,990,801
11
OtherGasPlantAdjustments
Utility Plant Adjustments (116)
122
12
GasStoredBaseGas
Gas Stored-Base Gas (117.1)
220
78,033,688
78,033,688
13
SystemBalancingGas
System Balancing Gas (117.2)
220
22,046,914
22,046,914
14
GasStoredInReservoirsAndPipelinesNoncurrent
Gas Stored in Reservoirs and Pipelines-Noncurrent (117.3)
220
205,108
83,051
15
GasOwedToSystemGas
Gas Owed to System Gas (117.4)
220
6,297,376
739,934
16
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
17
NonutilityProperty
Nonutility Property (121)
6,614,782
6,614,782
18
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Provision for Depreciation and Amortization (122)
643,520
643,520
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)
2,250
2,250
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)
5,973,512
5,973,512
31
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
32
Cash
Cash (131)
1,368,942
296,695
33
SpecialDeposits
Special Deposits (132-134)
362,868
362,584
34
WorkingFunds
Working Funds (135)
35
TemporaryCashInvestments
Temporary Cash Investments (136)
222-223
36
NotesReceivable
Notes Receivable (141)
511,903
541,443
37
CustomerAccountsReceivable
Customer Accounts Receivable (142)
36,368,072
42,681,421
38
OtherAccountsReceivable
Other Accounts Receivable (143)
6,542,446
6,899,810
39
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Provision for Uncollectible Accounts - Credit (144)
24,868
1,725
40
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
41
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Associated Companies (146)
12,565,351
6,073,254
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)
4,135,059
3,917,186
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
9,314,526
9,934,080
55
AdvancesForGas
Advances for Gas (166 thru 167)
56
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
57
RentsReceivable
Rents Receivable (172)
58
AccruedUtilityRevenues
Accrued Utility Revenues (173)
59
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
2,891,767
3,173,310
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)
74,036,066
73,878,058
65
DeferredDebitsAbstract
DEFERRED DEBITS
66
UnamortizedDebtExpense
Unamortized Debt Expense (181)
350,788
371,431
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
92,805,101
89,931,408
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)
4,200
5,378
73
TemporaryFacilities
Temporary Facilities (185)
74
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
2,241,039
2,249,891
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
8,112,974
10,178,835
79
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
80
DeferredDebits
TOTAL Deferred Debits (Total of lines 66 thru 79)
103,514,102
102,736,943
81
AssetsAndOtherDebits
TOTAL Assets and Other Debits (Total of lines 10-15,30,64,and 80)
3,697,727,191
3,661,003,033


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
379,835,513
379,835,513
7
OtherPaidInCapital
Other Paid-In Capital (208-211)
253
1,124,886,822
1,128,308,990
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
677,675,779
649,205,130
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
1,712,855
1,835,781
15
ProprietaryCapital
TOTAL Proprietary Capital (Total of lines 2 thru 14)
2,180,685,260
2,155,513,853
16
LongTermDebtAbstract
LONG TERM DEBT
17
Bonds
Bonds (221)
256-257
300,000,000
300,000,000
18
ReacquiredBonds
(Less) Reacquired Bonds (222)
256-257
19
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256-257
20
OtherLongTermDebt
Other Long-Term Debt (224)
256-257
100,000,000
100,000,000
21
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
258-259
22
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Dr (226)
258-259
1,270,500
1,346,175
23
CurrentPortionOfLongTermDebt
(Less) Current Portion of Long-Term Debt
24
LongTermDebt
TOTAL Long-Term Debt (Total of lines 17 thru 23)
398,729,500
398,653,825
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)
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)
25,432,717
25,737,983
35
OtherNoncurrentLiabilities
TOTAL Other Noncurrent Liabilities (Total of lines 26 thru 34)
25,432,717
25,737,983
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
CurrentPortionOfLongTermDebt
Current Portion of Long-Term Debt
38
NotesPayable
Notes Payable (231)
39
AccountsPayable
Accounts Payable (232)
43,240,963
48,665,194
40
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
419,081,845
389,863,376
41
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
4,160,159
3,087,152
42
CustomerDeposits
Customer Deposits (235)
43
TaxesAccrued
Taxes Accrued (236)
262-263
18,368,694
31,128,071
44
InterestAccrued
Interest Accrued (237)
3,864,256
702,093
45
DividendsDeclared
Dividends Declared (238)
46
MaturedLongTermDebt
Matured Long-Term Debt (239)
47
MaturedInterest
Matured Interest (240)
48
TaxCollectionsPayable
Tax Collections Payable (241)
49
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
268
34,745,924
54,113,441
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)
523,461,841
527,559,327
56
DeferredCreditsAbstract
DEFERRED CREDITS
57
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
3,832,663
5,057,268
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
20,453,774
13,480,133
61
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
170,182,555
170,576,881
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)
358,688,196
348,483,881
65
AccumulatedDeferredIncomeTaxesOther
Accumulated Deferred Income Taxes - Other (283)
16,260,685
15,939,882
66
DeferredCredits
TOTAL Deferred Credits (Total of lines 57 thru 65)
569,417,873
553,538,045
67
LiabilitiesAndOtherCredits
TOTAL Liabilities and Other Credits (Total of lines 15,24,35,55,and 66)
3,697,727,191
3,661,003,033


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
126,935,278
137,179,843
126,935,278
137,179,843
126,935,278
137,179,843
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
317-325
36,967,482
32,314,527
36,967,482
32,314,527
36,967,482
32,314,527
5
MaintenanceExpense
Maintenance Expenses (402)
317-325
6,059,633
4,469,522
6,059,633
4,469,522
6,059,633
4,469,522
6
DepreciationExpense
Depreciation Expense (403)
336-338
27,585,162
24,610,841
27,585,162
24,610,841
27,585,162
24,610,841
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336-338
328,843
35,937
328,843
35,937
328,843
35,937
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336-338
1,129
1,129
1,129
1,129
1,129
1,129
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)
8,957,526
1,395,371
8,957,526
1,395,371
8,957,526
1,395,371
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
11,513,982
11,513,982
11,513,982
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262-263
13,675,332
12,616,290
13,675,332
12,616,290
13,675,332
12,616,290
15
IncomeTaxesUtilityOperatingIncome
Income Taxes-Federal (409.1)
262-263
2,609,741
1,892,753
2,609,741
1,892,753
2,609,741
1,892,753
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes-Other (409.1)
262-263
763,351
332,842
763,351
332,842
763,351
332,842
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision of Deferred Income Taxes (410.1)
234-235
13,110,298
18,830,374
13,110,298
18,830,374
13,110,298
18,830,374
18
ProvisionForDeferredIncomeTaxesCreditUtilityOperatingIncome
(Less) Provision for Deferred Income Taxes-Credit (411.1)
234-235
909,482
909,482
909,482
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adjustment-Net (411.4)
20
GainsFromDispositionOfPlant
(Less) Gains from Disposition of Utility Plant (411.6)
249,917
249,917
249,917
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)
185,377
182,527
185,377
182,527
185,377
182,527
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Total of lines 4 thru 24)
90,824,309
96,682,113
90,824,309
96,682,113
90,824,309
96,682,113
26
NetUtilityOperatingIncome
Net Utility Operating Income (Total of lines 2 less 25) (Carry forward to line 27)
36,110,969
40,497,730
36,110,969
40,497,730
36,110,969
40,497,730
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)
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
37
InterestAndDividendIncome
Interest and Dividend Income (419)
22,584
89,461
22,584
89,461
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
3,424,492
3,850,600
3,424,492
3,850,600
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
203,935
348,528
203,935
348,528
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
41
OtherIncome
TOTAL Other Income (Total of lines 31 thru 40)
3,651,011
4,288,589
3,651,011
4,288,589
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
73,906
59,003
73,906
59,003
46
LifeInsurance
Life Insurance (426.2)
47
Penalties
Penalties (426.3)
66,156
66,156
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Expenditures for Certain Civic, Political and Related Activities (426.4)
6,923
5,780
6,923
5,780
49
OtherDeductions
Other Deductions (426.5)
120
120
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
340
146,985
64,903
146,985
64,903
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
30,182
90,166
30,182
90,166
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262-263
8,943
15,922
8,943
15,922
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Income Taxes (410.2)
234-235
40,849
40,849
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Credit (411.2)
234-235
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)
39,125
146,937
39,125
146,937
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
3,543,151
4,076,749
3,543,151
4,076,749
61
InterestChargesAbstract
INTEREST CHARGES
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
4,239,565
7,675,661
4,239,565
7,675,661
63
AmortizationOfDebtDiscountAndExpense
Amortization of Debt Disc. and Expense (428)
258-259
96,318
164,051
96,318
164,051
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
2,731,053
2,731,053
68
OtherInterestExpense
Other Interest Expense (431)
340
45,726
45,726
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Credit (432)
567,711
519,075
567,711
519,075
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
6,499,225
7,366,363
6,499,225
7,366,363
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
33,154,895
37,208,116
33,154,895
37,208,116
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)
33,154,895
37,208,116
33,154,895
37,208,116


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
2,259,346
2,259,346
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
103,694
103,694
3
Preceding Quarter/Year to Date Changes in Fair Value
4
Total (lines 2 and 3)
103,694
103,694
37,208,116
37,311,810
5
Balance of Account 219 at End of Preceding Quarter/Year
2,155,652
2,155,652
6
Balance of Account 219 at Beginning of Current Year
1,835,781
1,835,781
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
122,926
122,926
8
Current Quarter/Year to Date Changes in Fair Value
9
Total (lines 7 and 8)
122,926
122,926
33,154,895
33,277,821
10
Balance of Account 219 at End of Current Quarter/Year
1,712,855
1,712,855


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:


End of:
2018
/
Q1
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
(a)
644,520,884
522,827,319
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)
33,154,895
37,208,116
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)
677,675,779
560,035,435
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)
677,675,779
560,035,435
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:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:


End of:
2018
/
Q1
FOOTNOTE DATA

(a) Concept: UnappropriatedRetainedEarnings

Retained earnings as reported as of December 31 , 2017

$649,205,130

Revenue adjustment due to the adoption of ASC 606

 

effective January 1, 2018, net of tax

(4,684,246)

Beginning retained earnings as of Jannary 1, 2018

$644,520,884


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:


End of:
2018
/
Q1
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)
33,154,895
37,208,116
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
27,914,005
24,646,778
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of (Specify) (footnote details)
(a)
97,447
165,180
6
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
12,200,816
18,871,223
7
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustments (Net)
8
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
(b)
1,679,210
(l)
902,775
9
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
(c)
217,873
(m)
178,278
10
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
11
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
29,316,203
23,101,309
12
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
13
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
875,495
2,007,546
14
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
3,424,492
3,850,600
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)
903,685
2,418,787
18
NetCashProvidedByUsedInOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 16)
42,059,615
57,284,668
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)
73,825,012
(n)
74,311,930
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
(f)
3,424,492
(o)
3,850,600
27
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other Construction and Acquisition of Plant, Investment Activities
27.1
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription
Other (footnote details):
28
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 22 thru 27)
(g)
70,400,520
(p)
70,461,330
30
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
31
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
485,757
5,515
33
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Investments in and Advances to Associated and Subsidiary Companies
(q)
13,342,612
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)
69,914,763
57,113,203
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):
(h)
145,000,000
56.2
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (footnote details): Notes Payable to Associated Companies
(i)
28,927,395
57
NetIncreaseInShortTermDebt
Net Increase in Short-term Debt (c)
59
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total of lines 53 thru 58)
173,927,395
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):
(j)(k)
145,000,000
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)
28,927,395
73
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract
Net Increase (Decrease) in Cash and Cash Equivalents
74
NetIncreaseDecreaseInCashAndCashEquivalents
(Total of line 18, 49 and 71)
1,072,247
171,465
76
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
296,695
373,171
78
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
1,368,942
544,636


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:


End of:
2018
/
Q1
FOOTNOTE DATA

(a) Concept: NoncashAdjustmentsToCashFlowsFromOperatingActivities

Amortization of:

2018

 

2017

 

 

 

 

Debt discount and expense

$ 96,318

 

$ 164,051

Underground storage land and land rights

1,129

 

1,129

 

$ 97,447

 

$ 165,180

(b) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
Original value: 1679210
(c) Concept: NetIncreaseDecreaseInInventoryOperatingActivities
Original value: -217873
(d) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities

Detail of Other:

2018

 

2017

 

 

 

 

Retirements

$ (1,792,716)

 

$ (373,150)

Gas stored underground

(122,056)

 

(26,278)

Prepayments

619,554

 

230,950

Deferred rent accrual

(75,563)

 

186,000

Accrued employee benefits

213,634

 

1,187,494

Asset retirement obligation

(305,266)

 

123,099

Note receivable

98,351

 

127,891

Environmental reserve

(103,578)

 

(389,131)

Unearned revenue

319,799

 

1,299,252

Other

244,156

 

52,660

 

$ (903,685)

 

$ 2,418,787

(e) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Original value: -73825012
(f) Concept: AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
Original value: -3424492
(g) Concept: CashOutflowsForPlant
Original value: -70400520
(h) Concept: OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities

Proceeds from revolving credit facility

(i) Concept: OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities

 

2018

 

2017

Notes Payable to Associated Companies

$ 28,927,395

 

$ -

 

 

 

(j) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities

Payment to revolving credit facility

(k) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Original value: -145000000
(l) Concept: NetIncreaseDecreaseInReceivablesOperatingActivities
Original value: -902775
(m) Concept: NetIncreaseDecreaseInInventoryOperatingActivities
Original value: -178278
(n) Concept: GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Original value: -74311930
(o) Concept: AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
Original value: -3850600
(p) Concept: CashOutflowsForPlant
Original value: -70461330
(q) Concept: InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Original value: 13342612

Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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.

 

GULF SOUTH PIPELINE COMPANY, LP

NOTES TO FERC FINANCIAL STATEMENTS

 

Note 1:  Corporate Structure

 

Gulf South Pipeline Company, LP (Gulf South) is a wholly-owned subsidiary of Boardwalk Pipelines, LP (Boardwalk Pipelines), which is a wholly-owned subsidiary of Boardwalk Pipeline Partners, LP (Boardwalk Pipeline Partners). Boardwalk Pipeline Partners is a publicly-traded Delaware limited partnership formed in 2005. Boardwalk Pipelines Holding Corp. (BPHC), a wholly-owned subsidiary of Loews Corporation (Loews), and, with Boardwalk GP, LP, an indirect wholly-owned subsidiary of BPHC, owns the majority of the equity interests of Boardwalk Pipeline Partners, including limited partnership units and Boardwalk Pipeline Partners’ 2% general partner interest and all its incentive distribution rights.

 

 

Basis of Presentation

 

The accompanying unaudited interim financial statements were prepared in accordance with the accounting requirements of the Federal Energy Regulatory Commission (FERC) as set forth in its applicable 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). The principal differences from GAAP relate to the fact that these financial statements: (1) as permitted by FERC rules, contain certain condensed financial information and exclude certain footnote disclosures normally included in financial statements prepared in accordance with GAAP; (2) classify certain accounts differently on the Comparative Balance Sheet and Statement of Income; (3) do not reflect the new basis of accounting established as a result of a change in ownership which occurred in 2004 and 2011; (4) contain certain amounts deferred as regulatory assets or liabilities, which were recognized in income for GAAP; (5) reflect income taxes consistent with the FERC USofA and recently enacted FERC Policy, which were not recorded for GAAP since Gulf South is a limited partnership; (6) typically reflect the gain or loss on the disposal of assets as a component of accumulated depreciation, not on the Statement of Income; and (7) recognize allowance for funds used during construction (AFUDC) rather than capitalized interest as allowed under GAAP.

 

In the opinion of management, the accompanying unaudited interim financial statements reflect all adjustments (consisting of only normal recurring accruals) necessary to present fairly the financial position as of March 31, 2018, and December 31, 2017, and the results of operations and comprehensive income for the three months ended March 31, 2018 and 2017, and changes in cash flows and retained earnings for the three months ended March 31, 2018 and 2017. Reference is made to the Notes to Financial Statements in the 2017 Annual Report on Form 2 (2017 Form 2), which should be read in conjunction with these unaudited condensed financial statements. The accounting policies described in Note 2 to Gulf South’s Notes to Financial Statements included in the 2017 Form 2 are the same used in preparing these unaudited interim financial statements, except for the changes described in Note 2 below.

 

Net income for interim periods may not necessarily be indicative of results for the full year. Subsequent events have been evaluated through May 30, 2018, the date these financial statements were available to be issued.

 

 

Note 2: Accounting Policies

 

Accounting Pronouncements Adopted in 2018 - Revenue Recognition

 

In May 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2014-09, Revenue from Contracts with Customers, which was codified in Accounting Standards Codification (ASC) Topic 606 (ASC 606). ASC 606 supersedes the revenue recognition requirements in ASC Topic 605, Revenue Recognition (ASC 605), and requires the recognition of revenues when promised goods or services are transferred to customers in an amount that reflects the consideration to which the entity expects to be entitled to in exchange for those goods or services.

 

Effective January 1, 2018, Gulf South implemented ASC 606 using the modified retrospective method, without adjustment to the comparative period information, which remains reported under ASC 605. Upon implementation, Gulf South recorded a cumulative reduction to partners’ capital of $4.7 million, net of tax, resulting from contracts which had changes to rates during the service period without corresponding changes in service levels provided by Gulf South, with an offsetting increase to other liabilities of $6.4 million. Gulf South elected to apply ASC 606 to contracts with customers, and applicable amendments, which were not completed prior to the implementation date.

 

 

 

 

Revenue Recognition

 

Nature of Contracts

 

Gulf South primarily earns revenues from contracts with customers by providing transportation and storage services for natural gas on a firm and interruptible basis. Gulf South also provides interruptible natural gas parking and lending (PAL) services. Gulf South’s customers choose, based upon their particular needs, the applicable mix of services depending upon availability of pipeline and storage capacity, the price of services and the volume and timing of customer requirements. The maximum rates that may be charged by Gulf South for its services are established through the FERC’s cost-based rate-making process; however, rates actually charged by Gulf South may be less than those allowed by the FERC. Gulf South has been authorized to charge market-based rates for some of its natural gas storage capacity pursuant to authority granted by the FERC. Certain revenues that Gulf South collects may be subject to possible refund to its customers. Accordingly, during a rate case, estimated refund liabilities are recorded considering regulatory proceedings, advice of counsel and estimated risk-adjusted total exposure, as well as other factors. Gulf South’s service contracts can range from one to twenty years although Gulf South may enter into shorter- or longer-term contracts, and services are invoiced monthly with payment from the customer generally expected within ten to thirty days, depending on the terms of the contract.

Firm Service Contracts: Gulf South offers firm services to its customers. Gulf South customers can reserve a specific amount of pipeline capacity at specified receipt and delivery points on the Gulf South pipeline system (transportation service) or can reserve a specific amount of storage capacity at specified injection and withdrawal points at Gulf South storage facilities (storage service). Gulf South accounts for firm services as a single promise to stand ready each month of the contract term to provide the committed capacity for either transportation or storage services when needed by the customer, which represents a series of distinct monthly services that are substantially the same with the same pattern of transfer to the customer. Although several activities may be required to provide the firm service, the individual activities do not represent distinct performance obligations because all of the activities must be performed in combination in order for Gulf South to provide the firm service.

 

The transaction price for firm service contracts is comprised of a fixed fee based on the quantity of capacity reserved, regardless of use (capacity reservation fee), plus variable fees in the form of a usage fee paid on the volume of commodity actually transported or injected and withdrawn from storage. Both the fixed and usage fees are allocated to the single performance obligation of providing transportation or storage service and recognized over time based upon the output measure of time as Gulf South completes its stand-ready obligation to provide contracted capacity and the customer receives and consumes the benefit of the reserved capacity, which corresponds with the transfer of control to the customer. The fixed fee is recognized ratably over the contract term, representative of the proportion of the committed stand-ready capacity obligation that has been fulfilled to date, and the usage fee is recognized upon satisfaction of each distinct monthly performance obligation, consistent with the allocation objective and based upon the level of effort required to satisfy the stand-ready obligation in a given month. Capacity reservation revenues derived from a firm service contract are generally consistent during the contract term, but can be higher in winter periods than the rest of the year based upon seasonal rates.

 

Interruptible Service Contracts: In providing interruptible services to customers, Gulf South agrees to transport natural gas for a customer when capacity is available. Gulf South does not account for interruptible services with a customer as a contract until the customer nominates for service and Gulf South accepts the nomination based upon available pipeline or storage capacity because there are no enforceable rights and obligations until that time. The nomination and acceptance process is a daily activity and acceptance is granted based upon priority of service and availability of capacity. Upon acceptance, Gulf South accounts for interruptible services similarly to its firm services.

 

The transaction price for interruptible service contracts is comprised of a variable fee in the form of a usage fee paid on the volume of commodity actually transported or injected and withdrawn from storage. The usage fee is allocated to the single performance obligation of providing interruptible service. Interruptible service revenues are generally recognized over time based on the output measure of volume transported or stored when services are rendered upon the successful allocation of the services provided to the customer’s account, which best depicts the transfer of control to the customer and satisfaction of the promised service. Interruptible services are recognized in the month services are provided because Gulf South has a right to consideration from customers in amounts that correspond directly to the value that the customer receives from Gulf South’s performance. The rates charged may vary on a daily, monthly or seasonal basis.

 

Other: Periodically, Gulf South may enter into contracts with customers for the sale of natural gas. Gulf South recognizes revenues for these transactions at the point in time of the physical sale of the natural gas, which corresponds with the transfer of control of the natural gas to the customer and the consideration is measured as the stated sales price in the contract.

 

 

 

 

Contract Balances

 

Gulf South records contract assets when performance obligations are completed but not billed as of the reporting date. Gulf South records contract liabilities, or deferred income, when payment is received in advance of satisfying its performance obligations.

 

Other Recently Issued Accounting Pronouncements

 

In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) (ASU 2016-02), which will require, among other things, the recognition of lease assets and lease liabilities by lessees for those leases classified as operating leases under current GAAP. The amendments are to be applied at the beginning of the earliest period presented using a modified retrospective approach. ASU 2016-02 is effective for interim and annual reporting periods beginning after December 15, 2018, however, early adoption is permitted. Gulf South has initiated a project to evaluate the impact that ASU 2016-02 will have on its financial statements when implemented; however, no conclusions have been reached.

 

FERC Policy Statement, Notice of Inquiry and Notice of Proposed Rulemaking

 

 

Effective December 22, 2017, the Tax Cuts and Jobs Act changed several provisions of the federal tax code, including a reduction in the maximum corporate tax rate from 35% to 21% for tax years beginning January 1, 2018. In March 2018, the FERC announced a change in its policy regarding the inclusion of income taxes in rates, such that a pipeline owned by a master limited partnership will no longer be allowed to collect income taxes in its rates. Also in March 2018, the FERC issued a notice of proposed rulemaking (NOPR) and a notice of inquiry (NOI) which further address the effects of tax reform on rates. The NOPR proposes a requirement that all interstate natural gas pipelines make a one-time informational filing designed to show the approximate impact of tax reform and related income tax policy change on the cost of service of each pipeline. The NOI seeks industry comment on the treatment of accumulated deferred income taxes and bonus depreciation resulting from tax reform and its income tax policy changes. Gulf South has filed comments on both the NOPR and NOI and a final rule is anticipated to be issued in 2018. Gulf South is in the process of assessing the impacts that the policy statement, NOPR and NOI may have on its cost of service.

 

As a result of change in tax rates, Gulf South reduced its accumulated deferred income tax balances at December 31, 2017, and a regulatory liability of $168.4 million was established for the portion of the tax reduction related to utility plant (Account 282), due to specific normalization provisions under the Tax Cuts and Jobs Act. The regulatory liability began amortizing to utility income effective January 1, 2018 using the Reverse South Georgia method, which requires amortization over the remaining useful life of the utility plant.

 

With the issuance and subsequent posting of the Revised Policy Statement in the Federal Register, Gulf South suspended the recording of allowances for federal income taxes in its financial statements as of March 20, 2018. The deferred federal tax balances will remain on the balance sheet until FERC issues a final ruling or clarifies the accounting treatment.

 

 

Note 3: Revenues

 

Disaggregated Revenues

 

For a presentation of revenues disaggregated by type for the three months ended March 31, 2018, refer to page 299, Monthly Quantity & Revenue Data by Rate Schedule of this Quarterly Report on Form 3Q.

 

Contract Balances

 

As of March 31, 2018, Gulf South had customer accounts receivable of $36.4 million and deferred revenues of $7.8 million, which is expected to be recognized through 2018.

 

 

 

Note 4:  Gas Stored Underground and Gas Receivables and Payables

 

Gulf South provides storage services whereby they store natural gas on behalf of customers and also periodically hold customer gas under PAL services. Since the customers retain title to the gas held by Gulf South in providing these services, Gulf South does not record the related gas on its balance sheet.

 

Gulf South also periodically lends gas to customers under PAL and certain firm service, and gas may be owed to Gulf South as a result of transportation imbalances. As of March 31, 2018, the amount of gas owed to Gulf South due to gas imbalances and gas loaned under PAL and certain firm service agreements was approximately 2.7 trillion British thermal units (TBtu). Assuming an average market price during March 2018 of $2.56 per million British thermal units, the market value of that gas was approximately $6.9 million. As of December 31, 2017, the amount of gas owed to Gulf South due to gas imbalances and gas loaned under PAL and certain firm service agreements was approximately 2.0 TBtu. If any significant customer should have credit or financial problems resulting in a delay or failure to repay the gas owed to Gulf South, it could have a material adverse effect on Gulf South's financial condition, results of operations or cash flows.

 

 

Note 5: Accumulated Other Comprehensive Income (AOCI) and Fair Value Measurements

 

Gulf South's Accumulated Other Comprehensive Loss (AOCI) as of March 31, 2018, and December 31, 2017, was $1.7 million and $1.8 million, all of which relate to settled treasury rate locks that are being amortized to earnings over the terms of the related interest payments, generally the terms of the related debt. Gulf South estimates that approximately $0.4 million of net losses, net of tax, reported in AOCI as of March 31, 2018, are expected to be reclassified into earnings within the next twelve months.

 

Financial Assets and Liabilities

 

As of March 31, 2018 and December 31, 2017, Gulf South had no assets and liabilities which were recorded at fair value on a recurring basis. The following methods and assumptions were used in estimating the fair value disclosure amounts for its financial assets and liabilities, which are consistent with those disclosed in Gulf South’s Notes to Financial Statements included in the 2017 Form 2:

 

Cash: For cash, the carrying amount is a reasonable estimate of fair value.

 

Notes Receivable from/Notes Payable to Associated Companies: Note Receivable from/Notes payable to associated companies, which are represented by demand notes and earn a variable rate of interest, which is adjusted regularly to reflect current market conditions. Therefore, the carrying amount is a reasonable estimate of fair value. The interest rate on intercompany demand notes is the London Interbank Offered Rate (LIBOR) plus one percent and is adjusted every three months.

 

Long-Term Debt: The estimated fair value of Gulf South's publicly traded debt is based on quoted market prices at March 31, 2018, and December 31, 2017. The fair market value of the debt that is not publicly traded is based on market prices of similar debt at March 31, 2018, and December 31, 2017.

 

The carrying amount and estimated fair values of Gulf South's financial assets and liabilities which are not recorded at fair value on the Comparative Balance Sheet as of March 31, 2018, and December 31, 2017, were as follows (in millions):

 

 

 

 

 

 

 

 

 

 

As of March 31, 2018

 

 

 

Estimated Fair Value

Financial Assets

 

Carrying Amount

 

Level 1

 

Level 2

 

Level 3

 

 

 

Total

Cash

 

$

1.4

 

 

 

$

1.4

 

 

 

$

 

 

 

$

 

 

 

$

1.4

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Financial Liabilities

 

 

 

 

 

 

 

 

 

 

 

 

Long-term debt

 

$

398.7

 

 

 

$

 

 

 

$

401.8

 

 

 

$

 

 

 

$

401.8

 

 

 

 

Notes Payable to Associated

Companies

 

 

419.1

 

 

 

 

 

 

 

 

419.1

 

 

 

 

 

 

 

 

419.1

 

 

As of December 31, 2017

 

 

 

Estimated Fair Value

Financial Assets

 

Carrying Amount

 

Level 1

 

Level 2

 

Level 3

 

 

 

Total

Cash

 

$

0.3

 

 

 

$

0.3

 

 

 

$

 

 

 

$

 

 

 

$

0.3

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Financial Liabilities

 

 

 

 

 

 

 

 

 

 

 

 

Long-term debt

 

$

398.7

 

 

 

$

 

 

 

$

408.1

 

 

 

$

 

 

 

$

408.1

 

 

 

 

Notes Payable to Associated

Companies

 

 

389.9

 

 

 

 

 

 

 

 

389.9

 

 

 

 

 

 

 

 

389.9

 

 

 

 

 

Note 6: Commitments and Contingencies

 

Legal Proceedings and Settlements

 

Gulf South is party to various legal actions arising in the normal course of business. Management believes the disposition of these outstanding legal actions will not have a material impact on Gulf South's financial condition, results of operations or cash flows.

 

Environmental and Safety Matters

 

Gulf South is subject to federal, state, and local environmental laws and regulations in connection with the operation and remediation of various operating sites. As of March 31, 2018, and December 31, 2017, Gulf South had an accrued liability of approximately $4.2 million and $4.3 million related to assessment and/or remediation costs associated with the historical use of polychlorinated biphenyls, petroleum hydrocarbons and mercury. The liability represents management’s estimate of the undiscounted future obligations based on evaluations and discussions with counsel and operating personnel and the current facts and circumstances related to these matters. As of March 31, 2018, and December 31, 2017, approximately $1.0 million was recorded in Miscellaneous Current and Accrued Liabilities and approximately $3.2 million and $3.3 million were recorded in Other Deferred Credits.

 

Commitments for Construction

 

Gulf South’s future capital commitments are comprised of binding commitments under purchase orders for materials ordered but not received and firm commitments under binding construction service agreements. The commitments as of March 31, 2018, were approximately $139.2 million, all of which are expected to be settled within the next twelve months.

 

There were no substantial changes to Gulf South’s operating lease commitments or pipeline capacity agreements disclosed in Note 3 to Gulf South’s 2017 Form 2.

 

 

Note 7:  Financing

 

Long-Term Debt

As of March 31, 2018, and December 31, 2017, Gulf South had notes outstanding of $300.0 million with a weighted-average interest rate of 4.43%. The indentures governing the notes have restrictive covenants which provide that, with certain exceptions, Gulf South cannot create, assume or suffer to exist any lien upon any property to secure any indebtedness unless the debentures and notes shall be equally and ratably secured. All of Gulf South's debt obligations are unsecured. At March 31, 2018, Gulf South was in compliance with its debt covenants.

 

Revolving Credit Facility

 

Boardwalk Pipelines has a revolving credit facility having aggregate lending commitments of $1.5 billion and for which Gulf South is a borrower under the revolving credit facility with a borrowing sub-limit of $400.0 million. Gulf South’s sub-limit can be changed at Gulf South’s option as long as the aggregate lending commitments under the facility do not exceed $1.5 billion. Gulf South’s outstanding borrowings under the credit facility as of March 31, 2018 and December 31, 2017 was $100.0 million with a weighted-average borrowing rate of 3.07% and 2.74%, resulting in an available borrowing capacity of $300.0 million. As of May 30, 2018, Gulf South had outstanding borrowings of $110.0 million, resulting in an available borrowing capacity of $290.0 million. Boardwalk Pipelines and its subsidiaries, including Gulf South, were in compliance with all covenant requirements under the credit facility as of March 31, 2018.

 

 

 

Note 8:  Employee Benefits

 

Defined Contribution Plans

 

Gulf South employees are provided retirement benefits under a defined contribution money purchase plan and a 401(k) plan. Costs related to the defined contribution plans were $1.6 million and $1.5 million for the three months ended March 31, 2018 and 2017.

 

 

Note 9:  Related Party Transactions

 

Gulf South makes advances to or receives advances from Boardwalk Pipelines under the cash management program described in Note 2 of the 2017 Form 2. At March 31, 2018, and December 31, 2017, advances due from Gulf South to Boardwalk Pipelines totaled $419.1 million and $389.9 million. The advances are represented by demand notes. The interest rate on intercompany demand notes is compounded monthly based on LIBOR plus one percent and is adjusted quarterly.

 

Boardwalk Pipelines and Boardwalk Pipeline Partners provide certain management and other services to Gulf South, which includes corporate service charges received from Loews. For the three months ended March 31, 2018 and 2017, Boardwalk Pipelines and Boardwalk Pipeline Partners charged Gulf South $2.0 million and $2.1 million for these services.

 

Amounts applicable to transportation and storage services with associated companies, including fuel costs, included in the Statement of Income are as follows (in millions):

 

 

 

For the Three Months Ended

March 31,

Associated Companies:

 

 

2018

 

 

2017

Gulf Crossing Pipeline Company LLC (Gulf Crossing):

 

 

 

 

 

 

Gas Operating Revenues - associated companies

 

$

17.6

 

$

17.7

Texas Gas Transmission, LLC (Texas Gas):

 

 

 

 

 

 

Operation Expenses – associated companies

 

$

4.9

 

$

4.2

 

 

Note 10: Supplemental Disclosure of Cash Flow Information (in millions):

 

 

For the Three Months Ended

March 31,

 

2018

 

2017

Cash paid during the period for:

 

 

 

Interest (net of AFUDC borrowed)

$

0.2

 

 

$

8.1

 

 

 

 

 

 

 

 

 

Non-cash adjustments:

 

 

 

 

 

 

 

Accounts payable and Plant

$

36.5

 

 

$

48.1

 



Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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)
4,976,803,784
4,976,803,784
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)
4,976,803,784
4,976,803,784
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
11
ConstructionWorkInProgress
Construction Work in Progress
238,264,526
238,264,526
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
13
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Total of lines 8 thru 12)
5,215,068,310
5,215,068,310
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
1,794,853,133
1,794,853,133
15
UtilityPlantNet
Net Utility Plant (Total of lines 13 and 14)
3,420,215,177
3,420,215,177
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
1,791,847,367
1,791,847,367
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
3,005,766
3,005,766
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
22
DepreciationAmortizationAndDepletionUtilityPlantInService
TOTAL In Service (Total of lines 18 thru 21)
1,794,853,133
1,794,853,133
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)
1,794,853,133
1,794,853,133


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
39,808,892
6,734,620
2
Productions-Manufactured Gas
3
Production and Gathering-Natural Gas
82,381,018
69,628,276
4
Products Extraction-Natural Gas
5
Underground Gas Storage
462,487,685
220,330,965
6
Other Storage Plant
7
Base Load LNG Terminaling and Processing Plant
8
Transmission
4,249,315,773
1,395,250,575
9
Distribution
10
General
142,810,416
102,908,697
11
TOTAL (total of lines 1 thru 10)
4,976,803,784
1,794,853,133


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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)
Tax Gross-up on AFUDC Equity
38,546,405
1,348,823
125,378
39,769,850
2
Amortization Period: 48 Years
3
Asset Retirement Obligation
51,071
51,071
4
(b)
Fuel Tracker
3,400,006
2,004,789
5,404,795
5
(c)
Reg asset on Reg liability for excess DFIT
47,933,926
354,541
47,579,385
40
TOTAL
89,931,408
3,353,612
479,919
92,805,101


FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

-- FERC Docket # RP15-65-0000

(b) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Fuel Tracker Mechanism

-- FERC Docket #RP18-132-000

(c) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

The Regulatory Asset represents the gross up recorded on the Regulatory Liability for Excess Deferred Federal Income Taxes caused by the reduction in Federal Income tax rate in the Tax Cuts and Jobs Act of 2017.


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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)
Imbalance Cash In/Out
2,205,957
851,021
3,056,978
2
Excess Deferred Federal Income taxes
3
(b)
per Tax Cut and Jobs Act of 2017
168,370,924
1,245,347
167,125,577
45
Total
170,576,881
1,245,347
851,021
170,182,555


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Imbalance Cash In/Out

-- FERC Docket #RP11-2473

(b) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

A Regulatory Liability on Excess Deferred Federal Income Taxes was recorded due to the tax rate reductions in the Tax Cuts and Jobs Act of 2017.


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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)
1,727
1,727
2
Transportation of Gas for Others (489.2 and 489..3)
3
FTS
117,846,112
108,871
29,445,834
29,554,705
89,321,323
81,758
21,788,285
21,870,043
104,207,822
95,241
24,105,477
24,200,718
4
ITS
13,766,599
17,829
1,371,155
1,388,984
5,612,479
7,363
447,140
454,503
4,981,038
6,475
880,561
887,036
5
NNS
10,823,324
14,071
10,930,568
10,944,639
5,628,076
7,316
9,741,179
9,748,495
4,681,448
6,086
10,734,485
10,740,571
6
NNS-SCO
741,861
965
723,227
724,192
341,699
444
333,964
334,408
343,606
447
337,616
338,063
7
FTS-SCO
604,666
788
387,591
388,379
239,370
311
154,427
154,738
185,407
241
119,925
120,166
8
PAL
537,877
537,877
451,572
451,572
277,165
277,165
9
PXS
2,011,988
2,615
88,597
91,212
2,728,232
3,547
93,144
96,691
2,220,935
2,887
87,081
89,968
10
PS
11
FTS-P
5,833,652
7,584
1,294,301
1,301,885
1,274,244
1,656
1,160,221
1,161,877
3,322,332
4,319
1,287,432
1,291,751
12
ITS-P
1,369,335
1,780
69,395
71,175
441,882
574
25,111
25,685
415,291
540
20,886
21,426
63
Total Transportation (Other than Gathering)
152,997,537
154,503
44,848,545
45,003,048
105,587,305
102,969
34,195,043
34,298,012
120,357,879
116,236
37,850,628
37,966,864
64
Storage (489.4)
65
66
14,092,434
1,014,513
1,014,513
5,293,818
976,806
976,806
1,349,926
970,766
970,766
67
10,307,491
6,400
1,950,719
1,957,119
2,045,601
1,808
1,921,529
1,923,337
4,891,487
3,468
1,775,765
1,779,233
68
42,182
9,100
9,100
94,378
3,586
3,586
69
167,343
209
25,893
26,102
193,000
216
741
957
138,272
161
22,775
22,936
70
71
1,910
1,910
1,725
1,725
1,910
1,910
90
Total Storage
24,567,268
6,609
2,993,035
2,999,644
7,574,601
2,024
2,909,901
2,911,925
6,474,063
3,629
2,774,802
2,778,431
91
Gathering (489.1)
92
Gathering-Firm
7,936
29
29
6,375
702
702
5,356
1,023
1,023
93
Gathering-Interruptible
2,251,868
108,878
108,878
1,750,845
110,204
110,204
2,281,727
132,284
132,284
94
Total Gathering (489.1)
2,259,804
108,907
108,907
1,757,220
110,906
110,906
2,287,083
133,307
133,307
95
Additional Revenues
96
Products Sales and Extraction (490-492)
18,779
18,779
73,015
73,015
71,160
71,160
97
Rents (493-494)
300
300
8,619
8,619
300
300
98
(495) Other Gas Revenues
35,675
35,675
233,888
233,888
180,771
180,771
99
(496) (Less) Provision for Rate Refunds
100
Total Additional Revenues
54,754
54,754
315,522
315,522
252,231
252,231
101
Total Operating Revenues (Total of Lines 1,63,90,94 & 100)
179,824,609
161,112
48,005,241
48,166,353
114,919,126
104,993
37,531,372
37,636,365
129,119,025
119,865
41,012,695
41,132,560


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
1,727
9 MiscellaneousServiceRevenuesAbstract (488) Miscellaneous Service Revenues
10 RevenuesFromTransportationOfGasOfOthersThroughGatheringFacilitiesAbstract (489.1) Revenues from Transportation of Gas of Others Through Gathering Facilities
353,120
6,304,107
11 RevenuesFromTransportationOfGasOfOthersThroughTransmissionFacilitiesAbstract (489.2) Revenues from Transportation of Gas of Others Through Transmission Facilities
117,267,924
378,942,721
12 RevenuesFromTransportationOfGasOfOthersThroughDistributionFacilitiesAbstract (489.3) Revenues from Transportation of Gas of Others Through Distribution Facilities
13 RevenuesFromStoringGasOfOthersAbstract (489.4) Revenues from Storing Gas of Others
8,690,000
38,615,932
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
162,954
17 RentFromGasPropertyAbstract (493) Rent from Gas Property
9,219
18 InterdepartmentalRentsAbstract (494) Interdepartmental Rents
19 OtherGasRevenuesAbstract (495) Other Gas Revenues
450,334
20 OperatingRevenuesBeforeProvisionForRateRefundsAbstract Subtotal:
126,935,278
21 ProvisionForRateRefundsAbstract (496) (Less) Provision for Rate Refunds
22 OperatingRevenuesAbstract TOTAL
126,935,278


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
186,787
6
ProductionMaintenanceExpense (761-769) Maintenance
22,320
7
NaturalGasProductionAndGatheringPlantExpense Total Natural Gas Production and Gathering (lines 5 and 6)
209,107
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
101,994
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
146,352
23
PurchasedGasCostAdjustments (805.1) (Less) Purchase Gas Cost Adjustments
24
PurchasedGasOperationExpenses Total Purchased Gas (lines 15 through 23)
44,358
25
ExchangeGas (806) Exchange Gas
2,673,234
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
19,008,296
34
GasDeliveredToStorageCredit (808.2) (Less) Gas Delivered to Storage - Credit
14,033,061
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
11,597,153
39
GasUsedForProductsExtractionCredit (811) Gas Used for Products Extraction - Credit
72,772
40
GasUsedForOtherUtilityOperationsCredit (812) Gas Used for Other Utility Operations - Credit
1,441,605
41
GasUsedInUtilityOperationCredit Total Gas Used in Utility Operations - Credit (Lines 38 thru 40)
13,111,530
42
OtherGasSupplyExpenses (813) Other Gas Supply Expense
323,946
43
OtherGasSupplyExpensesOperation Total Other Gas Supply Expenses (Lines 24, 25, 32, 33, thru 36, 42, less 41)
10,441,225
44
ProductionExpenses Total Production Expenses (Lines 3,7,11,12, and 43)
10,232,118


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
2,598,160
4
UndergroundStorageMaintenanceExpenses (830-837) Maintenance
468,922
5
UndergroundStorageExpenses Total Underground Storage Expenses (Lines 3 and 4)
3,067,082
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
118,979
17
SystemControlAndLoadDispatchingGas (851) System Control and Load Dispatching
308,945
18
CommunicationSystemExpenses (852) Communication System Expenses
798,837
19
CompressorStationLaborAndExpensesTransmissionExpenses (853) Compressor Station Labor and Expenses
3,134,119
20
GasForCompressorStationFuel (854) Gas for Compressor Station Fuel
11,028,710
21
OtherFuelAndPowerForCompressorStations (855) Other Fuel and Power for Compressor Stations
29,126
22
MainsExpenses (856) Mains Expenses
6,275,164
23
MeasuringAndRegulatingStationExpensesTransmissionExpenses (857) Measuring and Regulating Station Expenses
1,696,712
24
TransmissionAndCompressionOfGasByOthers (858) Transmission and Compression of Gas by Others
6,868,452
25
OtherExpensesGasTransmission (859) Other Expenses
319,986
26
RentsGasTransmissionExpense (860) Rents
198,346
27
TransmissionOperationExpense Total Transmission Operation Expenses (Lines 16 through 26)
30,777,376
28
TransmissionExpensesMaintenanceAbstract Transmission Maintenance Expenses
29
MaintenanceSupervisionAndEngineeringGasTransmissionExpenses (861) Maintenance Supervision and Engineering
974,565
30
MaintenanceOfStructuresAndImprovementsTransmissionExpenses (862) Maintenance of Structures and Improvements
121,698
31
MaintenanceOfMainsTransmissionExpenses (863) Maintenance of Mains
2,890,980
32
MaintenanceOfCompressorStationEquipmentTransmissionExpenses (864) Maintenance of Compressor Station Equipment
1,322,066
33
MaintenanceOfMeasuringAndRegulatingStationEquipment (865) Maintenance of Measuring and Regulating Equipment
227,046
34
MaintenanceOfCommunicationEquipmentGasTransmission (866) Maintenance of Communication Equipment
32,036
35
MaintenanceOfOtherEquipmentTransmissionExpenses (867) Maintenance of Other Equipment
36
TransmissionMaintenanceExpensesGas Total Transmission Maintenance Expenses (Lines 29 through 35)
5,568,391
37
TransmissionExpenses Total Transmission Expenses (lines 27 and 36)
36,345,767
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)
39,412,849


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
23,224
2
CustomerServiceAndInformationalExpenses (907-910) Customer Service and Information Expenses
3
SalesExpenses (911-916) Sales Expenses
18,789
4
AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
5
AdministrativeAndGeneralExpensesOperationAbstract Operations
6
AdministrativeAndGeneralSalaries 920 Administrative and General Salaries
10,210,249
7
OfficeSuppliesAndExpenses 921 Office Supplies and Expenses
1,090,016
8
AdministrativeExpensesTransferredCredit (Less) 922 Administrative Expenses Transferred-Credit
5,481,516
9
OutsideServicesEmployed 923 Outside Services Employed
3,051,025
10
PropertyInsurance 924 Property Insurance
486,783
11
InjuriesAndDamages 925 Injuries and Damages
778,633
12
EmployeePensionsAndBenefits 926 Employee Pensions and Benefits
2,827,529
13
FranchiseRequirements 927 Franchise Requirements
14
RegulatoryCommissionExpenses 928 Regulatory Commission Expenses
322,668
15
DuplicateChargesCredit (Less) 929 Duplicate Charges-Credit
16
GeneralAdvertisingExpenses 930.1 General Advertising Expenses
17
MiscellaneousGeneralExpenses 930.2 Miscellaneous General Expenses
78,744
18
RentsAdministrativeAndGeneralExpense 931 Rents
440,240
19
AdministrativeAndGeneralOperationExpense TOTAL Operation (Total of lines 6 through 18)
13,804,371
20
MaintenanceAbstract Maintenance
21
MaintenanceOfGeneralPlant 932 Maintenance of General Plant
22
AdministrativeAndGeneralExpenses TOTAL Administrative and General Expenses (Total of lines 19 and 21)
13,804,371


Name of Respondent:


Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:


05/30/2018
Year/Period of Report:


End of:
2018
/
Q1
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
248,031
248,031
2
Production Plant, Manufacturing Plant
3
Production and Gathering Plant - Natural Gas
315,853
313,484
629,337
4
Products Extraction - Natural Gas
5
Underground Gas Storage Plant
1,855,542
15,359
1,129
1,872,030
6
Other Storage Plant
7
Base Load LNG Terminaling and Processing Plant
8
Processing Plant
9
Transmission Plant
23,133,100
23,133,100
10
Distribution Plant
11
General Plant
2,032,636
2,032,636
12
Common Plant
13
Total
27,585,162
328,843
1,129
27,915,134


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
2
QuantityOfNaturalGasReceivedByUtilityAbstract
GAS RECEIVED
3
QuantityOfNaturalGasReceivedByUtilityGasPurchases
Gas Purchases (Accounts 800-805)
4
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForGathering
Gas of Others Received for Gathering (Account 489.1)
303
(a)
6,302,256
(h)
6,302,256
5
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForTransmission
Gas of Others Received for Transmission (Account 489.2)
305
281,165,075
281,165,075
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
38,615,932
38,615,932
8
QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForProductionExtractionProcessing
Gas of Others Received for Production/Extraction/Processing (Account 490 and 491)
9
QuantityOfNaturalGasReceivedByUtilityExchangedGasReceivedFromOthers
Exchanged Gas Received from Others (Account 806)
328
16,111,596
16,111,596
10
QuantityOfNaturalGasReceivedByUtilityGasReceivedAsImbalances
Gas Received as Imbalances (Account 806)
328
89,041,579
89,041,579
11
QuantityOfNaturalGasReceivedByUtilityReceiptsOfUtilitysGasTransportedByOthers
Receipts of Respondent's Gas Transported by Others (Account 858)
332
58,873,879
58,873,879
12
QuantityOfNaturalGasReceivedByUtilityOtherGasWithdrawnFromStorage
Other Gas Withdrawn from Storage (Explain)
(b)
3,352,212
(i)
3,352,212
13
QuantityOfNaturalGasReceivedByUtilityGasReceivedFromShippersAsCompressorStationFuel
Gas Received from Shippers as Compressor Station Fuel
(c)
3,314,540
(j)
3,314,540
14
QuantityOfNaturalGasReceivedByUtilityGasReceivedFromShippersAsLostAndUnaccountedFor
Gas Received from Shippers as Lost and Unaccounted for
15
QuantityOfNaturalGasReceivedByUtilityOther
Other Receipts (Specify) (footnote details)
(d)
57,921,728
(k)
57,921,728
15.1
QuantityOfNaturalGasReceivedByUtilityOther
Other Receipts (Specify) (footnote details)
16
QuantityOfNaturalGasReceivedByUtility
Total Receipts (Total of lines 3 thru 15)
554,698,797
554,698,797
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
(e)
287,465,208
(l)
287,465,208
21
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasDistributedForOthers
Deliveries of Gas Distributed for Others (Account 489.3)
301
22
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfContractStorageGas
Deliveries of Contract Storage Gas (Account 489.4)
307
16,211,391
16,211,391
23
QuantityOfNaturalGasDeliveredByUtilityGasOfOthersDeliveredForProductionExtractionProcessing
Gas of Others Delivered for Production/Extraction/Processing (Account 490 and 491)
24
QuantityOfNaturalGasDeliveredByUtilityExchangeGasDeliveredToOthers
Exchange Gas Delivered to Others (Account 806)
328
16,114,891
16,114,891
25
QuantityOfNaturalGasDeliveredByUtilityGasDeliveredAsImbalances
Gas Delivered as Imbalances (Account 806)
328
90,136,473
90,136,473
26
QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasToOthersForTransportation
Deliveries of Gas to Others for Transportation (Account 858)
332
58,932,292
58,932,292
27
QuantityOfNaturalGasDeliveredByUtilityOtherGasDeliveredToStorage
Other Gas Delivered to Storage (Explain)
(f)
819,141
(m)
819,141
28
QuantityOfNaturalGasDeliveredByUtilityGasUsedForCompressorStationFuel
Gas Used for Compressor Station Fuel
509
3,927,343
3,927,343
29
GasUsedForOtherDeliveriesAndGasUsedForOtherOperations
Other Deliveries and Gas Used for Other Operations
(g)
82,552,465
(n)
82,552,465
29.1
GasUsedForOtherDeliveriesAndGasUsedForOtherOperations
Other Deliveries and Gas Used for Other Operations
30
QuantityOfNaturalGasDeliveredByUtility
Total Deliveries (Total of lines 18 thru 29)
554,520,922
554,520,922
31
GasLossesAndGasUnaccountedForGasAccountAbstract
GAS LOSSES AND GAS UNACCOUNTED FOR
32
GasAccountGasLossesAndGasUnaccountedForGasAccount
Gas Losses and Gas Unaccounted For
177,875
177,875
33
DeliveriesGasLossesAndUnaccountedForGasAccountAbstract
TOTALS
34
DeliveriesGasLossesAndUnaccountedForGasAccount
Total Deliveries, Gas Losses & Unaccounted For (Total of lines 30 and 32)
554,698,797
554,698,797


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
FOOTNOTE DATA

(a) Concept: QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForGathering

Total gathered volumes on Line 4 differ from total gathered volumes on page 309 due to fuel retainage on gathering of 1,851 dth.

(b) Concept: QuantityOfNaturalGasReceivedByUtilityOtherGasWithdrawnFromStorage

 

YTD

No-Notice Withdrawals

22,560,014

System Management

(19,207,802)

Total

3,352,212

(c) Concept: QuantityOfNaturalGasReceivedByUtilityGasReceivedFromShippersAsCompressorStationFuel

 

YTD

Fuel Retained

3,551,632

Fuel to Others

(237,092)

Total

3,314,540

(d) Concept: QuantityOfNaturalGasReceivedByUtilityOther

 

YTD

Condensate

1,056

PAL

7,759,685

Line Pack

5,920,595

Storage Adjustments

1,005

Storage Reversals - Scheduled Injections

44,347,464

Other Storage Adj. (NNS Imbalance)

(108,077)

Total

57,921,728

(e) Concept: QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasTransportedForOthers

For the purpose of ACA Calculation, the throughput volume is 296,897,426 dth represented as follows:

 

 

YTD

Line 20

287,465,208

Physical Deliveries included in Line 7

9,432,218

Total

296,897,426

(f) Concept: QuantityOfNaturalGasDeliveredByUtilityOtherGasDeliveredToStorage

 

YTD

No-Notice Injections

20,848,929

System Management

(21,668,070)

Total

(819,141)

(g) Concept: GasUsedForOtherDeliveriesAndGasUsedForOtherOperations

 

YTD

Condensate

25,634

PAL

7,333,654

Line Pack

6,113,642

Storage Adjustments

27,036

Storage Reversals - Scheduled Withdrawals

68,935,631

Gas Used for Operations

147,466

Other Storage Adj. (NNS Imbalance)

(30,598)

Total

82,552,465

(h) Concept: QuantityOfNaturalGasReceivedByUtilityGasOfOthersReceivedForGathering

Total gathered volumes on Line 4 differ from total gathered volumes on page 309 due to fuel retainage on gathering of 1,851 dth.

(i) Concept: QuantityOfNaturalGasReceivedByUtilityOtherGasWithdrawnFromStorage

 

YTD

No-Notice Withdrawals

22,560,014

System Management

(19,207,802)

Total

3,352,212

(j) Concept: QuantityOfNaturalGasReceivedByUtilityGasReceivedFromShippersAsCompressorStationFuel

 

YTD

Fuel Retained

3,551,632

Fuel to Others

(237,092)

Total

3,314,540

(k) Concept: QuantityOfNaturalGasReceivedByUtilityOther

 

YTD

Condensate

1,056

PAL

7,759,685

Line Pack

5,920,595

Storage Adjustments

1,005

Storage Reversals - Scheduled Injections

44,347,464

Other Storage Adj. (NNS Imbalance)

(108,077)

Total

57,921,728

(l) Concept: QuantityOfNaturalGasDeliveredByUtilityDeliveriesOfGasTransportedForOthers

For the purpose of ACA Calculation, the throughput volume is 296,897,426 dth represented as follows:

 

 

YTD

Line 20

287,465,208

Physical Deliveries included in Line 7

9,432,218

Total

296,897,426

(m) Concept: QuantityOfNaturalGasDeliveredByUtilityOtherGasDeliveredToStorage

 

YTD

No-Notice Injections

20,848,929

System Management

(21,668,070)

Total

(819,141)

(n) Concept: GasUsedForOtherDeliveriesAndGasUsedForOtherOperations

 

YTD

Condensate

25,634

PAL

7,333,654

Line Pack

6,113,642

Storage Adjustments

27,036

Storage Reversals - Scheduled Withdrawals

68,935,631

Gas Used for Operations

147,466

Other Storage Adj. (NNS Imbalance)

(30,598)

Total

82,552,465


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
232,349
470,372
561,866
1,264,587
636,171
1,287,879
1,538,389
3,462,439
(e)
31,980
31,980
5
Distribution
6
Storage
7,788
7,788
21,324
21,324
7
Total Shipper Supplied Gas
232,349
470,372
569,654
(a)
1,272,375
636,171
1,287,879
1,559,713
3,483,763
31,980
31,980
LESS GAS USED FOR COMPRESSOR STATION FUEL (LINE 28, PAGE 520)
9
Gathering
10
Production/Extraction/Processing
11
Transmission
374,888
471,265
711,152
1,557,305
1,026,443
1,290,325
1,947,133
4,263,901
12
Distribution
13
Storage
12,577
12,577
34,436
34,436
14
Total gas used in compressors
374,888
471,265
723,729
1,569,882
1,026,443
1,290,325
1,981,569
(b)
4,298,337
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
20,364
25,220
38,551
84,135
55,757
69,052
105,553
230,362
19
Distribution
20
Storage
6,258
6,258
17,134
17,134
21
Other Deliveries (specify) (footnote details)
22
Total Gas Used For Other Deliveries And Gas Used For Other Operations
20,364
25,220
44,809
90,393
55,757
69,052
122,687
(c)
247,496
23
LESS GAS LOST AND UNACCOUNTED FOR (LINE 32, PAGE 520)
24
Gathering
25
Production/Extraction/Processing
26
Transmission
56,400
69,846
106,770
233,016
154,423
191,241
292,336
638,000
27
Distribution
28
Storage
29
Other Deliveries (specify) (footnote details)
30
Total Gas Lost And Unaccounted For
56,400
69,846
106,770
233,016
154,423
191,241
292,336
(d)
638,000
30.1
NET EXCESS OR (DEFICIENCY)
31
Other Losses
32
Gathering
33
Production/Extraction/Processing
34
Transmission
219,303
95,959
294,607
609,869
600,452
262,739
806,633
1,669,824
35
Distribution
36
Storage
11,047
11,047
30,246
30,246
37
Total Net Excess Or (Deficiency)
219,303
95,959
305,654
620,916
600,452
262,739
836,879
1,700,070
38
DISPOSITION OF EXCESS GAS:
39
Gas sold to others
40
Gas used to meet imbalances
41
Gas added to system gas
219,303
95,959
305,654
620,916
600,452
262,739
836,879
1,700,070
42
Gas returned to shippers
43.1
43.2
43.3
43.4
43.5
43.6
43.7
43.8
51
Total Disposition Of Excess Gas
219,303
95,959
305,654
620,916
600,452
262,739
836,879
1,700,070
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
(f)
388,374,939
67
Backhaul Volume in Dths for the Quarter
68
TOTAL (Lines 66 and 67)
388,374,939


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
FOOTNOTE DATA

(a) Concept: ShipperSuppliedGas

Gas is valued at current market prices using NYMEX settlement prices.

(b) Concept: AmountCollectedGasUsedInCompressorStations

Allocated total gas used in compressors into discounted, negotiated and recourse based on gross receipts for each contract.

(c) Concept: AmountCollectedGasUsedForOtherDeliveriesAndGasUsedForOtherOperations

Allocated total gas used for other deliveries into discounted, negotiated and recourse based on gross receipts for each contract.

(d) Concept: AmountCollectedGasLostAndUnaccountedFor

Allocated total gas lost and unaccounted for into deliveries into discounted, negotiated and recourse based on gross receipts for each contract.

(e) Concept: VolumeNotCollectedShipperSuppliedGasTransmission

This amount represents a calculation of fuel over collected on contracts due to negotiated fuel rates that are greater than max tariff fuel rates.

(f) Concept: ForwardhaulVolumeOfThroughput

Line 66

QTD

Pg 520 ACA Throughput

296,897,426

Lease for others

91,477,513

 

388,374,939


Name of Respondent:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
169,458
288,339
465,854
923,651
615,301
1,046,959
1,691,517
3,353,777
9,451
9,451
5
Distribution
6
Storage
4
5,780
5,776
15
20,987
20,972
7
Total Shipper Supplied Gas
169,458
288,335
471,634
929,427
615,301
1,046,944
1,712,504
3,374,749
9,451
9,451
8
LESS GAS USED FOR COMPRESSOR STATION FUEL (LINE 28, PAGE 520)
9
Gathering
10
Production/Extraction/Processing
11
Transmission
258,990
276,811
536,725
1,072,526
940,391
1,005,102
1,948,849
3,894,342
12
Distribution
13
Storage
13,640
13,640
49,527
49,527
14
Total gas used in compressors
258,990
276,811
550,365
1,086,166
940,391
1,005,102
1,998,376
3,943,869
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
7,969
8,485
16,539
32,993
28,935
30,809
60,053
119,797
19
Distribution
20
Storage
6,558
6,558
23,812
23,812
21
Other Deliveries (specify) (footnote details)
22
Total Gas Used For Other Deliveries And Gas Used For Other Operations
7,969
8,485
23,097
39,551
28,935
30,809
83,865
143,609
23
LESS GAS LOST AND UNACCOUNTED FOR (LINE 32, PAGE 520)
24
Gathering
25
Production/Extraction/Processing
26
Transmission
25,018
26,636
51,923
103,577
90,840
96,719
188,532
376,091
27
Distribution
28
Storage
29
Other Deliveries (specify) (footnote details)
30
Total Gas Lost And Unaccounted For
25,018
26,636
51,923
103,577
90,840
96,719
188,532
376,091
30.1
NET EXCESS OR (DEFICIENCY)
31
Other Losses
32
Gathering
33
Production/Extraction/Processing
34
Transmission
72,483
29,679
35,487
78,291
263,185
107,767
128,853
284,271
35
Distribution
36
Storage
4
14,418
14,422
15
52,352
52,367
37
Total Net Excess Or (Deficiency)
72,483
29,675
49,905
92,713
263,185
107,752
181,205
336,638
38
DISPOSITION OF EXCESS GAS:
39
Gas sold to others
40
Gas used to meet imbalances
41
Gas added to system gas
72,483
29,675
49,905
92,713
263,185
107,752
181,205
336,638
42
Gas returned to shippers
43.1
43.2
43.3
43.4
43.5
43.6
43.7
43.8
51
Total Disposition Of Excess Gas
72,483
29,675
49,905
92,713
263,185
107,752
181,205
336,638
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:

Gulf South Pipeline Company, LP
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

05/30/2018
Year/Period of Report:

End of:
2018
/
Q1
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
179,727
359,158
569,602
1,108,487
474,300
947,817
1,503,180
2,925,297
9,274
9,274
5
Distribution
6
Storage
4,251
4,251
11,218
11,218
7
Total Shipper Supplied Gas
179,727
359,158
573,853
1,112,738
474,300
947,817
1,514,398
2,936,515
9,274
9,274
8
LESS GAS USED FOR COMPRESSOR STATION FUEL (LINE 28, PAGE 520)
9
Gathering
10
Production/Extraction/Processing
11
Transmission
278,778
342,755
644,169
1,265,702
735,695
904,531
1,699,962
3,340,188
12
Distribution
13
Storage
5,593
5,593
14,760
14,760
14
Total gas used in compressors
278,778
342,755
649,762
1,271,295
735,695
904,531
1,714,722
3,354,948
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
8,553
10,471
19,758
38,782
22,571
27,633
52,141
102,345
19
Distribution
20
Storage
3,318
3,318
8,756
8,756
21
Other Deliveries (specify) (footnote details)
22
Total Gas Used For Other Deliveries And Gas Used For Other Operations
8,553
10,471
23,076
42,100
22,571
27,633
60,897
111,101
23
LESS GAS LOST AND UNACCOUNTED FOR (LINE 32, PAGE 520)
24
Gathering
25
Production/Extraction/Processing
26
Transmission
10,682
13,077
24,677
48,436
28,190
34,510
65,123
127,823
27
Distribution
28
Storage
29
Other Deliveries (specify) (footnote details)
30
Total Gas Lost And Unaccounted For
10,682
13,077
24,677
48,436
28,190
34,510
65,123
127,823
30.1
NET EXCESS OR (DEFICIENCY)
31
Other Losses
32
Gathering
33
Production/Extraction/Processing
34
Transmission
118,286
7,145
119,002
244,433
312,156
18,857
314,046
645,059
35
Distribution
36
Storage
4,660
4,660
12,298
12,298
37
Total Net Excess Or (Deficiency)
118,286
7,145
123,662
249,093
312,156
18,857
326,344
657,357
38
DISPOSITION OF EXCESS GAS:
39
Gas sold to others
40
Gas used to meet imbalances
41
Gas added to system gas
118,286
7,145
123,662
249,093
312,156
18,857
326,344
657,357
42
Gas returned to shippers
43.1
43.2
43.3
43.4
43.5
43.6
43.7
43.8
51
Total Disposition Of Excess Gas
118,286
7,145
123,662
249,093
312,156
18,857
326,344
657,357
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

XBRL Instance File
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