2001Annual Report.pdf

Check appropriate box:
An Original Signed Form
Conformed Copy
Form Approved
OMB No. 1902-0028
(Expires 3/31/2005)
FERC Form No. 2
ANNUAL REPORT OF MAJOR
NATURAL GAS COMPANIES
This report is mandatory under the Natural Gas Act, Sections 10(a), and 16
and 18 CFR 260.1. Failure to report may result in criminal fines, civil
penalties, another sanctions as provided by law. The Federal Energy
Regulatory Commission does not consider this report to be of a confidential
nature.
FERC FORM No. 2 (1-99)
Exact Legal Name of Respondent (Company)Year of Report
Dec. 31, 2001Questar Pipeline Company
ANNUAL REPORT OF MAJOR NATURAL GAS COMPANIES
180 East 100 South, Salt Lake City, Utah, 84111
04/29/2002
ControllerDavid M. Curtis
12/31/2001
180 East 100 South, Salt Lake City, Utah, 84111
SupervisorJeff Callor
This Report Is:
(1) An Original
(2) A Resubmission
02 Year of Report
Dec. 31, Questar Pipeline Company
X
2001
01 Exact Legal Name of Respondent
IDENTIFICATION
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)
05 Name of Contact Person 06 Title of Contact Person
07 Address of Contact Person (Street, City, State, Zip Code)
801-324-5249
08 Telephone of Contact Person, Including Area Code 10 Date of Report
(Mo, Da, Yr)
ATTESTATION
The undersigned officer certifies that he/she has examined the accompanying report; that to the best of his/her knowledge,
information, and belief, all statements of fact contained in the accompanying report are true and the accompanying report
is a correct statement of the business and affairs of the above named respondent in respect to each and every matter set
forth therein during the period from and including January 1 to and including December 31 of the year of the report.
11 Name 12 Title
13 Signature 14 Date Signed
Title 18, U.S.C. 1001, makes it a crime for any person 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.
Page 1FERC FORM NO. 2 (12-96)
List of Schedules (Natural Gas Company)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Title of Schedule
(a)
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."
Reference
Page No.
(b)
Date Revised
(c)
Remarks
(d)
GENERAL CORPORATE INFORMATION AND FINANCIAL STATEMENTS
101General Information 1
102Control Over Respondent 2
103Corporations Controlled by Respondent 3
107Security Holders and Voting Powers 4
108Important Changes During the Year 5
110-113Comparative Balance Sheet 6
114-116Statement of Income for the Year 7
118-119Statement of Retained Earnings for the Year 8
120-121Statements of Cash Flows 9
122Notes to Financial Statements 10
BALANCE SHEET SUPPORTING SCHEDULES (Assets and Other Debits)
200-201Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization, and Depletion 11
204-209Gas Plant in Service 12
N/A212Gas Property and Capacity Leased from Others 13
213Gas Property and Capacity Leased to Others 14
N/A214Gas Plant Held for Future Use 15
216Construction Work in Progress-Gas 16
218General Description of Construction Overhead Procedure 17
219Accumulated Provision for Depreciation of Gas Utility Plant 18
220Gas Stored 19
N/A222-223Investments 20
224-225Investments in Subsidiary Companies 21
230Prepayments 22
N/A230Extraordinary Property Losses 23
N/A230Unrecovered Plant and Regulatory Study Costs 24
232Other Regulatory Assets 25
233Miscellaneous Deferred Debits 26
234-235Accumulated Deferred Income Taxes 27
BALANCE SHEET SUPPORTING SCHEDULES (Liabilities and Other Credits)
250-251Capital Stock 28
252
Capital Stock Subscribed, Capital Stock Liability for Conversion, Premium on Capital Stock, and
Installments Received on Capital Stock
29
253Other Paid-in Capital 30
N/A254Discount on Capital Stock 31
N/A254Capital Stock Expense 32
N/A255Securities issued or Assumed and Securities Refunded or Retired During the Year 33
256-257Long-Term Debt 34
258-259Unamortized Debt Expense, Premium, and Discount on Long-Term Debt 35
260Unamortized Loss and Gain on Reacquired Debt 36
261Reconciliation of Reported Net Income with Taxable Income for Federal Income Taxes 37
Page 2FERC FORM NO. 2 (12-96)
List of Schedules (Natural Gas Company) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Title of Schedule
(a)
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."
Reference
Page No.
(b)
Date Revised
(c)
Remarks
(d)
262-263Taxes Accrued, Prepaid, and Charged During Year 38
268Miscellaneous Current and Accrued Liabilities 39
269Other Deferred Credits 40
274-275Accumulated Deferred Income Taxes-Other Property 41
276-277Accumulated Deferred Income Taxes-Other 42
278Other Regulatory Liabilities 43
INCOME ACCOUNT SUPPORTING SCHEDULES
300-301Gas Operating Revenues 44
N/A302-303Revenues from Transportation of Gas of Others Through Gathering Facilities 45
304-305Revenues from Transportation of Gas of Others Through Transmission Facilities 46
306-307Revenues from Storage Gas of Others 47
308Other Gas Revenues 48
317-325Gas Operation and Maintenance Expenses 49
328Exchange and Imbalance Transactions 50
331Gas Used in Utility Operations 51
332Transmission and Compression of Gas by Others 52
334Other Gas Supply Expenses 53
335Miscellaneous General Expenses-Gas 54
336-338Depreciation, Depletion, and Amortization of Gas Plant 55
340Particulars Concerning Certain Income Deduction and Interest Charges Accounts 56
COMMON SECTION
350-351Regulatory Commission Expenses 57
354-355Distribution of Salaries and Wages 58
357Charges for Outside Professional and Other Consultative Services 59
GAS PLANT STATISTICAL DATA
508-509Compressor Stations 60
512-513Gas Storage Projects 61
514Transmission Lines 62
518Transmission System Peak Deliveries 63
519Auxiliary Peaking Facilities 64
520Gas Account-Natural Gas 65
522System Map 66
551Footnote Reference 67
552Footnote Text 68
Stockholder's Reports (check appropriate box) 69
Four copies will be submitted
No annual report to stockholders is prepared
X
Page 3FERC FORM NO. 2 (12-96)
General Information
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
David M. Curtis
Controller
180 East 100 South
Salt Lake City, Utah 84111
Colorado - Transportation of Natural Gas
Utah - Transportation and Storage of Natural Gas
Wyoming - Transportation and Storage of Natural Gas
None
(1)
(2)
Utah
01-02-75
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept and address of office
where any other corporate books of account are kept, if different from that where the general corporate books are kept.
2. Provide the name of the State under the laws of which respondent is incorporated and date of incorporation. If incorporated under a special law, give reference to such law. If not
incorporated, state that fact and give the type of organization and the date organized.
3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c)
the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased.
4. State the classes of utility and other services furnished by respondent during the year in each State in which the respondent operated.
Yes... Enter the date when such independent accountant was initially engaged:
NoX
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial
statements?
Page 101FERC FORM NO. 2 (12-96)
Control Over Respondent
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Company Name
(a)
Type of Control
(b)
State of
Incorporation
(c)
1. Report in column (a) the names of all corporations, partnerships, business trusts, and similar organizations that directly, indirectly,
or jointly held control (see page 103 for definition of control) over the respondent at the end of the year. If control is in a holding
company organization, report in a footnote the chain of organization.
2. If control is held by trustees, state in a footnote the names of trustees, the names of beneficiaries for whom the trust is maintained,
and the purpose of the trust.
3. In column (b) designate type of control over the respondent. Report an "M" if the company is the main parent or controlling
company having ultimate control over the respondent. Otherwise, report a "D" for direct, an "I" for indirect, or a "J" for joint control.
Percent Voting
Stock Owned
(d)
Questar Regulated Services Company I UT 1 100.00
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
Page 102FERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
Schedule Page: 102 Line No.: 1 Column: d
All shares of common stock of Questar Pipeline Company are owned by Questar Regulated Services Company. All shares of
common stock of Questar Regulated Services Company are owned by Questar Corporation.
FERC FORM NO. 2 (12-96)Page 552
Corporations Controlled by Respondent
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Name of Company Controlled
(a)
Type of Control
(b)
Kind of Business
(c)
1. Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by
respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote.
2. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held,
naming any intermediaries involved.
3. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests.
4. In column (b) designate type of control of the respondent as "D" for direct, an "I" for indirect, or a "J" for joint control.
---------------------------
DEFINITIONS
---------------------------
1. See the Uniform System of Accounts for a definition of control.
2. Direct control is that which is exercised without interposition of an intermediary.
3. Indirect control is that which is exercised by the interposition of an intermediary that exercises direct control.
4. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the
voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual
agreement or understanding between two or more parties who together have control within the meaning of the definition of control in
the Uniform System of Accounts, regardless of the relative voting rights of each party.
Percent Voting
Stock Owned
(d)
Footnote
Reference
(e)
TransColorado Gas Transmission Company Transporter of Natural Gas Not used 50J 1
Overthrust Pipeline Company Transporter of Natural Gas Not used 72J 2
Questar Southern Trails Pipeline Company Transporter of Natural Gas Not used 100D 3
Questar Transportation Services Natural Gas Processing Not used 100D 4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
Page 103FERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
Schedule Page: 103 Line No.: 2 Column: d
Questar Pipeline acquired an additional 18% of Overthrust Pipeline in January 2002 bringing its ownership percentage to 90%.
FERC FORM NO. 2 (12-96)Page 552
6550843
12/31/2001
May 15, 2001
1140 West 200 South
Salt Lake City, Utah11/23/2001
Other
(e)
Security Holders and Voting Powers
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Name (Title) and Address of
Security Holder
(a)
Total Votes
(b)
1. Give the names and addresses of the 10 security holders of the respondent who, at the date of the latest closing of the stock book
or compilation of list of stockholders of the respondent, prior to the end of the year, had the highest voting powers in the respondent,
and state the number of votes that each could cast on that date if a meeting were held. If any such holder held in trust, give in a
footnote the known particulars of the trust (whether voting trust, etc.), duration of trust, and principal holders of beneficiary interests in
the trust. If the company did not close the stock book or did not compile a list of stockholders within one year prior to the end of the
year, or if since it compiled the previous list of stockholders, some other class of security has become vested with voting rights, then
show such 10 security holders as of the close of the year. Arrange the names of the security holders in the order of voting power,
commencing with the highest. Show in column (a) the titles of officers and directors included in such list of 10 security holders.
2. If any security other than stock carries voting rights, explain in a supplemental statement how such security became vested with
voting rights and give other important details concerning the voting rights of such security. State whether voting rights are actual or
contingent; if contingent, describe the contingency.
3. If any class or issue of security has any special privileges in the election of directors, trustees or managers, or in the determination
of corporate action by any method, explain briefly in a footnote.
4. Furnish details concerning any options, warrants, or rights outstanding at the end of the year for others to purchase securities of
the respondent or any securities or other assets owned by the respondent, including prices, expiration dates, and other material
information relating to exercise of the options, warrants, or rights. Specify the amount of such securities or assets any officer, director,
associated company, or any of the 10 largest security holders is entitled to purchase. This instruction is inapplicable to convertible
securities or to any securities substantially all of which are outstanding in the hands of the general public where the options, warrants,
Common Stock
(c)
Preferred Stock
(d)
1. Give date of the latest closing of the stock
book prior to end of year, and, in a footnote, state
the purpose of such closing:
2. State the total number of votes cast at the latest general
meeting prior to the end of year for election of directors of the
respondent and number of such votes cast by proxy.
3. Give the date and place of
such meeting:
Total:
By Proxy:
VOTING SECURITIES
4. Number of votes as of (date):
TOTAL votes of all voting securities 5 6,550,843 6,550,843
TOTAL number of security holders 6 1 1
TOTAL votes of security holders listed below 7 6,550,843 6,550,843
Questar Regulated Services Comapany 8
180 East 100 South 9
Salt Lake City, Utah 84111 10
11
12
13
14
15
16
17
18
19
20
Page 107FERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
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.
1. None
2. None
3. None
4. None
5. Important Extensions of Respondant’s Transmission System
Docket Nos. CP00-68-000, -001: Pursuant to the FERC order (95 FERC ¶ 61,404) issued June 14, 2001, QPC,
on July 2, 2001, commenced construction of (1) 75-mile, 24-inch diameter Main Line No. 104, extending from
Price, Utah, to an interconnection with Kern River Gas Transmission Company near Elberta, Utah, and (2) two
Solar Taurus 60/C404 gas turbine-engine-driven centrifugal compressors, totaling 14,950 ISO (approximately
11,323 site-rated) compression horsepower, at QPC's existing Oak Spring Compressor Station. QPC's southern
transmission expansion project was completed and placed in service November 19, 2001.
6. None
7. None
8. Respondant did not make a general rate increase during 2001. A small adjustment was made for the merit
FERC FORM NO. 2 (12-96)Page 108
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Important Changes During the Year
budget based upon local and regional surveys. The amount of individual salary adjustment is controlled through
a merit matrix, which dictates progression through salary ranges. Employees are also paid an incentive based
upon meeting specific income goals and operating efficiencies.
9. Status of Materially Important Legal Proceedings.
(a) Docket No. RP02-96, By order issued December 18, 2001,the Commission approved QPC's November 30,
2001, fuel reimbursement filing changing its fuel reimbursement percentage from 0.8% to 1.6% effective
January 1, 2002.
(b) RP01-329, filed May 4, 2001, filed in compliance with the Commission's Order No. 587-M in Docket No.
RM96-1-015 that incorporate tariff revisions that incorporate the standards of the Gas Industry Standards Board.
This filing was approved by letter order dated November 14, 2001.
(c) KN TransColorado, Inc. v. Questar Corporation
Questar TransColorado, Inc. (QTC) and its partner, KN TransColorado, Inc., (KNTC) in the TransColorado Gas
Transmission Company (TransColorado) are involved in a complex lawsuit that is pending in a state district
court in Colorado. At the center of the lawsuit is the validity of a contractual right claimed by QTC to put its
50% interest in TransColorado to KNTC during the 12-month period beginning March 31, 2001. The current
value of the put is $118 million.
KNTC filed a lawsuit in June of 2000 alleging that Questar Pipeline and its affiliates breached their fiduciary
duties to TransColorado and KNTC by constructing and operating a pipeline (Questar Pipeline's Main Line 104)
that would compete with TransColorado, rendering TransColorado economically unviable. KNTC is seeking
damages in excess of $150 million plus punitive damages; a declaratory judgment that KNTC's obligation to
purchase QTC's interest in the project be declared void and unenforceable; and a dissolution of the partnership
under Colorado law. QTC and its affiliates subsequently filed a counterclaim and third-party complaint against
KNTC and named affiliates, including Kinder Morgan, Inc., seeking a declaratory judgement that its contractual
right to exercise the put is binding and enforceable, and damages
of at least $185 million.
The parties entered into a standstill agreement that preserves the claims made by Questar and KNTC
pending the resolution of the litigation. On December 31, 2000, QTC gave notice of its election to exercise its
contractual right to sell its 50% interest in TransColorado to KNTC.
The parties have engaged in extensive discovery proceedings and used a special master to review some issues
raised in discovery. The trial began April 1, 2002.
(d) Grynberg lawsuits
Questar affiliates are named defendants in a lawsuit filed by independent gas producer Jack J. Grynberg under
the Federal False Claims Act. This case and all substantially similar cases filed by Grynberg against other
pipelines and their affiliates have been consolidated for discovery and pre-trial rulings in Wyoming federal
district court. The cases involve allegations of industry wide mismeasurement and undervaluation of gas on
FERC FORM NO. 2 (12-96)Page 108.1
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Important Changes During the Year
which royalty payments are due the federal government. The complaint seeks treble damages and imposition of
civil penalties. The Wyoming district court judge denied the defendant's initial motion to dismiss. No motions
are currently pending.
Grynberg filed a case against Questar Pipeline, Questar Energy Trading and Questar Gas Management in Utah
state district court, alleging mismeasurement of gas volumes attributable to his working ownership interest in a
specified property in southwestern Wyoming. Grynberg alleged breach of contract, negligent misrepresentation,
fraud, breach of fiduciary duty, etc. On March 13, 2001, the trial judge granted defendants' motion to dismiss the
case, and Grynberg appealed that ruling to the Utah Supreme Court. Briefing of the case has been completed,
but no date for argument has been set.
(e) Will Price v. Gas Pipelines et al. (formerly Quinque Operating Co. v. Gas Pipelines)
Questar Pipeline and Questar's subsidiaries are named defendants in a purported nationwide class action
alleging mismeasurement of volumes and heating content of gas produced from private and state lands. The
plaintiffs are alleging a conspiracy among the defendants to set industry standards that undermeasure gas. The
defendants have filed motions to dismiss the pending actions for lack of personal jurisdiction and for failure to
state a claim. The producer's complaint does not include a request for any specific monetary damages.
(f) Other Legal Proceedings
There are various other legal proceedings against Questar Pipeline. While it is not currently possible to predict
or determine the outcomes of these proceedings, it is the opinion of management that the outcomes will not
have a material adverse effect on the Company's results of operations, financial position or liquidity.
10. None
11. None
FERC FORM NO. 2 (12-96)Page 108.2
Comparative Balance Sheet (Assets and Other Debits)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Balance at End
of Current Year
(in dollars)
(c)
Balance at End
of Previous Year
(in dollars)
(d)
UTILITY PLANT 0 0 1
Utility Plant (101-106, 114) 508,526,772 605,640,280200-201 2
Construction Work in Progress (107) 26,617,729 38,773,444200-201 3
TOTAL Utility Plant (Total of lines 2 and 3) 535,144,501 644,413,724200-201 4
(Less) Accum. Provision for Depr., Amort., Depl. (108, 111, 115) 241,243,342 253,789,202 5
Net Utility Plant (Total of line 4 less 5) 293,901,159 390,624,522 6
Nuclear Fuel (120.1 thru 120.4, and 120.6) 0 0 7
(Less) Accum. Provision for Amort., of Nuclear Fuel Assemblies (120.5) 0 0 8
Nuclear Fuel (Total of line 7 less 8) 0 0 9
Net Utility Plant (Total of lines 6 and 9) 293,901,159 390,624,522 10
Utility Plant Adjustments (116) 0 0122 11
Gas Stored-Base Gas (117.1) 100,207,370 102,214,506220 12
System Balancing Gas (117.2) 3,889,109 2,912,406220 13
Gas Stored in Reservoirs and Pipelines-Noncurrent (117.3) 0 0220 14
Gas Owned to System Gas (117.4) 0 0220 15
OTHER PROPERTY AND INVESTMENTS 0 0 16
Nonutility Property (121) 0 0 17
(Less) Accum. Provision for Depreciation and Amortization (122) 0 0 18
Investments in Associated Companies (123) 0 0222-223 19
Investments in Subsidiary Companies (123.1) 53,490,913 159,074,772224-225 20
(For Cost of Account 123.1 See Footnote Page 224, line 40) 0 0 21
Noncurrent Portion of Allowances 0 0 22
Other Investments (124) 0 0222-223 23
Special Funds (125 thru 128) 342,981 393,618 24
TOTAL Other Property and Investments (Total of lines 17-20, 22-24) 53,833,894 159,468,390 25
CURRENT AND ACCRUED ASSETS 0 0 26
Cash (131) 1,731,602 388,459 27
Special Deposits (132-134) 0 0 28
Working Funds (135) 0 0 29
Temporary Cash Investments (136) 0 0222-223 30
Notes Receivable (141) 0 0 31
Customer Accounts Receivable (142) 6,944,405 5,085,637 32
Other Accounts Receivable (143) 672,880 860,192 33
(Less) Accum. Provision for Uncollectible Accounts - Credit (144) 0 0 34
Notes Receivable from Associated Companies (145) 68,300,000 72,100,000 35
Accounts Receivable from Associated Companies (146) 1,733,334 1,566,194 36
Fuel Stock (151) 0 0 37
Fuel Stock Expenses Undistributed (152) 0 0 38
Residuals (Elec) and Extracted Products (Gas) (153) 0 0 39
Plant Materials and Operating Supplies (154) 2,289,892 2,640,532 40
Merchandise (155) 0 0 41
Other Materials and Supplies (156) 0 0 42
Nuclear Materials Held for Sale (157) 0 0 43
Page 110FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Balance at End
of Current Year
(in dollars)
(c)
Comparative Balance Sheet (Assets and Other Debits)(continued)
Balance at End
of Previous Year
(in dollars)
(d)
Allowances (158.1 and 158.2) 0 0 44
(Less) Noncurrent Portion of Allowances 0 0 45
Stores Expense Undistributed (163)( 13,628)( 312,651) 46
Gas Stored Underground-Current (164.1) 0 0220 47
Liquefied Natural Gas Stored and Held for Processing (164.2 thru 164.3) 0 0220 48
Prepayments (165) 458,099 617,224230 49
Advances for Gas (166 thru 167) 0 0 50
Interest and Dividends Receivable (171) 0 0 51
Rents Receivable (172) 0 0 52
Accrued Utility Revenues (173) 0 0 53
Miscellaneous Current and Accrued Assets (174) 1,992,414 961,980 54
TOTAL Current and Accrued Assets (Total of lines 27 thru 54) 84,108,998 83,907,567 55
DEFERRED DEBITS 0 0 56
Unamortized Debt Expense (181) 2,263,257 3,558,200 57
Extraordinary Property Losses (182.1) 0 0230 58
Unrecovered Plant and Regulatory Study Costs (182.2) 0 0230 59
Other Regulatory Assets (182.3) 6,117,233 6,002,074232 60
Preliminary Survey and Investigation Charges (Electric)(183) 0 0 61
Preliminary Survey and Investigation Charges (Gas)(183.1 and 183.2) 275,894 0 62
Clearing Accounts (184)( 642,914)( 448,971) 63
Temporary Facilities (185) 0 0 64
Miscellaneous Deferred Debits (186) 4,000,049 479,376233 65
Deferred Losses from Disposition of Utility Plant (187) 0 0 66
Research, Development, and Demonstration Expend. (188) 0 0 67
Unamortized Loss on Reacquired Debt (189) 4,079,457 8,828,443 68
Accumulated Deferred Income Taxes (190) 2,628,740 2,631,072234-235 69
Unrecovered Purchased Gas Costs (191) 0 0 70
TOTAL Deferred Debits (Total of lines 57 thru 70) 18,721,716 21,050,194 71
TOTAL Assets and Other Debits (Total of lines 10-15,25,55,and 71) 554,662,246 760,177,585 72
Page 111FERC FORM NO. 2 (12-96)
Comparative Balance Sheet (Liabilities and Other Credits)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Balance at End
of Current Year
(in dollars)
(c)
Balance at End
of Previous Year
(in dollars)
(d)
PROPRIETARY CAPITAL 0 0 1
Common Stock Issued (201) 6,550,843 6,550,843250-251 2
Preferred Stock Issued (204) 0 0250-251 3
Capital Stock Subscribed (202, 205) 0 0252 4
Stock Liability for Conversion (203, 206) 0 0252 5
Premium on Capital Stock (207) 124,910,906 124,910,906252 6
Other Paid-In Capital (208-211) 17,122,500 17,122,500253 7
Installments Received on Capital Stock (212) 0 0252 8
(Less) Discount on Capital Stock (213) 0 0254 9
(Less) Capital Stock Expense (214) 0 0254 10
Retained Earnings (215, 215.1, 216) 74,654,401 79,427,001118-119 11
Unappropriated Undistributed Subsidiary Earnings (216.1) 12,397,192 14,865,050118-119 12
(Less) Reacquired Capital Stock (217) 0 0250-251 13
TOTAL Proprietary Capital (Total of lines 2 thru 13) 235,635,842 242,876,300 14
LONG TERM DEBT 0 0 15
Bonds (221) 115,000,000 0256-257 16
(Less) Reacquired Bonds (222) 0 0256-257 17
Advances from Associated Companies (223) 0 0256-257 18
Other Long-Term Debt (224) 130,400,000 310,400,000256-257 19
Unamortized Premium on Long-Term Debt (225) 0 0258-259 20
(Less) Unamortized Discount on Long-Term Debt-Dr (226) 379,766 334,693258-259 21
(Less) Current Portion of Long-Term Debt 0 0 22
TOTAL Long-Term Debt (Total of lines 16 thru 22) 245,020,234 310,065,307 23
OTHER NONCURRENT LIABILITIES 0 0 24
Obligations Under Capital Leases-Noncurrent (227) 0 0 25
Accumulated Provision for Property Insurance (228.1) 0 0 26
Accumulated Provision for Injuries and Damages (228.2) 0 0 27
Accumulated Provision for Pensions and Benefits (228.3) 0 0 28
Accumulated Miscellaneous Operating Provisions (228.4) 0 0 29
Accumulated Provision for Rate Refunds (229) 0 0 30
TOTAL Other Noncurrent Liabilities (Total of lines 25 thru 30) 0 0 31
Page 112FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Balance at End
of Current Year
(in dollars)
(c)
Comparative Balance Sheet (Liabilities and Other Credits)(continued)
Balance at End
of Previous Year
(in dollars)
(d)
CURRENT AND ACCRUED LIABILITIES 0 0 32
Current Portion of Long-Term Debt 0 0 33
Notes Payable (231) 0 100,000,000 34
Accounts Payable (232) 3,177,689 7,790,159 35
Notes Payable to Associated Companies (233) 0 18,300,000 36
Accounts Payable to Associated Companies (234) 2,355,966 4,019,711 37
Customer Deposits (235) 0 0 38
Taxes Accrued (236) 1,969,414 3,412,917262-263 39
Interest Accrued (237) 1,625,129 2,380,000 40
Dividends Declared (238) 0 0 41
Matured Long-Term Debt (239) 0 0 42
Matured Interest (240) 0 0 43
Tax Collections Payable (241) 4,249 4,300 44
Miscellaneous Current and Accrued Liabilities (242) 153,413 159,644268 45
Obligations Under Capital Leases-Current (243) 0 0 46
TOTAL Current and Accrued Liabilities (Total of lines 33 thru 46) 9,285,860 136,066,731 47
DEFERRED CREDITS 0 0 48
Customer Advances for Construction (252) 0 0 49
Accumulated Deferred Investment Tax Credits (255) 11,799 5,863 50
Deferred Gains from Disposition of Utility Plant (256) 0 0 51
Other Deferred Credits (253) 6,214,373 4,149,509269 52
Other Regulatory Liabilities (254) 1,286,746 2,262,540278 53
Unamortized Gain on Reacquired Debt (257) 0 0260 54
Accumulated Deferred Income Taxes (281-283) 57,207,392 64,751,335 55
TOTAL Deferred Credits (Total of lines 49 thru 55) 64,720,310 71,169,247 56
TOTAL Liabilities and Other Credits (Total of lines 14,23,31,47,and 56) 554,662,246 760,177,585 57
Page 113FERC FORM NO. 2 (12-96)
Statement of Income for the Year
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Total
Current Year
(in dollars)
(c)
Total
Previous Year
(in dollars)
(d)
1. Report amounts for accounts 412 and 413, Revenue and Expenses from Utility Plant Leased to Others, in another utility column
(i,j) in a similar manner to a utility department. Spread the amount(s) over lines 2 thru 24 as appropriate. Include these amounts in
columns (c) and (d) totals.
2. Report amounts in discount 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above.
3. Report data for lines 7, 9, and 10 for Natural Gas companies using accounts 404.1, 404.2, 404.3, 407.1, and 407.2.
UTILITY OPERATING INCOME 0 0 1
Gas Operating Revenues (400) 113,577,439 118,306,800300-301 2
Operating Expenses 0 0 3
Operation Expenses (401) 36,885,551 39,219,643317-325 4
Maintenance Expenses (402) 5,319,874 5,781,828317-325 5
Depreciation Expense (403) 14,340,742 14,835,444336-338 6
Amortization and Depletion of Utility Plant (404-405) 477,788( 630,975)336-338 7
Amortization of Utility Plant Acu. Adjustment (406) 0 0336-338 8
Amort. of Prop. Losses, Unrecovered Plant and Reg. Study Costs (407.1) 0 0 9
Amortization of Conversion Expenses (407.2) 0 0 10
Regulatory Debits (407.3) 0 0 11
(Less) Regulatory Credits (407.4) 0 0 12
Taxes Other than Income Taxes (408.1) 2,619,928 2,846,595262-263 13
Income Taxes-Federal (409.1) 9,384,459 9,016,230262-263 14
Income Taxes-Other (409.1) 305,700 706,359262-263 15
Provision of Deferred Income Taxes (410.1) 2,451,893 4,349,248234-235 16
(Less) Provision for Deferred Income Taxes-Credit (411.1) 0 0234-235 17
Investment Tax Credit Adjustment-Net (411.4) 0 0 18
(Less) Gains from Disposition of Utility Plant (411.6) 0 0 19
Losses from Disposition of Utility Plant (411.7) 0 0 20
(Less) Gains from Disposition of Allowances (411.8) 0 0 21
Losses from Disposition of Allowances (411.9) 0 0 22
TOTAL Utility Operating Expenses (Total of lines 4 thru 22) 71,785,935 76,124,372 23
Net Utility Operating Income (Total of lines 2 less 23) (Carry forward to page 116, line 25) 41,791,504 42,182,428 24
Page 114FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Total
Current Year
(in dollars)
(c)
Statement of Income for the Year(continued)
Total
Previous Year
(in dollars)
(d)
Net Utility Operating Income (Carried forward from page 114) 41,791,504 42,182,428 25
OTHER INCOME AND DEDUCTIONS 0 0 26
Other Income 0 0 27
Nonutility Operating Income 0 0 28
Revenues form Merchandising, Jobbing and Contract Work (415) 0 0 29
(Less) Costs and Expense of Merchandising, Job & Contract Work (416) 0 0 30
Revenues from Nonutility Operations (417) 0 0 31
(Less) Expenses of Nonutility Operations (417.1) 0 0 32
Nonoperating Rental Income 0 0 33
Equity in Earnings of Subsidiary Companies (418.1) 3,907,649 2,467,858119 34
Interest and Dividend Income (419) 3,260,691 3,604,074 35
Allowance for Other Funds Used During Construction (419.1) 415,381 1,717,216 36
Miscellaneous Nonoperating Income (421) 431,272 190,835 37
Gain on Disposition of Property (421.1) 214,455 329,675 38
TOTAL Other Income (Total of lines 29 thru 38) 8,229,448 8,309,658 39
Other Income Deductions 0 0 40
Loss on Disposition of Property (421.2) 8,976 13,348 41
Miscellaneous Amortization (425) 0 0 42
Miscellaneous Income Deductions (426.1 thru 426.5) 228,061 127,639340 43
TOTAL Other Income Deductions (Total of lines 41 thru 43) 237,037 140,987340 44
Taxes Applic. to Other Income and Deductions 0 0 45
Taxes Other than Income Taxes (408.2) 0 0262-263 46
Income Taxes-Federal (409.2)( 4,522,573)( 1,634,466)262-263 47
Income Taxes-Other (409.2) 232,829( 210,194)262-263 48
Provision for Deferred Income Taxes (410.2) 4,336,924 3,228,810234-235 49
(Less) Provision for Deferred Income Taxes-Credit (411.2) 0 0234-235 50
Investment Tax Credit Adjustments-Net (411.5) 0 0 51
(Less) Investment Tax Credits (420) 5,915 5,937 52
TOTAL Taxes on Other Income and Deductions (Total of lines 46-52) 41,265 1,378,213 53
Net Other Income and Deductions (Total of lines 39, 44, 53) 7,951,146 6,790,458 54
INTEREST CHARGES 0 0 55
Interest on Long-Term Debt (427) 19,505,466 18,716,381 56
Amortization of Debt Disc. and Expense (428) 192,402 241,360258-259 57
Amortization of Loss on Reacquired Debt (428.1) 318,882 485,514 58
(Less) Amortization of Premium on Debt-Credit (429) 0 0258-259 59
(Less) Amortization of Gain on Reacquired Debt-Credit (429.1) 0 0 60
Interest on Debt to Associated Companies (430) 259,726 290,805340 61
Other Interest Expense (431) 82,328 838,462340 62
(Less) Allowance for Borrowed Funds Used During Construction-Credit (432) 441,071 1,340,095 63
Net Interest Charges (Total of lines 56 thru 63) 19,917,733 19,232,427 64
Income Before Extraordinary Items (Total of lines 25,54 and 64) 29,824,917 29,740,459 65
EXTRAORDINARY ITEMS 0 0 66
Extraordinary Income (434) 0 0 67
(Less) Extraordinary Deductions (435) 0 0 68
Net Extraordinary Items (Total of line 67 less line 68) 0 0 69
Income Taxes-Federal and Other (409.3) 0 0262-263 70
Extraordinary Items after Taxes (Total of line 69 less line 70) 0 0 71
Net Income (Total of lines 65 and 71) 29,824,917 29,740,459 72
Page 116FERC FORM NO. 2 (12-96)
Statement of Income for the Year
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Other Utility
Current Year
(in dollars)
(i)
Other Utility
Previous Year
(in dollars)
(j)
4. Explain in a footnote if the previous year's figures are different from those reported in prior reports.
5. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles, lines 2 to 23, and
report the information in the blank space on page 122 or in a supplemental statement.
Elec. Utility
Current Year
(in dollars)
(e)
Elec. Utility
Previous Year
(in dollars)
(f)
Gas Utility
Current Year
(in dollars)
(g)
Gas Utility
Previous Year
(in dollars)
(h)
0 0 0 0 0 0 1
0 60 113,577,379 118,306,800 0 0 2
0 0 0 0 0 0 3
0 0 36,885,551 39,219,643 0 0 4
0 0 5,319,874 5,781,828 0 0 5
0 0 14,340,742 14,835,444 0 0 6
0 0 477,788( 630,975) 0 0 7
0 0 0 0 0 0 8
0 0 0 0 0 0 9
0 0 0 0 0 0 10
0 0 0 0 0 0 11
0 0 0 0 0 0 12
0 0 2,619,928 2,846,595 0 0 13
0 0 9,384,459 9,016,230 0 0 14
0 0 305,700 706,359 0 0 15
0 0 2,451,893 4,349,248 0 0 16
0 0 0 0 0 0 17
0 0 0 0 0 0 18
0 0 0 0 0 0 19
0 0 0 0 0 0 20
0 0 0 0 0 0 21
0 0 0 0 0 0 22
0 0 71,785,935 76,124,372 0 0 23
0 60 41,791,444 42,182,428 0 0 24
Page 115FERC FORM NO. 2 (12-96)
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.
Statement of Retained Earnings for the Year
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Item
(a)
Contra Primary
Account Affected
(b)
Current Year
Amount
(in dollars)
(c)
Previous Year
Amount
(in dollars)
(d)
UNAPPROPIATED RETAINED EARNINGS
Balance--Beginning of Year 70,237,133 74,654,401 1
Changes 2
Adjustments to Retained Earnings (Account 439) 3
Credit: 3.01
Credit: 3.02
Credit: 3.03
Credit: 3.04
Credit: 3.05
Credit: 3.06
Credit: 3.07
Credit: 3.08
Credit: 3.09
Credit: 3.10
TOTAL Credits to Retained Earnings (Account 439) (Total of lines 3.01 to 3.?) 4
Debit: 4.01
Debit: 4.02
Debit: 4.03
Debit: 4.04
Debit: 4.05
Debit: 4.06
Debit: 4.07
Debit: 4.08
Debit: 4.09
Debit: 4.10
TOTAL Debits to Retained Earnings (Account 439) (Total of lines 4.01 to 4.?) 5
Balance Transferred from Income (Acct 433 less Acct 418.1) 25,917,268 27,272,600 6
Appropiations of Retained Earnings (Account 436) 7
7.01
7.02
7.03
7.04
7.05
7.06
7.07
7.08
7.09
7.10
TOTAL Appropriations of Retained Earnings (Account 436) (Total of lines 7.01 to 8
Dividends Declared-Preferred Stock (Account 437) 9
9.01
9.02
9.02
9.03
9.04
9.05
9.06
9.07
9.08
Page 118-119FERC FORM NO. 2 (12-96)
6. Show separately the State and Federal income tax effect of items shown in Account 439, Adjustments to Retained Earnings.
7. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent; state the number and annual amounts to
be reserved or appropriated as well as the totals eventually to be accumulated.
8. At lines 3, 4, 7, 9, 11, and 15, add rows as necessary to report all data. When rows are added, the additional row numbers should follow in sequence, e.g., 3.01, 3.02, etc.
Statement of Retained Earnings for the Year (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Item
(a)
Current Year
Amount
(in dollars)
(c)
Previous Year
Amount
(in dollars)
(d)
9.09
9.10
TOTAL Dividends Declared-Preferred Stock (Account 437) (Total of lines 9.01 to 9 10
Dividends Declared-Common Stock (Account 438) 11
First Quarter ( 5,375,000)( 5,625,000) 11.01
Second Quarter ( 5,375,000)( 5,625,000) 11.02
Third Quarter ( 5,375,000)( 5,625,000) 11.03
Fourth Quarter ( 5,375,000)( 5,625,000) 11.04
11.05
11.06
11.07
11.08
11.09
11.10
TOTAL Dividends Declared-Common Stock (Account 438) (Total of lines 11.01 to 11.( 21,500,000)( 22,500,000) 12
Transfers from Account 216.1, Unappropriated Undistributed Subsidiary Earnings 13
Balance-End of Year (Total of lines 1, 4, 5, 6, 8, 10, 12 and 13) 74,654,401 79,427,001 14
APPROPRIATED RETAINED EARNINGS (Account 215)
15.01
15.02
15.03
15.04
15.05
15.06
15.07
15.08
15.09
15.10
TOTAL Appropriated Retained Earnings (Account 215) 16
APPROPRIATED RETAINED EARNINGS-AMORTIZATION RESERVE, FEDERAL (AccountAPPROPRIATED RETAINED EARNINGS-AMORTIZATION RESERVE, FEDERAL (Account 215.1)
TOTAL Appropriated Retained Earnings-Amortization Reserve, Federal (Account 215. 17
TOTAL Appropriated Retained Earnings (Account 215, 215.1) (Total of lines 16 and 18
TOTAL Retained Earnings (Account 215, 215.1, 216) (Total of lines 14 and 18) 74,654,401 79,427,001 19
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account 216.1)
Balance-Beginning of Year (Debit or Credit) 8,489,543 12,397,192 20
Equity in Earnings for Year (Credit) (Account 418.1) 3,907,649 2,467,858 21
(Less) Dividends Received (Debit) 22
Other Changes (Explain) 23
Balance-End of Year 12,397,192 14,865,050 24
Page 118-119aFERC FORM NO. 2 (12-96)
Statement of Cash Flows
1. Information about noncash investing and financing activities should be provided on page 122. Provide also on page 122 a reconciliation between
"Cash and Cash Equivalents at End of Year" with related amounts on the balance sheet.
2. Under "Other" specify significant amounts and group others.
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 on page 122 the amounts of interest paid (net of amounts capitalized) and income taxes paid.
4. Investing Activities: Include at Other (Line 27) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with labilities
assumed on page 122. Do not include on this statement the dollar amount of leases capitalized per U.S. of A. General Instruction 20; instead provide a
reconciliation of the dollar amount of leases capitalized with the plant cost on page 122.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description (See Instrctions for explanation of codes)
(a)
Current Year
Amount
(b)
Previous Year
Amount
(c)
1 Net Cash Flow from Operating Activities
2 29,824,917 29,740,458Net Income (Line 72(c) on page 116)
3 Noncash Charges (Credits) to Income:
4 15,465,631 16,033,624Depreciation and Depletion
5 477,788( 630,975)Amortization of (Specify)
5.01 Extraordinary Item - Asset Write Down
5.02
5.03
5.04
5.05
5.06
5.07
5.08
5.09
5.10
5.11
5.12
5.13
5.14
5.15
6 6,775,636 7,541,611Deferred Income Taxes (Net)
7 ( 5,915)( 5,936)Investment Tax Credit Adjustments (Net)
8 ( 13,992,162)( 1,961,404)Net (Increase) Decrease in Receivables
9 166,470( 51,617)Net (Increase) Decrease in Inventory
10 Net (Increase) Decrease in Allowances Inventory
11 ( 4,111,755) 8,480,871Net Increase (Decrease) in Payables and Accrued Expenses
12 ( 843,263) 115,159Net (Increase) Decrease in Other Regulatory Assets
13 187,747 975,794Net Increase (Decrease) in Other Regulatory Liabilities
14 415,381 1,717,216(Less) Allowance for Other Funds Used During Construction
15 3,907,649 2,467,858(Less) Undistributed Earnings from Subsidiary Companies
16 Other:
16.01
16.02 1,938,460( 4,134,748)Gain and Losses From Operating Activities
16.03
16.04
16.05
16.06
16.07
16.08
16.09
16.10
16.11
16.12
Page 120FERC FORM NO. 2 (12-96)
Statement of Cash Flows (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description (See Instrctions for explanation of codes)
(a)
Current Year
Amount
(b)
Previous Year
Amount
(c)
16.13
16.14
16.15
17 Net Cash Provided by (Used in) Operating Activities
18 31,560,524 51,917,763(Total of Lines 2 thru 16.?)
19
20 Cash Flows from Investment Activities:
21 Construction and Acquisition of Plant (including land):
22 ( 19,785,941)( 113,079,535)Gross Additions to Utility Plant (less nuclear fuel)
23 Gross Additions to Nuclear Fuel
24 Gross Additions to Common Utility Plant
25 Gross Additions to Nonutility Plant
26 ( 415,381)( 1,717,216)(Less) Allowance for Other Funds Used During Construction
27 Other:
27.01
27.02
27.03
27.04
27.05
28 ( 19,370,560)( 111,362,319)Cash Outflows for Plant (Total of lines 22 thru 27.?)
29
30 Acquisition of Other Noncurrent Assets (d)
31 2,076,036 417,414Proceeds from Disposal of Noncurrent Assets (d)
32
33 ( 24,744,078)( 103,116,001)Investments in and Advances to Assoc. and Subsidiary Companies
34 Contributions and Advances from Assoc. and Subsidiary Companies
35 Disposition of Investments in (and Advances to)
36 Associated and Subsidiary Companies
37
38 Purchase of Investment Securities (a)
39 Proceeds from Sales of Investment Securities (a)
Page 120aFERC FORM NO. 2 (12-96)
Statement of Cash Flows (continued)
5. Codes used:
(a) Net Proceeds or payments.
(b) Bonds, Debentures, and other long-term debt.
(c) Include commercial paper.
(d) Identify separate such items as investments fixed assets, intangibles, etc.
6. Enter on page 122 clarifications and explanations.
7. At lines 5, 16, 27, 47, 56, 58, and 65, add rows as necessary to report all data. Number the extra rows in sequence, 5.01, 5.02, etc.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description (See Instrctions for explanation of codes)
(a)
Current Year
Amount
(b)
Previous Year
Amount
(c)
40 Loans Made or Purchased
41 Collections on Loans
42
43 Net (Increase) Decrease in Receivables
44 Net (Increase) Decrease in Inventory
45 Net (Increase) Decrease in Allowance Held for Speculation
46 Net Increase (Decrease) in Payables and Accrued Expenses
47 Other:
47.01
47.02
47.03
47.04
47.05
47.06
47.08
47.09
47.10
48 Net Cash Provided by (Used in) Investing Activities
49 ( 42,038,602)( 214,060,906)(Total of lines 28 thru 47.?)
50
51 Cash Flows from Financing Activities:
52 Proceeds from Issuance of:
53 165,000,000Long-Term Debt (b)
54 Preferred Stock
55 Common Stock
56 60,000,000Other: Paid in Capital Common Stock
56.01
56.02
56.03
56.04
56.05
57 ( 29,200,000) 18,300,000Net Increase in Short-Term Debt (c)
58 Other:
58.01
58.02
58.03
58.04
58.05
58.06
58.07
58.08
58.09
58.10
Page 121FERC FORM NO. 2 (12-96)
Statement of Cash Flows (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description (See Instrctions for explanation of codes)
(a)
Current Year
Amount
(b)
Previous Year
Amount
(c)
59 30,800,000 183,300,000Cash Provided by Outside Sources (Total of lines 53 thru 58.?)
60
61 Payments for Retirement of:
62 Long-Term Debt (b)
63 Preferred Stock
64 Common Stock
65 Other:
65.01
65.02
65.03
65.04
65.05
66 Net Decrease in Short-Term Debt (c)
67
68 Dividends on Preferred Stock
69 ( 21,500,000)( 22,500,000)Dividends on Common Stock
70 Net Cash Provided by (Used in) Financing Activities
71 9,300,000 160,800,000(Total of lines 59 thru 69)
72
73 Net Increase (Decrease) in Cash and Cash Equivalents
74 ( 1,178,078)( 1,343,143)(Total of Line 18, 49 and 71)
75
76 2,909,680 1,731,602Cash and Cash Equivalents at Beginning of Year
77
78 1,731,602 388,459Cash and Cash Equivalents at End of Year
Page 121aFERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
Schedule Page: 120 Line No.: 5 Column: b
Amortization of intangible assets.
FERC FORM NO. 2 (12-96)Page 552
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
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.
4. 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.
5. Explain concisely any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
6. 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.
7. 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.
8. 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.
9. 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.
QUESTAR PIPELINE COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 - Summary of Accounting Policies
Investment in Subsidiary Companies: Questar Pipeline uses the equity method to account for
investments in affiliates in which it does not have control. The principal affiliates are: Overthrust Pipeline
Company and TransColorado Gas Transmission Company. Questar Pipeline is the operator of the
Overthrust Segment of the Trailblazer Pipeline System. Approval of all partners is required for all
substantive policy matters. Questar Pipeline has two totally owned subsidiaries, Questar Transportation
Services and Questar Southern Trails Company Generally, the Company's investment in these affiliates
equals the underlying equity in net assets, except for TransColorado where the investment was written
down in 1999. The Company experienced an other-than-temporary decline in its partnership investment
caused by low volumes resulting from unfavorable regional transportation economics.
Regulation: Questar Pipeline is regulated by the Federal Energy Regulatory Commission (FERC)
which establishes rates for the transportation and storage of natural gas. The FERC also regulates, among
other things, the extension and enlargement or abandonment of jurisdictional natural gas facilities.
Regulation is intended to permit the recovery, through rates, of the cost of service including a return on
investment. The financial statements are presented in accordance with regulatory requirements. Methods
of allocating costs to time periods, in order to match revenues and expenses, may differ from those of
nonregulated businesses because of cost allocation methods used in establishing rates.
Other Regulatory Assets and Liabilities: Gains and losses on the reacquisition of debt by rate-regulated
affiliates are deferred and amortized as debt expense over the would-be remaining life of the retired debt or
the life of the replacement debt in order to match regulatory treatment. The cost of the early retirement
windows offered to employees of rate-regulated subsidiaries is capitalized and amortized over a five-year
FERC FORM NO. 2 (12-96)Page 122
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Notes to Financial Statements
period . The Company has adopted procedures with the FERC to include under-and over-provided deferred
taxes in customer rates on a systematic basis. Questar Pipeline uses the deferral method to account for
investment tax credits as required by the FERC.
Use of Estimates: The preparation of financial statements in conformity with accounting principles
generally accepted in the United States requires management to make estimates and assumptions that affect
the amounts of assets and liabilities and disclosure of contingent liabilities reported in the financial
statements and accompanying notes. Actual results could differ from those estimates.
Revenue Recognition: Revenues are recognized in the period that services are provided or products are
delivered. Questar Pipeline periodically collects revenues subject to possible refunds pending final orders
from the FERC. The Company establishes reserves for revenues collected subject to refund.
Cash and Cash Equivalents: Cash equivalents consist principally of repurchase agreements with
maturities of three months or less. In almost all cases, the repurchase agreements are highly liquid
investments in overnight securities made through commercial bank accounts that result in available funds
the next business day.
Notes Receivable from Questar: Notes receivable from Questar represent interest bearing demand notes
for cash loaned to Questar until needed in the Company's operations. The funds are centrally managed
by Questar and earn an interest rate that is identical to the interest rate paid by the Company for
borrowings from Questar.
Property, Plant and Equipment: Property, plant and equipment is stated at cost. The provision for
depreciation is based upon rates, which will systematically charge the costs of assets over their estimated
useful lives. The costs of property, plant and equipment are depreciated in the financial statements using
the straight-line method, ranging from 3% to 33% per year and averaging 2.9% and 3.2% in 2001 and 2000
2000 respectively.
Allowance for Funds Used During Construction: The Company capitalizes the cost of capital during the
construction period of plant and equipment in accordance with FERC guidelines. Capitalized financing
costs, called allowance for funds used during construction (AFUDC), consist of debt and equity portions.
The debt portion of AFUDC is recorded as a reduction of interest expense and the equity portion is
recorded in other income. Debt expense was reduced by $1.3 million in 2001and $.4 million in 2000.
AFUDC included in interest and other income amounted to $1.7 million in 2001 and $.4 million in 2000.
Income Taxes: The Company accounts for income tax expense on a separate return basis. Pursuant to
the Internal Revenue Code and associated regulations, the Company 's operations are consolidated with
those of Questar and its subsidiaries for income tax reporting purposes. The Company records tax benefits
as they are generated. The Company receives payments from Questar for such tax benefits as they are
utilized on the consolidated return.
New Accounting Standards: On January 1, 2001, the Company adopted the accounting provisions
of Statement of Financial Accounting Standards 133, as amended, "Accounting for Derivative
Instruments and Hedging Activities" (SFAS 133). SFAS 133 addresses the accounting for derivative
instruments, including certain derivative instruments embedded in other contracts. Under the standard,
entities are required to carry all derivative instruments in the balance sheet at fair value. The accounting for
changes in fair value, which result in gains or losses, of a derivative instrument would either be reported in
income or comprehensive income. The Company has not entered into any commodity or interest-based
derivative instruments. There is no financial impact on the Company since adopting this accounting
standard.
In June 2001, the Financial Accounting Standards Board (“FASB”) issued SFAS 141, Business
FERC FORM NO. 2 (12-96)Page 122.1
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Notes to Financial Statements
Combinations,” which addresses financial accounting and reporting for business combinations.
SFAS 141 is effective for all business combinations initiated after June 30, 2001 and for all business
combinations accounted for under the pooling method initiated before but completed after June 30, 2001.
The Company has not entered into any business combinations transactions since adopting this
accounting standard.
In June 2001, the FASB issued SFAS 142, “Goodwill and Other Intangible Assets,” which addresses, among
other things, the financial accounting and reporting for goodwill subsequent to an acquisition. The new
standard eliminates the requirement to amortize acquired goodwill; instead, such goodwill shall be reviewed
at least yearly for impairment or sooner if a specific trigger occurs. Goodwill acquired after July 1, 2001, is
exempt from amortization. At December 31, 2001, the Company did not have any goodwill or other intangible
assets that qualify for the accounting treatment under SFAS 142.
In June 2001, the FASB issued SFAS 143, “Accounting for Asset Retirement Obligations,” which
addresses, among other things, the financial accounting and reporting of the fair value of legal obligations
associated with the retirement of tangible long-lived assets. The new standard requires that retirement costs
be estimated at fair value, capitalized and depreciated over the life of the assets. The new standard may
affect the cost basis of rate-regulated assets. SFAS 143 is effective for 2003. The Company has not
evaluated the impact of SFAS 143.
In August 2001, the FASB issued SFAS 144, "Accounting for the Impairment or Disposal of Long-Lived
Assets." The new standard addresses financial accounting and reporting for the impairment or disposal of
long-lived assets, specifically, for a segment of a business accounted for as a discontinued operation, and
modifies the provisions of SFAS 121. SFAS 144 is effective for 2002. The Company has not evaluated the
impact of SFAS 144.
Reclassifications: Certain reclassifications were made to the 2000 financial statements to conform with
the 2001 presentation.
Note 2 - Investment in Unconsolidated Affiliates
Questar Pipeline, through its subsidiaries, has interests in partnerships accounted for on the equity basis.
Transportation of natural gas is the primary business activity of these partnerships. As of December 31,
2001, these affiliates did not have debt obligations with third-party lenders. The principal partnerships and
percentage ownership were as follows: Overthrust Pipeline Co. (72%) and TransColorado Gas Transmission
Co. (50%). Questar Pipeline acquired an additional 18% of Overthrust Pipeline in January 2002 bringing its
ownership percentage to 90%.
Summarized information of the partnerships follows:
2001 2000
(In Thousands)
Year Ended December 31,
Revenues $24,714 $19,207
Operating loss (1,973)(5,459)
Loss before income taxes (7,966)(16,570)
At December 31,
Current assets $15,446 $7,615
Noncurrent assets 431,449 406,611
FERC FORM NO. 2 (12-96)Page 122.2
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Notes to Financial Statements
Current liabilities 87,249 259,678
Noncurrent liabilities 25,731 17,735
Debt included in current liabilities 200,000
Note 3 - Debt
Questar makes loans to Questar Pipeline under a short-term borrowing arrangement. Outstanding
short-term notes payable to Questar totaled $18.3 million with an interest rate of 2.31% at December 31,
2001 and no amounts were borrowed as of December 31, 2000.
Questar Pipeline also invests excess cash balances with Questar. The funds are centrally managed by
Questar and earn an interest rate that is identical to the interest rate paid by the subsidiaries borrowing
from Questar. Notes receivable from Questar as of December 31, 2000, amounted to $20.7 million with an
interest rate of 6.91%, and no amounts loaned as of December 31, 2001.
On October 12, 2001, Questar Pipeline borrowed $100 million of short-term debt with a variable rate of
interest. The weighted average interest rate at December 31, 2001 was 2.831%. The proceeds were used to
repay through a wholly-owned subsidiary, Questar TransColorado, Inc. (QTC), debt owed by
TransColorado Gas Transmission Company (TransColorado).
The details of long-term debt at December 31 are as follows:
2001 2000
(In Thousands)
Medium-term notes 5.85% to 7.55%,
due 2008 to 2018 $310,400 $130,400
9 3/8% debentures due 2021 85,000
9 7/8% debentures due 2020 30,000
Total long-term debt outstanding 310,400 245,400
Less unamortized debt discount 335 380
$310,065 $245,020
On May 11, 2001, Questar Pipeline filed a Form S-3 with the Securities and Exchange Commission to issue
up to $250 million of medium-term notes, Series B, with maturities of nine months to 30 years. On May 29,
2001, Questar Pipeline issued $100 million of ten-year notes with a 7.09% coupon rate. On September 26,
2001, Questar Pipeline issued $80 million of ten-year medium-term notes with a coupon rate of 6.57%.
On March 30, 2001, Questar Pipeline redeemed the remaining $30 million of its 9 7/8% debentures. The
redemption price was equal to 104.67% of the principal amount plus interest from December 1, 2000. In
addition, Questar Pipeline redeemed all $85 million of its 9 3/8% debentures on June 25, 2001. The
redemption price was equal to 104.51% of the principal amount plus interest for twenty-four days.
Cash paid for interest was $19.1 million in 2001 and $20.4 million in 2000.
Note 4 - Financial Instruments and Risk Management
The carrying amounts and estimated fair values of the Company's financial instruments at December 31
were as follows:
2001 2000
Carrying Estimated Carrying Estimated
FERC FORM NO. 2 (12-96)Page 122.3
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Notes to Financial Statements
Amount Fair Value Amount Fair Value
(In Thousands)
Financial assets
Cash and cash equivalents $388 $388 $1,732 $1,732
Financial liabilities
Notes Payable to Questar $18,300 $18,300
Short-term loans 100,000 100,000
Long-term debt 310,065 309,272 245,020 250,099
The Company used the following methods and assumptions in estimating fair values: (1)
Cash and cash
equivalents and short-term loans - the carrying amount approximates fair value; (2) Long-term debt - the fair
value of long-term debt is based on discounted present value of cash flows using the Company's current
borrowing rates. Fair value is calculated at a point in time and does not represent the amount the Company
would pay to retire the debt securities.
Credit Risk: Questar Pipeline's primary market is the Rocky Mountain region in the United States, and
will include the southwestern region once Questar Pipline's subsidiary, Questar Southern Trails, puts its
pipeline into service. The Company's exposure to credit risk may be impacted by the concentration of
customers in these regions due to changes in economic or other conditions. The Company's customers
may be affected differently by changing conditions. Management believes that its credit-review
procedures, loss reserves and collection procedures have adequately provided for usual and customary
credit-related losses.
Note 5 - Income Taxes
The components of income taxes for years ended December 31 were as follows:
2001 2000
(In Thousands)
Federal
Current $7,382 $4,861
Deferred 6,921 9,616
State
Current 496 539
Deferred 651 (2,833)
$15,450 $12,183
The difference between the statutory federal income tax rate and the Company's effective income tax rate is
explained as follows:
2001 2000
(In Percentages)
Federal income taxes at 35%35.0 35.0
Increase (decrease) as a result of:
State income taxes, net of federal income tax 1.8 (3.8)
Prior years' tax settlement
Other 0.3 (0.2)
Effective income tax rate 37.1 31.0
FERC FORM NO. 2 (12-96)Page 122.4
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Notes to Financial Statements
Significant components of the Company's deferred income taxes at December 31 were as follows:
2001 2000
(In Thousands)
Deferred tax liabilities
Property, plant and equipment $72,024 $50,152
Other 6,406 22,144
Total deferred tax liabilities 78,430 72,296
Deferred tax assets
Write-down of investment
in partnership 10,306 11,806
Other 5,998 5,899
Total deferred tax assets 16,304 17,705
Net deferred income taxes $62,126 $54,591
A Colorado state income tax credit derived from conducting business in a designated enterprise zone
reduced state income taxes by $3.2 million in 2000. The tax credit has a 3-year carryback and a 12-year
carryforward provision. As of December 31, 2001, the balance of the tax credit carryforward was $2.4 million.
Cash paid for income taxes was $6.4 million in 2001 and $7.5 million in 2000.
Note 6 - Rate Matters and Other
Federal rate regulation
On September 27, 2001, the Federal Energy Regulatory Commission (FERC) issued a Notice of Proposed
Rule making on Standards of Conduct for Transmission Providers (NOPR) that would significantly broaden
the scope of the FERC's affiliate regulations for pipelines. The NOPR would require all transmission
providers to comply with standards of conduct dealing with affiliated energy companies. Those standards
include the separation of functions and non-discriminatory treatment of transmission customers. The
NOPR would essentially diminish operational efficiencies and increase costs by mandating a complete
separation of operations. Questar Regulated Services supplies administrative, technical, accounting, legal
and regulatory support for both Questar Pipeline and Questar Gas.
Questar Gas, Questar Pipeline, industry associations and other companies have filed written and verbal
comments with the FERC about the problems this NOPR would create for the industry and its customers
and asked the FERC to reconsider its proposal.
CPUC Decision and Southern Trails
A ruling from the California Public Utilities Commission (CPUC) on Residential Load Service tariff has
adverse effects on new pipelines attempting to enter the California market. Under the CPUC's proposed new
peaking rate, new gas fired power plants wanting natural gas service from both Southern California Gas
Company (SoCal) and the Southern Trails Pipeline will pay a higher rate for SoCal's service than customers
taking service entirely from SoCal. In addition, new power plants would be subject to more restrictive
balancing services than captive customers and would pay even more for interruptible service than California
power plants in other parts of the state. While the Company continues to actively pursue natural gas
markets on the California portion of its Southern Trails Pipeline, the Company is considering alternative
uses as well.
Note 7 - Litigation and Commitments
FERC FORM NO. 2 (12-96)Page 122.5
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Notes to Financial Statements
KN TransColorado, Inc. v. Questar Corporation
Questar TransColorado, Inc. (QTC) and its partner, KN TransColorado, Inc., (KNTC) in the TransColorado
Gas Transmission Company (TransColorado) are involved in a complex lawsuit that is pending in a state
district court in Colorado. At the center of the lawsuit is the validity of a contractual right claimed by QTC
to put its 50% interest in TransColorado to KNTC during the 12-month period beginning March 31, 2001.
The current value of the put is $118 million.
KNTC filed a lawsuit in June of 2000 alleging that Questar Pipeline and its affiliates breached their fiduciary
duties to TransColorado and KNTC by constructing and operating a pipeline (Questar Pipeline's Main Line
104) that would compete with TransColorado, rendering TransColorado economically unviable. KNTC is
seeking damages in excess of $150 million plus punitive damages; a declaratory judgment that KNTC's
obligation to purchase QTC's interest in the project be declared void and unenforceable; and a dissolution
of the partnership under Colorado law. QTC and its affiliates subsequently filed a counterclaim and
third-party complaint against KNTC and named affiliates, including Kinder Morgan, Inc., seeking a
declaratory judgement that its contractual right to exercise the put is binding and enforceable, and damages
of at least $185 million.
The parties entered into a standstill agreement that preserves the claims made by Questar and KNTC
pending the resolution of the litigation. On December 31, 2000, QTC gave notice of its election to exercise
its contractual right to sell its 50% interest in TransColorado to KNTC.
The parties have engaged in extensive discovery proceedings and used a special master to review some
issues raised in discovery. The trial is scheduled to begin April 1, 2002.
Grynberg lawsuits
Questar affiliates are named defendants in a lawsuit filed by independent gas producer Jack J. Grynberg
under the Federal False Claims Act. This case and all substantially similar cases filed by Grynberg against
pipelines and their affiliates have been consolidated for discovery and pre-trial rulings in Wyoming federal
district court. The cases involve allegations of industry wide mismeasurement and undervaluation of gas on
which royalty payments are due the federal government. The complaint seeks treble damages and
imposition of civil penalties. The Wyoming district court judge denied the defendant's initial motion to
dismiss. No motions are currently pending.
Grynberg has filed a case against Questar Pipeline, Questar Energy Trading and Questar Gas Management
in Utah state district court, alleging mismeasurement of gas volumes attributable to his working ownership
interest in a specified property in southwestern Wyoming. Grynberg alleges breach of contract, negligent
misrepresentation, fraud, breach of fiduciary duty, etc. On March 13, 2001, the trial judge granted
defendants' motion to dismiss a case by Grynberg and Grynberg appealed that ruling to the Utah State
Supreme Court. Briefing of the case is currently taking place.
It is too early to estimate the outcome of the cases filed by Grynberg against Questar affiliates.
Will Price v. Gas Pipelines et al. (formerly Quinque Operating Co. v. Gas Pipelines)
Questar Pipeline and Questar's subsidiaries are named defendants in a purported nationwide class action
alleging mismeasurement of volumes and heating content of gas produced from private and state lands. The
plaintiffs are alleging a conspiracy among the defendants to set industry standards that undermeasure gas.
The defendants have filed motions to dismiss the pending actions for lack of personal jurisdiction and for
failure to state a claim. The producer's complaint does not include a request for any specific monetary
damages.
Other Legal Proceedings
FERC FORM NO. 2 (12-96)Page 122.6
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Notes to Financial Statements
There are various other legal proceedings against Questar Pipeline. While it is not currently possible to
predict or determine the outcomes of these proceedings, it is the opinion of management
that the outcomes
will not have a material adverse effect on the Company's results of operations, financial
position or liquidity.
Note 8 - Employment Benefits
Pension Plan: Substantially all of Questar Pipeline's employees are covered by Questar's defined benefit
pension plan. Benefits are generally based on years of service and the employee's 72-pay period interval
of highest earnings during the ten years preceding retirement. It is Questar's policy to make contributions
to the plan at least sufficient to meet the minimum funding requirements of applicable laws and
regulations. Plan assets consist principally of equity securities and corporate and U.S. government debt
obligations.
Questar Pipeline's portion of plan assets and benefit obligations is not determinable because the plan
assets are not segregated or restricted to meet the Company's pension obligations. If the Company were
to withdraw from the pension plan, the pension obligation for the Company's employees would be
retained by the pension plan. At December 31, 2001, Questar's net benefit obligation exceeded the fair
value of plan assets.
Questar Regulated Services offered early retirement windows to eligible employees in 2000. In 2000, a total
of 276 employees and recipients of long-term disability from Questar Gas, Questar Pipeline and Questar
Regulated Services elected to retire effective October 31. The $14.4 million cost of the early retirement
window will be amortized over a five-year period in accordance with regulatory treatment. Pension cost was
$1.2 million in 2001 and $.4 million in 2000.
Postretirement Benefits Other Than Pensions: Generally postretirement health-care benefits and life
insurance are provided only to employees hired before January 1, 1997. Questar Pipeline pays a portion of
postretirement health-care costs as determined by an employee's years of service and limited to 170% of the
1992 contribution. The Company's policy is to fund amounts allowable for tax deduction under the Internal
Revenue Code. Plan assets consist of equity securities, and corporate and U.S. government debt
obligations. The Company is amortizing the transition obligation over a 20-year period, which began in 1992.
The FERC allows rate-recovery of future postretirement benefits costs to the extent that contributions are
made to an external trust. Questar Pipeline has recorded a $2.3 million regulatory liability as of December 31,
2001. As a result of returns earned on investments, the Company recorded expense reductions of $.3 million
and $.4 million in 2001and 2000, respectively. At December 31, 2001, Questar's net benefit
obligation exceeded the fair value of plan assets.
Questar Pipeline's portion of plan assets and benefit obligations related to postretirement medical and life
insurance benefits is not determinable because the plan assets are not segregated or restricted to meet
the Company's obligations.
Postemployment Benefits: Questar Pipeline recognizes the net present value of the liability for
postemployment benefits, such as long-term disability benefits and health-care and life-insurance costs,
when employees become eligible for such benefits. Postemployment benefits are paid to former employees
after employment has been terminated but before retirement benefits are paid. The Company accrues both
current and future costs. The Company has a regulatory asset amounting to $.4 million as of December 31,
2001.
Employee Investment Plan: The Company participates in Questar's Employee Investment Plan (Plan),
which allows eligible employees to purchase shares of Questar common stock or other investments through
FERC FORM NO. 2 (12-96)Page 122.7
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Notes to Financial Statements
payroll deduction. The Company matches 80% of employees'-pretax purchases up to a maximum of 6%
and contributes an additional $200 of common stock in the name of each eligible employee. The Company's
expense equals its matching contribution. The Company's expense to the plan was $.4 million in 2001and $.3
million in 2000.
Note 9 - Related-Party Transactions
Regulated Services provides administrative, technical, accounting, and legal support to Questar
Pipeline at its cost. Regulated Services also obtains data processing and communication services from an
affiliate, Questar InfoComm Inc., which are allocated to Questar Pipeline. Regulated Services charged
Questar Pipeline $21 million in 2001 and $18.8 million in 2000. The majority of these costs are
allocated and included in operating and maintenance expenses. The allocation methods are based
on several methods dictated by the nature of the charges. Management believes that the allocation methods
are reasonable.
Questar Pipeline receives a substantial portion of its revenues from Questar Gas Company. Revenues
received from Questar Gas amounted to $72.9 million in 2001and $73.7 million in 2000.
The Company also received revenues from other affiliated companies totaling $2.6 million in 2001 and $2.8 million
in 2000.
Questar performs certain administrative functions for Questar Pipeline. The Company was charged for its
allocated portion of these services that totaled $2.6 million in 2001 and $3 million in 2000. These costs
are included in operating and maintenance expenses and are allocated based on each affiliate's
proportional share of revenues, net of gas costs; property, plant and equipment; and payroll.
Management believes that the allocation method is reasonable.
Questar InfoComm Inc. is an affiliated company that provides data processing and communication services
to Questar Pipeline. Direct charges paid by the Company to Questar InfoComm amounted to $4.3 million in
2001 and $9 million in 2000.
Questar Pipeline has a 10-year lease with an option for renewal with an affiliate for some space in an office
building located in Salt Lake City, Utah. Rent expense was $.7 million and $.6 million 2001and
2000, respectively. The annual lease payment for the five years following 2001 are scheduled as
$.7 million per year from 2002 through 2006.
The Company incurred debt expense payable to Questar of $.3 million in 2001and $.8 million in 2000
and received interest income amounting to $.7 million in 2001 and $.2 million in 2000.
FERC FORM NO. 2 (12-96)Page 122.8
Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization and Depletion
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Item
(a)
Total
(b)
UTILITY PLANT 1
In Service 2
604,235,634 Plant in Service (Classified) 3
Property Under Capital Leases 4
Plant Purchased or Sold 5
Completed Construction not Classified 6
Experimental Plant Unclassified 7
604,235,634 TOTAL Utility Plant (Total of lines 3 thru 7) 8
175,723Leased to Others 9
Held for Future Use 10
38,773,444Construction Work in Progress 11
1,228,923Acquisition Adjustments 12
644,413,724 TOTAL Utility Plant (Total of lines 8 thru 12) 13
253,789,202Accumulated Provisions for Depreciation, Amortization, & Depletion 14
390,624,522 Net Utility Plant (Total of lines 13 and 14) 15
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION 16
In Service: 17
243,417,606 Depreciation 18
Amortization and Depletion of Producing Natural Gas Land and Land Rights 19
76,136 Amortization of Underground Storage Land and Land Rights 20
9,066,537 Amortization of Other Utility Plant 21
252,560,279 TOTAL In Service (Total of lines 18 thru 21) 22
Leased to Others 23
Depreciation 24
Amortization and Depletion 25
TOTAL Leased to Others (Total of lines 24 and 25) 26
Held for Future Use 27
Depreciation 28
Amortization 29
TOTAL Held for Future Use (Total of lines 28 and 29) 30
Abandonment of Leases (Natural Gas) 31
1,228,923Amortization of Plant Acquisition Adjustment 32
253,789,202 TOTAL Accum. Provisions (Should agree with line 14 above)(Total of lines 22, 26, 30, 31, and 32) 33
Page 200FERC FORM NO. 2 (12-96)
Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization and Depletion (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Electric
(c)
Gas
(d)
Other (specify)
(e)
Common
(f)
1
2
604,235,634 3
4
5
6
7
604,235,634 8
175,723 9
10
38,773,444 11
1,228,923 12
175,723 644,238,001 13
253,789,202 14
175,723 390,448,799 15
16
17
243,417,606 18
19
76,136 20
9,066,537 21
252,560,279 22
23
24
25
26
27
28
29
30
31
1,228,923 32
253,789,202 33
Page 201FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106)
1. Report below the original cost of gas plant in service according to the prescribed accounts.
2. In addition to Account 101, Gas Plant in Service (Classified), this page and the next include Account 102, Gas Plant Purchased or Sold, Account
103, Experimental Gas Plant Unclassified, and Account 106, Completed Construction Not Classified-Gas.
3. Include in column (c) and (d), as appropriate corrections of additions and retirements for the current or preceding year.
4. Enclose in parenthesis credit adjustments of plant accounts to indicate the negative effect of such accounts.
5. Classify Account 106 according to prescribed accounts, on an
estimated basis if necessary, and include the entries in column (c).Also to be included in column (c) are entries for reversals of tentative distributions of
prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary
accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to
the account for accumulated depreciation provision. Include also in column (d) reversals of tentative distributions of prior year's unclassified retirements.
Attach supplemental statement showing the account distributions of these tentative classifications in columns (c) and (d),
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Account
(a)
Balance at
Beginning of Year
(b)
Additions
(c)
Line
No.
INTANGIBLE PLANT 1
488,600 301 Organization 2
112,859 302 Franchises and Consents 3
8,963,433 4,944,076 303 Miscellaneous Intangible Plant 4
9,564,892 4,944,076 TOTAL Intangible Plant (Enter Total of lines 2 thru 4) 5
PRODUCTION PLANT 6
Natural Gas Production and Gathering Plant 7
325.1 Producing Lands 8
325.2 Producing Leaseholds 9
325.3 Gas Rights 10
325.4 Rights-of-Way 11
325.5 Other Land and Land Rights 12
326 Gas Well Structures 13
327 Field Compressor Station Structures 14
328 Field Measuring and Regulating Station Equipment 15
329 Other Structures 16
330 Producing Gas Wells-Well Construction 17
331 Producing Gas Wells-Well Equipment 18
332 Field Lines 19
333 Field Compressor Station Equipment 20
334 Field Measuring and Regulating Station Equipment 21
335 Drilling and Cleaning Equipment 22
336 Purification Equipment 23
337 Other Equipment 24
338 Unsuccessful Exploration and Development Costs 25
TOTAL Production and Gathering Plant (Enter Total of lines 8 26
PRODUCTS EXTRACTION PLANT 27
340 Land and Land Rights 28
341 Structures and Improvements 29
342 Extraction and Refining Equipment 30
343 Pipe Lines 31
344 Extracted Products Storage Equipment 32
345 Compressor Equipment 33
Page 204FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Account
(a)
Balance at
Beginning of Year
(b)
Additions
(c)
Line
No.
346 Gas Measuring and Regulating Equipment 34
347 Other Equipment 35
TOTAL Products Extraction Plant (Enter Total of lines 28 thru 35) 36
TOTAL Natural Gas Production Plant (Enter Total of lines 26 and 37
Manufactured Gas Production Plant (Submit Supplementary 38
TOTAL Production Plant (Enter Total of lines 37 and 38) 39
NATURAL GAS STORAGE AND PROCESSING PLANT 40
Underground Storage Plant 41
102,793 350.1 Land 42
8,038 350.2 Rights-of-Way 43
4,996,084 50,058 351 Structures and Improvements 44
32,973,454 20,781 352 Wells 45
83,639 352.1 Storage Leaseholds and Rights 46
867,529 352.2 Reservoirs 47
10,599,379 352.3 Non-recoverable Natural Gas 48
8,808,417 2,652 353 Lines 49
45,422,460 166,193 354 Compressor Station Equipment 50
2,126,922 355 Other Equipment 51
9,113,608 18,516 356 Purification Equipment 52
2,103,623 29,285 357 Other Equipment 53
117,205,946 287,485 TOTAL Underground Storage Plant (Enter Total of lines 42 thru 54
Other Storage Plant 55
360 Land and Land Rights 56
361 Structures and Improvements 57
362 Gas Holders 58
363 Purification Equipment 59
363.1 Liquefaction Equipment 60
363.2 Vaporizing Equipment 61
363.3 Compressor Equipment 62
363.4 Measuring and Regulating Equipment 63
363.5 Other Equipment 64
TOTAL Other Storage Plant (Enter Total of lines 56 thru 64) 65
Base Load Liquefied Natural Gas Terminaling and Processing Plant 66
364.1 Land and Land Rights 67
364.2 Structures and Improvements 68
364.3 LNG Processing Terminal Equipment 69
364.4 LNG Transportation Equipment 70
364.5 Measuring and Regulating Equipment 71
364.6 Compressor Station Equipment 72
364.7 Communications Equipment 73
364.8 Other Equipment 74
TOTAL Base Load Liquefied Nat'l Gas, Terminaling and 75
117,205,946 287,485 TOTAL Nat'l Gas Storage and Processing Plant (Total of lines 54, 76
TRANSMISSION PLAN 77
229,936 365.1 Land and Land Rights 78
2,085,448 365.2 Rights-of-Way 79
8,267,166 1,037,930 366 Structures and Improvements 80
Page 206FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Account
(a)
Balance at
Beginning of Year
(b)
Additions
(c)
Line
No.
234,934,366 67,258,512 367 Mains 81
68,028,069 17,753,462 368 Compressor Station Equipment 82
20,042,714 6,831,137 369 Measuring and Regulating Station Equipment 83
10,925,184 874,460 370 Communication Equipment 84
47,772 18,822 371 Other Equipment 85
344,560,655 93,774,323 TOTAL Transmission Plant (Enter Totals of lines 78 thru 85) 86
DISTRIBUTION PLANT 87
374 Land and Land Rights 88
375 Structures and Improvements 89
376 Mains 90
377 Compressor Station Equipment 91
378 Measuring and Regulating Station Equipment-General 92
379 Measuring and Regulating Station Equipment-City Gate 93
380 Services 94
381 Meters 95
382 Meter Installations 96
383 House Regulators 97
384 House Regulator Installations 98
385 Industrial Measuring and Regulating Station Equipment 99
386 Other Property on Customers' Premises100
387 Other Equipment101
TOTAL Distribution Plant (Enter Total of lines 88 thru 101)102
GENERAL PLANT103
1,296,440 75,396 389 Land and Land Rights104
11,765,651 43,990 390 Structures and Improvements105
5,794,436 277,520 391 Office Furniture and Equipment106
8,104,973 468,108 392 Transportation Equipment107
63,884 393 Stores Equipment108
3,154,524 19,016 394 Tools, Shop, and Garage Equipment109
207,566 395 Laboratory Equipment110
2,646,604 220,190 396 Power Operated Equipment111
896,407 910 397 Communication Equipment112
1,860,147 32,756 398 Miscellaneous Equipment113
35,790,632 1,137,886 Subtotal (Enter Total of lines 104 thru 113)114
399 Other Tangible Property115
35,790,632 1,137,886 TOTAL General Plant (Enter Total of lines 114 and 115)116
507,122,125 100,143,770 TOTAL (Accounts 101 and 106)117
Gas Plant Purchased (See Instruction 8)118
(Less) Gas Plant Sold (See Instruction 8)119
Experimental Gas Plant Unclassified120
507,122,125 100,143,770 TOTAL Gas Plant In Service (Enter Total of lines 117 thru 120)121
Page 208FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106) (continued)
including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of
Account 101 and 106 will avoid serious omissions of respondent's reported amount for plant actually in service at end of year.
6. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary
account
classifications arising from distribution of amounts initially recorded in Account 102. In showing the clearance of Account 102, include in column (e) the
amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or
credits to primary account classifications.
7. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing
subaccount classification of such plant conforming to the requirements of these pages.
8. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchaser,
and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give date of
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at
End of Year
(g)
Line
No.
1
488,600 2
112,859 3
13,907,509 4
14,508,968 5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
Page 205FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at
End of Year
(g)
Line
No.
34
35
36
37
38
39
40
41
102,793 42
8,038 43
5,046,142 44
32,994,235 45
83,639 46
867,529 47
10,599,379 48
8,811,069 49
45,614,497 25,844 50
2,126,922 51
9,132,124 52
2,132,908 53
117,519,275 25,844 54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
117,519,275 25,844 76
77
229,936 78
2,070,817 14,631 79
9,297,887 7,209 80
Page 207FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at
End of Year
(g)
Line
No.
301,569,119 623,759 81
85,755,687( 25,844) 82
26,249,705 624,146 83
11,673,970 125,674 84
66,594 85
436,913,715( 25,844) 1,395,419 86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
1,371,836104
11,809,641105
62,458 5,583,344 551,070106
( 54,710) 7,916,596 601,775107
63,884108
3,164,820 8,720109
207,566110
2,386,660 480,134111
897,317112
1,892,010 893113
7,748 35,293,674 1,642,592114
115
7,748 35,293,674 1,642,592116
7,748 604,235,632 3,038,011117
118
119
120
7,748 604,235,632 3,038,011121
Page 209FERC FORM NO. 2 (12-96)
Gas Property and Capacity Leased from Others
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Name of Lessor
(a)
*
(b)
Description of Lease
(c)
1. Report below the information called for concerning gas property and capacity leased from others for gas operations.
2. For all leases in which the average annual lease payment over the initial term of the lease exceeds $500,000, describe in column
(c), if applicable: the property or capacity leased. Designate associated companies with an asterisk in column (b).
Lease Payments for
Current Year
(d)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
Total 45
Page 212FERC FORM NO. 2 (12-96)
Gas Property and Capacity Leased to Others
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Name of Lessor
(a)
*
(b)
Description of Lease
(c)
1. For all leases in which the average lease income over the initial term of the lease exceeds $500,000 provide in column (c), a
description of each facility or leased capacity that is classified as gas plant in service, and is leased to others for gas operations.
2. In column (d) provide the lease payments received from others.
3. Designate associated companies with an asterisk in column (b).
Lease Payments for
Current Year
(d)
12 Acres - CoalvilleEarl Robinson 1
2,40036.86 Acres - Located Near CoalvilleDennis Wright 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
2,400Total 45
Page 213FERC FORM NO. 2 (12-96)
Gas Plant Held for Future Use (Account 105)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Description and Location
of Property
(a)
1. Report separately each property held for future use at end of the year having an original cost of $1,000,000 or more. Group other
items of property held for future use.
2. For property having an original cost of $1,000,000 or more previously used in utility operations, now held for future use, give in
column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the
original cost was transferred to Account 105.
Date Originally Included
in this Account
(b)
Date Expected to be Used
in Utility Service
(c)
Balance at
End of Year
(d)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
Total 45
Page 214FERC FORM NO. 2 (12-96)
Construction Work in Progress-Gas (Account 107)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Description of Project
(a)
Construction Work in
Progress-Gas
(Account 107)
(b)
1. Report below descriptions and balances at end of year of projects in process of construction (Account 107).
2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development,
and Demonstration (see Account 107 of the Uniform System of Accounts).
3. Minor projects (less than $1,000,000) may be grouped.
Estimated Additional
Cost of Project
(c)
Underground Storage Plant-Clay Basin 1
Storage Division 2
2,295,321 Clay Basin Dewpoint Plant 3
222,840 Miscellaneous 4
Underground Storage Plant-Peaking 5
Transmission Division 6
17,060 Miscellaneous 7
Transmission Plant 8
3,293,860 Miscellaneous 9
2,620,540 Billable and Expense Work Orders 10
14,382,447 ML 104 - ML 40/JL 12 to Kern River 11
6,936,435 ML 104 Compressor 12
1,466,271 ML 3 At Morgan 13
Other 14
3,334,188 SW Wyoming Storage Project 15
General and Intangible 16
1,397,103 QPC Hub Software 17
2,807,379 Miscellaneous 18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
38,773,444Total 45
Page 216FERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
General Description of Construction Overhead Procedure
1. For each construction overhead explain: (a) the nature and extent of work, etc., the overhead charges are intended to cover, (b) the general
procedure for determining the amount capitalized, (c) the method of distribution to construction jobs, (d) whether different rates are applied to
different types of construction, (e) basis of differentiation in rates for different types of construction, and (f) whether the overhead is directly or
indirectly assigned.
2. Show below the computation of allowance for funds used during construction rates, in accordance with the provisions of Gas Plant
Instructions 3 (17) of the Uniform System of Accounts.
3. Where a net-of-tax rate for borrowed funds is used, show the appropriate tax effect adjustment to the computations below in a manner that
clearly indicates the amount of reduction in the gross rate for tax effects.
(a) Construction overhead charged to construction represents the indirect labor
and administrative costs applicable to construction.
(b) A work order is used to accumulate overhead costs. These costs are then cleared to
open work orders.
(c) Overhead charged to construction is allocated on a per dollar rate. This rate can
vary each month depending upon the amount of overhead accumulated and the
dollars charged to construction projects.
(d) The calculated rate is applied to all types of construction.
(e) None
(f) Overhead is directly assigned to each work order.
FERC FORM NO. 2 (12-96)Page 218
General Description of Construction Overhead Procedure (continued)
COMPUTATION OF ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION RATES
For line (5), column (d) below, enter the rate granted in the last rate proceeding. If not available, use the average rate earned during the preceding 3 years.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Title
(a)
Cost Rate
Percentage
(d)
Amount
(b)
Capitalization
Ration (percent)
(c)
1. Components of Formula (Derived from actual book balances and actual cost rates):
6,991,667(1) Average Short-Term Debt S
3.70(2) Short-Term Interest s
255,816,667 7.65 51.71(3) Long-Term Debt D d
(4) Preferred Stock P p
238,891,377 11.75 48.29(5) Common Equity C c
494,708,044 100.00(6) Total Capitalization
59,577,106(7) Average Construction Work In Progress Balance W
5.01
3.932. Gross Rate for Borrowed Funds s(S/W) + d[(D/(D+P+C)) (1-(S/W))]
3. Rate for Other Funds [1-(S/W)] [p(P/(D+P+C)) + c(C/(D+P+C))]
4. Weighted Average Rate Actually Used for the Year:
a. Rate for Borrowed Funds -
b. Rate for Other Funds -
Page 218aFERC FORM NO. 2 (12-96)
Accumulated Provision for Depreciation of Gas Utility Plant (Account 108)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Item
(a)
Total
(c+d+e)
(b)
1. Explain in a footnote any important adjustments during year.
2. Explain in a footnote any difference between the amount for book cost of plant retired, line 10, column (c), and that reported for gas
plant in service, page 204-209, column (d), excluding retirements of nondepreciable property.
3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when
such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been
recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize
the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate
functional classifications.
4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
5. At lines 7 and 14, add rows as necessary to report all data. Additional rows should be numbered in sequence, e.g., 7.01, 7.02, etc.
Gas Plant in
Service
(c)
Gas Plant Held
for Future Use
(d)
Gas Plant Leased
to Others
(e)
Section A. BALANCES AND CHANGES DURING YEAR
1 230,240,770 230,240,770 Balance Beginning of Year
2 Depreciation Provisions for Year, Charged to
3 14,835,444 14,835,444 (403) Depreciation Expense
4 (413) Expense of Gas Plant Leased to Others
5 545,105 545,105 Transportation Expenses - Clearing
6 653,074 653,074 Other Clearing Accounts
7 Other Clearing (Specify):
7.01
7.02
7.03
7.04
7.05
8 16,033,623 16,033,623TOTAL Deprec. Prov. for Year (Total of lines 3 thru 7.?)
9 Net Charges for Plant Retired:
10 ( 3,038,011)( 3,038,011) Book Cost of Plant Retired
11 ( 19,658)( 19,658) Cost of Removal
12 ( 438,853)( 438,853) Salvage (Credit)
13 ( 2,618,816)( 2,618,816)TOTAL Net Chrgs for Plant Ret. (Total of lines 10 thru 12)
14 ( 237,971)( 237,971) Other Debit or Credit Items (Describe): See below
14.01
14.02
14.03
14.04
14.05
14.06
14.07
14.08
14.09
14.10
15 243,417,606 243,417,606Balance End of Year (Total of lines 1,8,13,14 to14.?
Page 219FERC FORM NO. 2 (12-96)
Accumulated Provision for Depreciation of Gas Utility Plant (Account 108) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Item
(a)
Total
(c+d+e)
(b)
1. Explain in a footnote any important adjustments during year.
2. Explain in a footnote any difference between the amount for book cost of plant retired, line 10, column (c), and that reported for gas
plant in service, page 204-209, column (d), excluding retirements of nondepreciable property.
3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when
such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been
recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize
the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate
functional classifications.
4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
5. At lines 7 and 14, add rows as necessary to report all data. Additional rows should be numbered in sequence, e.g., 7.01, 7.02, etc.
Gas Plant in
Service
(c)
Gas Plant Held
for Future Use
(d)
Gas Plant Leased
to Others
(e)
Section B. BALANCES AT END OF YEAR ACCORDING TO
FUNCTIONAL CLASSIFICATIONS
16 Productions-Manufactured Gas
17 Production and Gathering-Natural Gas
18 Products Extraction-Natural Gas
19 67,746,917 67,746,917 Underground Gas Storage
20 Other Storage Plant
21 Base Load LNG Terminaling and Processing Plant
22 151,607,007 151,607,007 Transmission
23 Distribution
24 24,063,682 24,063,682 General
25 243,417,606 243,417,606TOTAL (Total of lines 16 thru 24)
Page 219FERC FORM NO. 2 (12-96)(continued)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
Schedule Page: 219 Line No.: 14 Column: c
Other Debit or Credit
(a) Debits Gain on Disposition of Assets $259,494
Transfers to Associated Companies 192,511
Credit Loss on Disposition of Assets 41,064
Transfers from Associated Companies 172,970
Total - Column (b) ( $237,971)
FERC FORM NO. 2 (12-96)Page 552













































 

 







































 

























 


!



!



!










!










"

#







! 

 





!









 


$














 
 









%


&
&



'


(










$

) 











$
!  



*

++



"
,
- 

.
/
0"01111
  


$

2
!
$

2

&


$

2"

$

23


.

$

43

%&5
$

43

%&5
$

43"


'
 





  





 













 





 










 





  

 
!
"



#
$ 
%


&





 

  




 




'










#




 #  











(

(

(

)"*
+



   !" #$
Book Cost at Beginning of Year
(If book cost is different from
cost to respondent, give cost to
respondent in a footnote and
explain difference)
(c)
Investments (Account 123, 124, and 136)
1. Report below investments in Accounts 123, Investments in Associated Companies, 124, Other Investments, and 136, Temporary Cash Investments.
2. Provide a subheading for each account and list thereunder the information called for:
(a) Investment in Securities-List and describe each security owned, giving name of issuer, date acquired and date of maturity. For bonds, also give principal amount, date of issue,
maturity, and interest rate. For capital stock (including capital stock of respondent reacquired under a definite plan for resale pursuant to authorization by the Board of Directors, and
included in Account 124, Other Investments) state number of shares, class, and series of stock. Minor investments may be grouped by classes. Investments included in Account 136,
Temporary Cash Investments, also may be grouped by classes.
(b) Investment Advances-Report separately for each person or company the amounts of loans or investment advances that are properly includable in Account 123. Include advances
subject to current repayment in Account 145 and 146. With respect to each advance, show whether the advance is a note or open account.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description of Investment
(a)
Purchases or
Additions
During the Year
(d)
*
(b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 222FERC FORM NO. 2 (12-96)
Investments (Account 123, 124, and 136) (continued)
List each note, giving date of issuance, maturity date, and specifying whether note is a renewal. Designate any advances due from officers, directors, stockholders, or employees.
3. Designate with an asterisk in column (b) any securities, notes or accounts that were pledged, and in a footnote state the name of pledges and purpose of the pledge.
4. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and cite Commission, date of authorization, and case or docket
number.
5. Report in column (h) interest and dividend revenues from investments including such revenues from securities disposed of during the year.
6. In column (i) report for each investment disposed of during the year the gain or loss represented by the difference between cost of the investment (or the other amount at which
carried in the books of account if different from cost) and the selling price thereof, not including any dividend or interest adjustment includible in column (h).
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Gain or Loss from
Investment
Disposed of
(i)
Revenues for
Year
(h)
Sales or Other
Dispositions
During Year
(e)
Principal Amount or
No. of Shares at
End of Year
(f)
Book Cost at End of Year
(If book cost is different from cost
to respondent, give cost to
respondent in a footnote and
explain difference)
(g)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 223FERC FORM NO. 2 (12-96)
Date of
Maturity
(c)
Investments in Subsidiary Companies (Account 123.1)
1. Report below investments in Account 123.1, Investments in Subsidiary Companies.
2. Provide a subheading for each company and list thereunder the information called for below. Sub-total by company and give a total in columns (e), (f), (g) and (h).
(a) Investment in Securities-List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate.
(b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect
to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal.
3. Report separately the equity in undistributed subsidiary earnings since acquisition. The total in column (e) should equal the amount entered for Account 418.1.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description of Investment
(a)
Amount of
Investment at
Beginning of Year
(d)
Date
Acquired
(b)
16,141,00104/01/1982Overthrust Pipeline Company 1
2,947,09910/01/1990TransColorado Gas Transmission Company 2
21,362,72211/17/1998Questar Line 90 Company Questar Southern Trails Pipeline Company 3
13,040,09108/22/1999Questar Transportation Services 4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
53,490,913TOTAL Cost of Account 123.1 $ 40 TOTAL
Page 224FERC FORM NO. 2 (12-96)
Investments in Subsidiary Companies (Account 123.1) (continued)
4. Designate in a footnote, any securities, notes, or accounts that were pledged, and state the name of pledgee and purpose of the pledge.
5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or
docket number.
6. Report in column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year.
7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which
carried in the books of account if different from cost), and the selling price thereof, not including interest adjustments includible in column (f).
8. Report on Line 40, column (a) the total cost of Account 123.1.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Gain or Loss from
Investment
Disposed of
(h)
Equity in Subsidiary
Earnings for Year
(e)
Revenues for Year
(f)
Amount of Investment
at End of Year
(g)
15,610,110( 530,891) 1
105,488,486 102,541,387 2
22,562,906 1,200,184 3
15,413,269 2,373,178 4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
159,074,771 105,583,85840
Page 225FERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
Schedule Page: 224 Line No.: 1 Column: e
The total shown for Equity in Subsidiary Companies includes a $1.5 Million cash distribution recieved from Overthrust
Pipeline Company in October 2001. This distribution is not included in the 418.1 account but is recorded as an a decrease
in total investment.
Schedule Page: 224 Line No.: 2 Column: e
The total in Equity in Subsidiary Earning from TransColorado includes the following amounts that are not reported in the
418.1 account:
Cash Call January 2001 $2 million
Cash Call April 2001 $2 million
Cash Call July 2001 $.7 million
Addional Investment October 2001 $100 Million
These amounts are recorded as increases to investment.
FERC FORM NO. 2 (12-96)Page 552
Prepayments (Acct 165), Extraordinary Property Losses (Acct 182.1), Unrecovered Plant and Regulatory Study Costs (Acct 182.2)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Nature of Payment
(a)
Balance at End
of Year
(in dollars)
(b)
1. Report below the particulars (details) on each prepayment.
PREPAYMENTS (ACCOUNT 165)
617,224Prepaid Insurance 1
Prepaid Rents 2
Prepaid Taxes 3
Prepaid Interest 4
Miscellaneous Prepayments 5
617,224TOTAL 6
Page 230aFERC FORM NO. 2 (12-96)
Prepayments (Acct 165), Extraordinary Property Losses (Acct 182.1), Unrecovered Plant and Regulatory Study Costs (Acct 182.2)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description of Extraordinary Loss [include the
date of loss, the date of Commission
authorization to use Account 182.1 and period of
amortization (mo, yr, to mo, yr)] Add rows as
necessary to report all data.
(a)
Balance at
End of Year
(g)
Balance at
Beginning
of Year
(b)
Total
Amount
of Loss
(c)
EXTRAORDINARY PROPERTY LOSSES (ACCOUNT 182.1)
Losses
Recognized
During Year
(d)
Written off
During Year
Account
Charged
(e)
Written off
During Year
Amount
(f)
7
8
9
10
11
12
13
14
15 Total
Page 230bFERC FORM NO. 2 (12-96)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description of Unrecovered Plant and Regulatory
Study Costs [Include in the description of costs,
the date of Commission authorization to use
Account 182.2 and period of amortization (mo,
yr, to mo, yr)] Add rows as necessary to report
all data. Number rows in sequence beginning
with the next row number after the last row
number used for extraordinary property losses.
(a)
Balance at
End of Year
(g)
Balance at
Beginning
of Year
(b)
Total
Amount
of Charges
(c)
UNRECOVERED PLANT AND REGULATORY STUDY COSTS (ACCOUNT 182.2)
Costs
Recognized
During Year
(d)
Written off
During Year
Account
Charged
(e)
Written off
During Year
Amount
(f)
Prepayments (Acct 165), Extraordinary Property Losses (Acct 182.1), Unrecovered Plant and Regulatory Study Costs (Acct 182.2)
(continued)
16
17
18
19
20
21
22
23
24
25
26 Total
Page 230cFERC FORM NO. 2 (12-96)
Other Regulatory Assets (Account 182.3)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Description and Purpose of
Other Regulatory Assets
(a)
Balance at
Beginning
of Year
(b)
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 (a).
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.
Balance at
End of Year
(f)
Debits
(c)
Written off
During Year
Account
Charged
(d)
Written off
During Year
Amount
(e)
Regulatory Asset for FAS 109 Rate Base 282/283 4,213,417 36,446 4,249,863 1
Regulatory Asset for FAS 109 Non Rate Base 283 52,398 52,398 2
Regulatory Asset for FAS 106 3
Regulatory asset for FAS 112 232 396,759 73,791 322,968 4
Regulatory Asset Early Retirement Costs 5 Year
Amortization Period 184 123,965 78,294 202,259
5
Regulatory Asset Early Retirement Costs 165/232 1,199,593 312,938 1,512,531 6
Regulatory Asset Early Retirement Costs 165/232 15,942 4,159 20,101 7
Regulatory Asset for LTD 242,887( 242,887) 8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
6,117,233 316,678 431,837 6,002,074Total 40
Page 232FERC FORM NO. 2 (12-96)
Miscellaneous Deferred Debits (Account 186)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Description of Miscellaneous
Deferred Debits
(a)
Balance at
Beginning
of Year
(b)
1. Report below the details called for concerning miscellaneous deferred debits.
2. For any deferred debit being amortized, show period of amortization in column (a).
3. Minor items (less than $250,000) may be grouped by classes.
Balance at
End of Year
(f)
Debits
(c)
Credits
Account
Charged
(d)
Credits
Amount
(e)
756,789 454,086 787,579 423,296 928.0Deferred Regulatory Commission Expense 1
4,139,596 4,139,596 253.7Fuel Gas Amortization - Prior Period 2
9,740,100 10,530,717( 790,617)253.6Fuel Gas Amortization - Current 3
3,164,604 284 2,961,259 203,629 146.0Intercompany Clearing 4
1 1 143.0Woods Cross Hanger 5
461,280 25,006 462,143 24,143 232.0Deferred Debit - Invoices on Hold 6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
Miscellaneous Work in Progress... 39
479,376 18,262,370 14,741,698 4,000,048Total 40
Page 233FERC FORM NO. 2 (12-96)
Accumulated Deferred Income Taxes (Account 190)
1. Report the information called for below concerning the respondent's accounting for deferred income taxes.
2. At Other (Specify), include deferrals relating to other income and deductions.
3. At lines 4 and 6, add rows as necessary to report all data. Number the additional rows in sequence 4.01, 4.02, etc. and 6.01, 6.02, etc.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Account Subdivisions
(a)
Changes During
Year
Amounts Credited
to Account 411.1
(d)
Balance at
Beginning
of Year
(b)
Changes During
Year
Amounts Debited
to Account 410.1
(c)
Account 190 1
Electric 2
( 67,377) 2,628,740Gas 3
Other (Define) 4
4.01
4.02
4.03
4.04
4.05
4.06
4.07
4.08
4.09
4.10
4.11
4.12
4.13
4.14
4.15
4.16
4.17
4.18
4.19
4.20
4.21
4.22
4.23
4.24
4.25
4.26
4.27
4.28
4.29
4.30
( 67,377) 2,628,740Total (Total of lines 2 thru 4) 5
Other (Specify) 6
6.01
6.02
6.03
6.04
6.05
6.06
6.07
6.08
6.09
Page 234FERC FORM NO. 2 (12-96)
Accumulated Deferred Income Taxes (Account 190) (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Account Subdivisions
(a)
Changes During
Year
Amounts Credited
to Account 411.1
(d)
Balance at
Beginning
of Year
(b)
Changes During
Year
Amounts Debited
to Account 410.1
(c)
6.10
6.11
6.12
6.13
6.14
6.15
6.16
6.17
6.18
6.19
6.20
( 67,377) 2,628,740TOTAL Account 190 (Total of lines 5 thru 6.?) 7
Classification of TOTAL 8
( 63,735)( 374,070)Federal Income Tax 9
( 3,642) 3,002,810State Income Tax 10
Local Income Tax 11
Page 234aFERC FORM NO. 2 (12-96)
Accumulated Deferred Income Taxes (Account 190) (continued)
4. If more space is needed, use separate pages as required.
5. In the space provided below, identify by amount and classification, significant items for which deferred taxes are being provided. Indicate insignificant amounts listed under "Other."
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Adjustments
Debits
Account No.
(g)
Changes During
Year
Amounts Debited
to Account 410.2
(e)
Changes During
Year
Amounts Credited
to Account 411.2
(f)
Adjustments
Debits
Amount
(h)
Adjustments
Credits
Account No.
(i)
Adjustments
Credits
Amount
(j)
Balance at
End of Year
(k)
1
2
2,631,072 65,045 3
4
4.01
4.02
4.03
4.04
4.05
4.06
4.07
4.08
4.09
4.10
4.11
4.12
4.13
4.14
4.15
4.16
4.17
4.18
4.19
4.20
4.21
4.22
4.23
4.24
4.25
4.26
4.27
4.28
4.29
4.30
2,631,072 65,045 5
6
6.01
6.02
6.03
6.04
6.05
6.06
6.07
6.08
6.09
Page 235FERC FORM NO. 2 (12-96)
Accumulated Deferred Income Taxes (Account 190) (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Adjustments
Debits
Account No.
(g)
Changes During
Year
Amounts Debited
to Account 410.2
(e)
Changes During
Year
Amounts Credited
to Account 411.2
(f)
Adjustments
Debits
Amount
(h)
Adjustments
Credits
Account No.
(i)
Adjustments
Credits
Amount
(j)
Balance at
End of Year
(k)
6.10
6.11
6.12
6.13
6.14
6.15
6.16
6.17
6.18
6.19
6.20
2,631,072 65,045 7
8
( 275,310)( 35,025) 9
2,906,382 100,070 10
11
Page 235aFERC FORM NO. 2 (12-96)
Capital Stock (Accounts 201 and 204)
1. Report below the details called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and
preferred stock.
2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.
3. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Class and Series of Stock and
Name of Stock Exchange
(a)
Call Price at
End of Year
(d)
Number of Shares
Authorized by Charter
(b)
Par or Stated Value
per Share
(c)
Common Stock - Not Traded on a Stock Exchange 1.00 25,000,000 1
Subtotal Common Stock 1.00 25,000,000 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 250FERC FORM NO. 2 (12-96)
Capital Stock (Accounts 201 and 204)
4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
5. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year.
6. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and
purpose of pledge.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Outstanding per Bal. Sheet
(total amt outstanding
without reduction for amts
held by respondent)
Shares
(e)
Held by
Respondent
As Reacquired
Stock (Acct 217)
Cost
(h)
Outstanding per Bal.
Sheet
Amount
(f)
Held by
Respondent
As Reacquired
Stock (Acct 217)
Shares
(g)
Held by
Respondent
In Sinking and
Other Funds
Amount
(j)
Held by
Respondent
In Sinking and
Other Funds
Shares
(i)
6,550,843 6,550,843 1
6,550,843 6,550,843 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 251FERC FORM NO. 2 (12-96)
Capital Stock: Subscribed, Liability for Conversion, Premium on, and Installments Recieved on (Accts 202, 203, 205, 206, 207, and 212)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Name of Account and
Description of Item
(a)
*
(b)
Number
of Shares
(c)
1. Show for each of the above accounts the amounts applying to each class and series of capital stock.
2. For Account 202, Common Stock Subscribed, and Account 205, Preferred Stock Subscribed, show the subscription price and the
balance due on each class at the end of year.
3. Describe in a footnote the agreement and transactions under which a conversion liability existed under Account 203, Common
Stock Liability for Conversion, or Account 206, Preferred Stock Liability for Conversion, at the end of year.
4. For Premium on Account 207, Capital Stock, designate with an asterisk in column (b), any amounts representing the excess of
consideration received over stated values of stocks without par value.
Amount
(d)
124,910,906 6,550,843Account 207 1
Premium on Capital Stock 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
6,550,843 124,910,906Total 40
Page 252FERC FORM NO. 2 (12-96)
Other Paid-In Capital (Accounts 208-211)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Item
(a)
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital
accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation
with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting
such change.
(a) Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation.
(b) Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave
rise to amounts reported under this caption including identification with the class and series of stock to which related.
(c) Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits,
and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which
related.
(d) Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with
brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Amount
(b)
17,122,500209 Reduction in Par or Stated Value of Capital Stock 1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
17,122,500Total 40
Page 253FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
DISCOUNT ON CAPITAL STOCK (ACCOUNT 213)
1. Report the balance at end of year of discount on capital stock for each class and series of capital stock. Use as many rows as necessary to report all data.
2. If any change occurred during the year in the balance with respect to any class or series of stock, attach a statement giving details of the change. State the reason for any charge-off
during the year and specify the account charged.
Line
No.
Class and Series of Stock
(a)
Balance at
End of Year
(b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
TOTAL
Class and Series of Stock
(a)
Balance at
End of Year
(b)
CAPITAL STOCK EXPENSE (ACCOUNT 214)
Line
No.
1. Report the balance at end of year of capital stock expenses for each class and series of capital stock. Use as many rows as necessary to report all data. Number the rows in
sequence starting from the last row number used for Discount on Capital Stock above.
2. If any change occurred during the year in the balance with respect to any class or series of stock, attach a statement giving details of the change. State the reason for any charge-off
of capital stock expense and specify the account charged.
16
17
18
19
20
21
22
23
24
25
26
27
28
TOTAL
Page 254FERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
Securities Issued or Assumed and Securities Refunded or Retired During the Year
1. Furnish a supplemental statement briefly describing security financing and refinancing transactions during the year and the accounting for
the securities, discounts, premiums, expenses, and related gains or losses. Identify as to Commission authorization numbers and dates.
2. Provide details showing the full accounting for the total principal amount, par value, or stated value of each class and series of security
issued, assumed, retired, or refunded and the accounting for premiums, discounts, expenses, and gains or losses relating to the securities. Set
forth the facts of the accounting clearly with regard to redemption premiums, unamortized discounts, expenses, and gain or losses relating to
securities retired or refunded, including the accounting for such amounts carried in the respondent's accounts at the date of the refunding or
refinancing transactions with respect to securities previously refunded or retired.
3. Include in the identification of each class and series of security, as appropriate, the interest or dividend rate, nominal date of issuance,
maturity date, aggregate principal amount, par value or stated value, and number of shares. Give also the issuance of redemption price and
name of the principal underwriting firm through which the security transactions were consummated.
4. Where the accounting for amounts relating to securities refunded or retired is other than that specified in General Instruction 17 of the
Uniform System of Accounts, cite the Commission authorization for the different accounting and state the accounting method.
5. For securities assumed, give the name of the company for which the liability on the securities was assumed as well as details of the
transactions whereby the respondent undertook to pay obligations of another company. If any unamortized discount, premiums, expenses, and
gains or losses were taken over onto the respondent's books, furnish details of these amounts with amounts relating to refunded securities
clearly earmarked.
FERC FORM NO. 2 (12-96)Page 255
Date of
Maturity
(c)
Long-Term Debt (Accounts 221, 222, 223, and 224)
1. Report by Balance Sheet Account the details concerning long-term debt included in Account 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and
224, Other Long-Term Debt.
2. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds.
3. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names
of associated companies from which advances were received.
4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Class and Series of Obligation and
Name of Stock Exchange
(a)
Outstanding
(Total amount
outstanding without
reduction for amts
held by respondent)
(d)
Nominal Date
of Issue
(b)
221 Long Term Debt - Bonds 9.875% Debentures 06/01/202006/11/1990 1
221 Long Term Debt - Bonds 9.375% Debentures 06/01/202106/01/1999 2
224 Long Term Debt - Note 6.00% 10,000,00010/06/200810/05/1998 3
224 Long Term Debt - Note 5.95% 15,000,00010/06/200810/05/1998 4
224 Long Term Debt - Note 5.85% 10,000,00010/07/200810/07/1998 5
224 Long Term Debt - Note 6.45% 25,100,00010/15/201510/26/1998 6
224 Long Term Debt - Note 6.05% 23,300,00012/01/200811/30/1998 7
224 Long Term Debt - Note 6.48% 5,000,00012/11/201812/11/1998 8
224 Long Term Debt - Note 7.41% 22,000,00010/01/200910/01/1999 9
224 Long Term Debt - Note 7.55% 20,000,00010/26/200910/25/1999 10
224 Long Term Debt - Note 6.57% 80,000,00009/26/201109/26/2001 11
224 Long Term Debt - Note 7.09% 100,000,00006/01/201105/29/2001 12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
310,400,00040TOTAL
Page 256FERC FORM NO. 2 (12-96)
Held by
Respondent
Reacquired Bonds
(Acct 222)
(g)
Long-Term Debt (Accounts 221, 222, 223, and 224)
5. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)
principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates.
6. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name
of the pledgee and purpose of the pledge.
7. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote.
8. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (f). Explain in a footnote any
difference between the total of column (f) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies.
9. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Interest for
Year
Rate
(in %)
(e)
Redemption Price
per $100 at
End of Year
(i)
Interest for
Year
Amount
(f)
Held by
Respondent
Sinking and
Other Funds
(h)
732,396 1
3,851,563 2
600,000 3
892,500 4
585,000 5
1,618,950 6
1,409,650 7
324,000 8
1,630,200 9
1,510,000 10
4,174,683 11
1,387,439 12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
18,716,38140
Page 257FERC FORM NO. 2 (12-96)
Unamortized Debt Expense, Premium and Discount on Long-Term Debt (Accounts 181, 225, 226)
1. Report under separate subheadings for Unamortized Debt Expense, Unamortized Premium on Long-Term Debt and Unamortized Discount on Long-Term Debt, details of expense,
premium or discount applicable to each class and series of long-term debt.
2. Show premium amounts by enclosing the figures in parentheses.
3. In column (b) show the principal amount of bonds or other long-term debt originally issued.
4. In column (c) show the expense, premium or discount with respect to the amount of bonds or other long-term debt originally issued.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Designation of
Long-Term Debt
(a)
Amortization
Period
Date From
(d)
Principal Amount
of Debt Issued
(b)
Total Expense
Premium or
Discount
(c)
Amortization
Period
Date To
(e)
04/15/201004/15/1985 955,874 50,000,000181 Long Term Debt - Bonds 12.5% Debentures 1
06/01/202006/11/1990 822,026 30,000,000181 Long Term Debt - Bonds 9.875% Debentures 2
06/01/202106/01/1991 993,044 85,000,000181 Long Term Debt - 9.375% Debentures 3
10/06/200810/05/1998 90,585 10,000,000181 Long Term Debt - Note 6.00% 4
10/06/200810/05/1998 135,878 15,000,000181 Long Term Debt - Note 5.95% 5
10/07/200810/07/1998 90,585 10,000,000181 Long Term Debt - Note 5.85% 6
10/15/201510/26/1998 246,194 25,100,000181 Long Term Debt - Note 6.45% 7
12/01/200810/30/1998 211,063 23,300,000181 Long Term Debt - Note 6.05% 8
12/11/201812/11/1998 51,543 5,000,000181 Long Term Debt - Note 6.48% 9
10/26/200910/25/1999 181,170 20,000,000181 Long Term Debt - Note 6.20% 10
10/01/200910/01/1999 199,287 22,000,000181 Long Term Debt - Note 5.91% 11
09/26/201109/26/2001 500,000 80,000,000181 Long Term Debt - Note 6.57% 12
06/01/201105/29/2001 625,000 100,000,000181 Long Term Debt - Note 7.09% 13
Total Unamortized Debt Expense 14
15
16
06/01/202006/11/1990 265,000 30,000,000226 Long Term Debt - Bonds 9.875% Debentures 17
06/01/202106/01/1991 306,000 85,000,000226 Long Term Debt - 9.375% Debentures 18
06/01/201105/29/2001 100,000,000226 Long Term Debt - 7.09% Debentures 19
571,000 223,400,000Total Unamortized Discount on Long Term Debt 20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 258FERC FORM NO. 2 (12-96)
Unamortized Debt Expense, Premium and Discount on Long-Term Debt (Accounts 181, 225, 226)
5. Furnish in a footnote details regarding the treatment of unamortized debt expense, premium or discount associated with issues redeemed during the year. Also, give in a footnote
the date of the Commission's authorization of treatment other than as specified by the Uniform System of Accounts.
6. Identify separately undisposed amounts applicable to issues which were redeemed in prior years.
7. Explain any debits and credits other than amortization debited to Account 428, Amortization of Debt Discount and Expense, or credited to Account 429, Amortization of Premium on
Debt-Credit.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Balance at
Beginning
of Year
(f)
Debits During
Year
(g)
Credits During
Year
(h)
Balance at
End of Year
(i)
314,715 37,955 352,670 1
504,906 27,416 532,322 2
642,718 33,102 675,820 3
70,357 6,250 28,085 48,522 4
105,536 9,375 42,128 72,783 5
70,390 6,250 28,085 48,555 6
213,327 10,335 70,494 153,168 7
166,123 14,562 65,438 115,247 8
45,817 1,875 14,043 33,649 9
153,878 12,500 56,170 110,208 10
168,350 13,750 61,787 120,313 11
487,500 12,500 500,000 12
614,583 614,583 13
3,558,200 185,870 1,480,813 2,263,257 14
15
16
162,684 8,832 171,516 17
198,050 10,200 208,250 18
( 26,041) 651,041 625,000 19
334,693 670,073 625,000 379,766 20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 259FERC FORM NO. 2 (12-96)
Unamortized Loss and Gain on Reacquired Debt (Accounts 189, 257)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Designation of
Long-Term Debt
(a)
Date
Reacquired
(b)
1. Report under separate subheadings for Unamortized Loss and Unamortized Gain on Reacquired Debt, details of gain and loss,
including maturity date, on reacquisition applicable to each class and series of long-term debt. If gain or loss resulted from a refunding
transaction, include also the maturity date of the new issue.
2. In column (c) show the principal amount of bonds or other long-term debt reacquired.
3. In column (d) show the net gain or net loss realized on each debt reacquisition as computed in accordance with General Instruction
17 of the Uniform Systems of Accounts.
4. Show loss amounts by enclosing the figures in parentheses.
5. Explain in a footnote any debits and credits other than amortization debited to Account 428.1, Amortization of Loss on Reacquired
Debt, or credited to Account 429.1, Amortization of Gain on Reacquired Debt-Credit.
Balance at
End of Year
(f)
Principal
of Debt
Reacquired
(c)
Net Gain or
Loss
(d)
Balance at
Beginning
of Year
(e)
1,729,720 1,938,329 3,937,500 45,000,00006/20/1991
Long Term Debt - Bonds 12.5% Debenture Maturity
Date 04/15/2010
1
2,030,855 2,141,128 2,426,000 20,000,00005/31/1998
Long Term Debt - Bonds 9.875% Debenture Maturity
Date 06/01/2020
2
3,721,690 1,401,000 30,000,00005/29/2001
Long Term Debt - Bonds 9.875% Debenture Maturity
Date 06/01/2020
3
1,346,178 3,833,500 85,000,00005/29/2001
Long Term Debt - Bonds 9.375% Debenture Maturity
Date 06/01/2020
4
8,828,443 4,079,457 11,598,000 180,000,000Total Account 189 5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
Page 260FERC FORM NO. 2 (12-96)
Unamortized Loss and Gain on Reacquired Debt (Accounts 189, 257) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Designation of
Long-Term Debt
(a)
Date
Reacquired
(b)
1. Report under separate subheadings for Unamortized Loss and Unamortized Gain on Reacquired Debt, details of gain and loss,
including maturity date, on reacquisition applicable to each class and series of long-term debt. If gain or loss resulted from a refunding
transaction, include also the maturity date of the new issue.
2. In column (c) show the principal amount of bonds or other long-term debt reacquired.
3. In column (d) show the net gain or net loss realized on each debt reacquisition as computed in accordance with General Instruction
17 of the Uniform Systems of Accounts.
4. Show loss amounts by enclosing the figures in parentheses.
5. Explain in a footnote any debits and credits other than amortization debited to Account 428.1, Amortization of Loss on Reacquired
Debt, or credited to Account 429.1, Amortization of Gain on Reacquired Debt-Credit.
Balance at
End of Year
(f)
Principal
of Debt
Reacquired
(c)
Net Gain or
Loss
(d)
Balance at
Beginning
of Year
(e)
39
40
Page 260FERC FORM NO. 2 (12-96)(continued)
Reconciliation of Reported Net Income with Taxable Income for Feder Income Taxes
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Details
(a)
1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal Income Tax accruals
and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on
Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate
clearly the nature of each reconciling amount.
2. If the utility is a member of a group that files consolidated Federal tax return, reconcile reported net income with taxable net income
as if a separate return were to be filed, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State
names of group members, tax assigned to each group member, and basis of allocation, assignments, or sharing of the consolidated tax
among the group members.
Amount
(b)
29,740,458Net Income for the Year (Page 116) 1
Reconciling Items for the Year 2
3
Taxable Income Not Reported on Books 4
182,100 Customer Contributions 5
6
7
182,100TOTAL 8
Deductions Recorded on Books Not Deducted for Return 9
14,311,201 Federal Income Tax 10
340,550 Additional Pension Accrual 11
778,994 Other 12
15,430,745TOTAL 13
Income Recorded on Books Not Included in Return 14
3,573,362 Subsidiary Net Income 15
16
17
3,573,362TOTAL 18
Deductions on Return Not Charged Against Book Income 19
12,223,280 Depreciation 20
82,082 Software Development 21
4,748,986 Bond Reacquisition Costs 22
4,293,987 Transcolorado Losses 23
24
25
21,348,335TOTAL 26
20,431,606Federal Tax Net Income 27
Show Computation of Tax: 28
Federal Taxable Income 20,431,606 29
Tax Rate .35 30
Current Tax 7,151,062 31
Deferred Fed Tax 7,199,147 32
Prior Period Adjs/Other (39,008) 33
Total Federal Income Tax 14,311,201 34
35
Page 261FERC FORM NO. 2 (12-96)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
1. Give details of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and
other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual or estimated amounts of such taxes are known, show the amounts in a
footnote and designate whether estimated or actual amounts.
2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes). Enter the amounts in both columns (d) and (e). The
balancing of this
page is not affected by the inclusion of these taxes.
3. Include in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b) amounts credited to the
portion of prepaid taxes charged to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts.
4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Kind of Tax
(See Instruction 5)
(a)
Balance at
Beg. of Year
Prepaid Taxes
(c)
Balance at
Beg. of Year
Taxes Accrued
(b)
Federal Tax 1
21,612FICA 2
3,474Federal Unemployment Insurance 3
( 476,573)Federal Income Tax 4
Federal Highway Tax 5
Federal Environmental Tax 6
( 451,487)Subtotal Total Federal Tax 7
State Tax 8
Colorado 9
1,664,455Income Tax 10
35Unemployment Insurance - 1997 11
( 37)Unemployment Insurance - 1998 12
209,460Property Tax - 2000 13
Property Tax - 2001 14
206,195Use Tax 15
2,080,108Subtotal Total Colorado Tax 16
Utah 17
( 178,818)Income Tax 18
( 8)Withholding Tax 19
83Unemployment Insurance - 1996 20
525Unemployment Insurance - 1997 21
( 416)Unemployment Insurance - 1998 22
( 122)Unemployment Insurance - 1999 23
597Unemployment Insurance - 2000 24
Unemployment Insurance - 2001 25
Property Tax - 2001 26
58,923Use Tax 27
( 119,236)Subtotal Total Utah State Tax 28
29
30
31
32
33
34
35
36
37
38
39
Page 262aFERC FORM NO. 2 (12-96)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Kind of Tax
(See Instruction 5)
(a)
Balance at
Beg. of Year
Prepaid Taxes
(c)
Balance at
Beg. of Year
Taxes Accrued
(b)
Wyoming 1
26Unemployment Insurance - 1997 2
( 794)Unemployment Insurance - 1998 3
( 654)Unemployment Insurance - 1999 4
( 37)Unemployment Insurance - 2000 5
Unemployment Insurance - 2001 6
468,961Property Tax - 2000 7
Property Tax - 2001 8
( 5,374)Use Tax 9
Special Fuel Tax 10
462,128Subtotal Total Wyoming Tax 11
Idaho 12
Income Tax 13
Subtotal Total Idaho Tax 14
New Mexico 15
Income Tax 16
( 393)Unemployment Insurance - 1998 17
( 1,706)Use Tax 18
( 2,099)Subtotal Total New Mexico Tax 19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
1,969,414TOTAL
Page 262a.1FERC FORM NO. 2 (12-96)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
1. Give details of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and
other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual or estimated amounts of such taxes are known, show the amounts in a
footnote and designate whether estimated or actual amounts.
2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes). Enter the amounts in both columns (d) and (e). The
balancing of this
page is not affected by the inclusion of these taxes.
3. Include in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b) amounts credited to the
portion of prepaid taxes charged to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts.
4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Other Income and
Deductions
(Account 408.2,
409.2)
(l)
Other Utility Dept.
(Account 408.1,
409.1)
(k)
Electric
(Account 408.1,
409.1)
(i)
Gas
(Account 408.1,
409.1)
(j)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
1
408,793 2
5,200 3
2,562,743 4,819,021 4
5
6
2,562,743 5,233,014 7
8
9
49,261 10
11
2 12
( 44,738) 13
190,654 14
15
195,179 16
17
213,990 241,402 18
19
20
21
22
23
24
1,294 25
1,204,795 26
211,326 27
213,990 1,658,817 28
29
30
31
32
33
34
35
36
37
38
39
Page 262bFERC FORM NO. 2 (12-96)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Other Income and
Deductions
(Account 408.2,
409.2)
(l)
Other Utility Dept.
(Account 408.1,
409.1)
(k)
Electric
(Account 408.1,
409.1)
(i)
Gas
(Account 408.1,
409.1)
(j)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
1
2
3
4
74 5
1,643 6
7
867,552 8
9
10
869,269 11
12
30 13
30 14
15
( 8,518) 16
17
18
( 8,518) 19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
2,776,733 7,947,791TOTAL
Page 262b.1FERC FORM NO. 2 (12-96)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
5. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (a).
6. Enter all adjustments of the accrued and prepaid tax accounts in column (f) and explain each adjustment in a footnote. Designate debit adjustments by parentheses.
7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing
authority.
8. Show in columns (i) thru (p) how the taxes accounts were distributed. Show both the utility department and number of account charged. For taxes charged to utility plant, show the
number of the appropriate balance sheet plant account or subaccount.
9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
10. Items under $250,000 may be grouped.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Balance at
End of Year
Prepaid Taxes
(Included in Acct 165)
(h)
Balance at
End of Year
Taxes Accrued
(Account 236)
(g)
Taxes Charged
During Year
(d)
Taxes Paid
During Year
(e)
Adjustments
(f)
1
26,839 657,806 663,033 2
2,843 8,832 8,201 3
144,505 6,760,686 7,381,764 4
5
6
174,187 7,427,324 8,052,998 7
8
9
2,869,502( 1,155,786) 49,261 10
35 11
( 35) 2 12
164,722( 44,738) 13
190,848 190,848 14
206,189 6 15
3,266,539( 991,058) 195,373 16
17
( 538,642) 815,216 455,392 18
64( 72) 19
( 83) 20
490( 35) 21
( 220) 196 22
( 492)( 20)( 390) 23
490( 138)( 245) 24
233 1,609 1,842 25
1,196,182 1,196,182 26
39,388 1,146,878 1,127,343 27
( 498,959) 3,159,925 2,780,202 28
29
30
31
32
33
34
35
36
37
38
39
Page 263aFERC FORM NO. 2 (12-96)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Balance at
End of Year
Prepaid Taxes
(Included in Acct 165)
(h)
Balance at
End of Year
Taxes Accrued
(Account 236)
(g)
Taxes Charged
During Year
(d)
Taxes Paid
During Year
(e)
Adjustments
(f)
1
724 698 2
( 221) 573 3
( 822)( 191)( 359) 4
822( 48) 811 5
362 1,281 1,643 6
468,961 7
475,588 475,588 951,176 8
( 3,094) 67,911 70,191 9
13 13 10
472,856 1,014,018 1,024,746 11
12
30 30 13
30 30 14
15
( 8,518)( 8,518) 16
393 17
( 1,706) 18
( 1,706)( 8,518)( 8,125) 19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
3,412,917 10,601,721 12,045,224TOTAL
Page 263a.1FERC FORM NO. 2 (12-96)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
5. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (a).
6. Enter all adjustments of the accrued and prepaid tax accounts in column (f) and explain each adjustment in a footnote. Designate debit adjustments by parentheses.
7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing
authority.
8. Show in columns (i) thru (p) how the taxes accounts were distributed. Show both the utility department and number of account charged. For taxes charged to utility plant, show the
number of the appropriate balance sheet plant account or subaccount.
9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
10. Items under $250,000 may be grouped.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Other
(p)
Adjustment to Ret.
Earnings
(Account 439)
(o)
Extraordinary Items
(Account 409.3)
(m)
Other Utility Opn.
Income
(Account 408.1,
409.1)
(n)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
1
254,240 2
3,001 3
4
5
6
257,241 7
8
9
10
11
12
13
194 14
15
194 16
17
18
19
( 83) 20
( 35) 21
196 22
( 390) 23
( 245) 24
548 25
( 8,613) 26
916,017 27
907,395 28
29
30
31
32
33
34
35
36
37
38
39
Page 263bFERC FORM NO. 2 (12-96)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Other
(p)
Adjustment to Ret.
Earnings
(Account 439)
(o)
Extraordinary Items
(Account 409.3)
(m)
Other Utility Opn.
Income
(Account 408.1,
409.1)
(n)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
1
698 2
573 3
( 359) 4
737 5
6
7
83,624 8
70,191 9
13 10
155,477 11
12
13
14
15
16
393 17
18
393 19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
1,320,700TOTAL
Page 263b.1FERC FORM NO. 2 (12-96)
Miscellaneous Current and Accrued Liabilities (Account 242)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Item
(a)
1. Describe and report the amount of other current and accrued liabilities at the end of year.
2. Minor items (less than $250,000) may be grouped under appropriate title.
Balance at
End of Year
(b)
Transportation Imbalances (242005) 1
159,644Director's Deferred Compensation 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
159,644Total 45
Page 268FERC FORM NO. 2 (12-96)
Other Deferred Credits (Account 253)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.Description of Other
Deferred Credits
(a)
Balance at
Beginning
of Year
(b)
1. Report below the details called for concerning other deferred credits.
2. For any deferred credit being amortized, show the period of amortization.
3. Minor items (less than $250,000) may be grouped by classes.
Balance at
End of Year
(f)
Debit
Contra
Account
(c)
Debit
Amount
(d)
Credits
(e)
Production Hold Accounts: 1
5,578,636 3,864,639232 2,131,052 417,055Retainage 2
3
131 16,500 16,500Security Deposits 4
5
78,982 96,552142 32,306 49,876Transportaion Imbalances 6
7
Accruals For Projects With Uncertain
Completion:
8
9
287,763 287,763Gas Storage Feasibility Study 10
97,897421.1 97,897Sunnyside Land 11
53,912 53,912GTC Project Accrual 12
416,102 416,102Southwest Wyoming Storage Project 13
91,829 91,829Well Bore Monitor Project 14
109,801 109,801Gas Storage Feasibility Study 15
16
17
18
441 441Property Tax Settlement 19
20
13,598,374 16,947,363186 ( 1) 3,348,988Fuel Gas Deferral 21
22
1,260,029 1,574,444232 1,012,568 1,326,983Other Accruals (including Rev. Credit) 23
24
Unapplied Receipts 25
26
( 2,764)( 2,764)Remittance Receipts 27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
6,214,383 4,149,509 22,580,895 20,516,021Total 45
Page 269FERC FORM NO. 2 (12-96)
Accumulated Deferred Income Taxes-Other Property (Account 282)
1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to property not subject to accelerated amortization.
2. For Other, include deferrals relating to other income and deductions.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Account Subdivisions
(a)
Amounts
Credited to
Account 411.1
(d)
Balance at
Beginning
of Year
(b)
Amounts
Debited to
Account 410.1
(c)
Account 282 1
Electric 2
3,210,970Gas 56,151,195 3
Other (Define) 4
4.01
4.02
4.03
4.04
4.05
3,210,970Total (Total of lines 2 thru 4) 56,151,195 5
Other (Specify) 6
6.01
6.02
6.03
6.04
6.05
3,210,970TOTAL Account 282 (Total of lines 5 thru 6.?) 56,151,195 7
Classification of TOTAL 8
3,041,291Federal Income Tax 53,100,224 9
169,679State Income Tax 3,050,971 10
Local Income Tax 11
Page 274FERC FORM NO. 2 (12-96)
Accumulated Deferred Income Taxes-Other Property (Account 282) (continued)
3. Add rows as necessary to report all data. When rows are added, the additional row numbers should follow in sequence, 4.01, 4.02 and 6.01, 6.02, etc. Use separate pages as
required.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Adjustments
Debits
Acct. No.
(g)
Changes during
Year
Amounts Debited
to Account 410.2
(e)
Changes during
Year
Amounts Credited
to Account 411.2
(f)
Adjustments
Debits
Amount
(h)
Adjustments
Credits
Account No.
(i)
Adjustments
Credits
Amount
(j)
Balance at
End of Year
(k)
1
2
59,343,314( 22,961)1823 4,110 3
4
4.01
4.02
4.03
4.04
4.05
59,343,314( 22,961) 4,110 5
6
6.01
6.02
6.03
6.04
6.05
59,343,314( 22,961) 4,110 7
8
56,118,554( 22,961) 9
3,224,760 4,110 10
11
Page 275FERC FORM NO. 2 (12-96)
Accumulated Deferred Income Taxes-Other (Account 283)
1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283.
2. For Other, include deferrals relating to other income and deductions.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Account Subdivisions
(a)
Amounts
Credited to
Account 411.1
(d)
Balance at
Beginning
of Year
(b)
Amounts
Debited to
Account 410.1
(c)
Account 283 1
Electric 2
1,277,572Gas 1,056,197 3
Other (Define) 4
4.01
4.02
4.03
4.04
4.05
4.06
4.07
4.08
4.09
4.10
4.11
4.12
4.13
4.14
4.15
4.16
4.17
4.18
4.19
4.20
4.21
4.22
4.23
4.24
4.25
4.26
4.27
4.28
4.29
4.30
4.31
4.32
4.33
4.34
4.35
4.36
4.37
4.38
4.39
4.40
4.41
4.42
4.43
Page 276FERC FORM NO. 2 (12-96)
Accumulated Deferred Income Taxes-Other (Account 283) (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Account Subdivisions
(a)
Amounts
Credited to
Account 411.1
(d)
Balance at
Beginning
of Year
(b)
Amounts
Debited to
Account 410.1
(c)
4.44
4.45
1,277,572Total (Total of lines 2 thru 4) 1,056,197 5
Other (Specify) 6
6.01
6.02
6.03
6.04
6.05
6.06
6.07
6.08
6.09
6.10
6.11
6.12
6.13
6.14
6.15
1,277,572TOTAL Account 283 (Total of lines 5 thru 1,056,197 7
Classification of TOTAL 8
1,208,514Federal Income Tax ( 5,432,875) 9
69,058State Income Tax 6,489,072 10
Local Income Tax 11
Page 276aFERC FORM NO. 2 (12-96)
Accumulated Deferred Income Taxes-Other (Account 283) (continued)
3. Provide in a footnote explanations for pages 276 and 277. Include amounts relating to insignificant items listed under Other.
4. Add additional rows as necessary to report all data. When rows are added, the additional row numbers should follow in sequence, 4.01, 4.02, and 6.01, 6.02, etc. Use separate
pages as required.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Adjustments
Debits
Acct. No.
(g)
Changes during
Year
Amounts Debited
to Account 410.2
(e)
Changes during
Year
Amounts Credited
to Account 411.2
(f)
Adjustments
Debits
Amount
(h)
Adjustments
Credits
Account No.
(i)
Adjustments
Credits
Amount
(j)
Balance at
End of Year
(k)
1
2
5,408,022( 13,485)1823 3,087,738 3
4
4.01
4.02
4.03
4.04
4.05
4.06
4.07
4.08
4.09
4.10
4.11
4.12
4.13
4.14
4.15
4.16
4.17
4.18
4.19
4.20
4.21
4.22
4.23
4.24
4.25
4.26
4.27
4.28
4.29
4.30
4.31
4.32
4.33
4.34
4.35
4.36
4.37
4.38
4.39
4.40
4.41
Page 277FERC FORM NO. 2 (12-96)
Accumulated Deferred Income Taxes-Other (Account 283) (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Adjustments
Debits
Acct. No.
(g)
Changes during
Year
Amounts Debited
to Account 410.2
(e)
Changes during
Year
Amounts Credited
to Account 411.2
(f)
Adjustments
Debits
Amount
(h)
Adjustments
Credits
Account No.
(i)
Adjustments
Credits
Amount
(j)
Balance at
End of Year
(k)
4.42
4.43
4.44
4.45
5,408,022( 13,485) 3,087,738 5
6
6.01
6.02
6.03
6.04
6.05
6.06
6.07
6.08
6.09
6.10
6.11
6.12
6.13
6.14
6.15
5,408,022( 13,485) 3,087,738 7
8
( 1,461,792)( 13,485) 2,776,054 9
6,869,814 311,684 10
11
Page 277aFERC FORM NO. 2 (12-96)
Other Regulatory Liabilities (Account 254)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.Description and Purpose of
Other Regulatory Liabilities
(a)
Balance at
Beginning
of Year
(b)
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.
Balance at
End of Year
(f)
DEBITS
Account
Credited
(c)
DEBITS
Amount
(d)
Credits
(e)
6,930 6,930Regulatory Liability FAS 109 1
975,794 2,255,610 1,279,816Regulatory Liability FAS 106 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
0 975,794 2,262,540 1,286,746Total 45
Page 278FERC FORM NO. 2 (12-96)
Gas Operating Revenues
1. Report below natural gas operating revenues for each prescribed account total. The amounts must be consistent with the detailed data on succeeding pages.
2. Revenues in columns (b) and (c) include transition costs from upstream pipelines.
3. Other Revenues in columns (f) and (g) include reservation charges received by the pipeline plus usage charges, less revenues reflected in columns (b) through (e). Include in
columns (f) and (g) revenues for Accounts 480-495.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Title of Account
(a)
Revenues for
GRI and ACA
Amount for
Current Year
(d)
Revenues for
Transition
Costs and
Take-or-Pay
Amount for
Current Year
(b)
Revenues for
Transition
Costs and
Take-or-Pay
Amount for
Previous Year
(c)
Revenues for
GRI and ACA
Amount for
Previous Year
(e)
480-484 Sales 1
485 Intracompany Transfers 2
487 Forfeited Discounts 3
488 Miscellaneous Service Revenues 4
489.1 Revenues from Transportation of Gas of Others
Through Gathering Facilities
5
2,971,490 2,248,378
489.2 Revenues from Transportation of Gas of Others
Through Transmission Facilities
6
489.3 Revenues from Transportation of Gas of Others
Through Distribution Facilities
7
65,671 78,279489.4 Revenues from Storing Gas of Others 8
490 Sales of Prod. Ext. from Natural Gas 9
491 Revenues from Natural Gas Proc. by Others 10
492 Incidental Gasoline and Oil Sales 11
493 Rent from Gas Property 12
494 Interdepartmental Rents 13
495 Other Gas Revenues 14
3,037,161 2,326,657Subtotal: 15
496 (Less) Provision for Rate Refunds 16
3,037,161 2,326,657TOTAL: 17
Page 300FERC FORM NO. 2 (12-96)
Gas Operating Revenues
4. If increases or decreases from previous year are not derived from previously reported figures, explain any inconsistencies in a footnote.
5. On Page 108, include information on major changes during the year, new service, and important rate increases or decreases.
6. Report the revenue from transportation services that are bundled with storage services as transportation service revenue.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Dekatherm of
Natural Gas
Amount for
Current Year
(j)
Total
Operating
Revenues
Amount for
Current Year
(h)
Total
Operating
Revenues
Amount for
Previous Year
(i)
Dekatherm of
Natural Gas
Amount for
Previous Year
(k)
Other
Revenues
Amount for
Previous Year
(g)
Other
Revenues
Amount for
Current Year
(f)
480-484 Sales 1
485 Intracompany Transfers 2
487 Forfeited Discounts 3
488 Miscellaneous Service Revenues 4
489.1 Revenues from Transportation of Gas of Others
Through Gathering Facilities
5
312,760,704
489.2 Revenues from Transportation of Gas of Others
Through Transmission Facilities 74,753,640 275,246,971 72,546,575 77,002,018 69,575,085
6
489.3 Revenues from Transportation of Gas of Others
Through Distribution Facilities
7
131,765,496489.4 Revenues from Storing Gas of Others 39,712,849 137,166,763 39,649,908 39,791,128 39,584,237 8
490 Sales of Prod. Ext. from Natural Gas 9
491 Revenues from Natural Gas Proc. by Others 10
492 Incidental Gasoline and Oil Sales 1,042,481 1,001,044 1,042,481 1,001,044 11
493 Rent from Gas Property 80,780 80,780 80,780 80,780 12
494 Interdepartmental Rents 13
495 Other Gas Revenues 390,392 299,133 390,392 299,133 14
444,526,200Subtotal: 115,980,142 412,413,734 113,577,440 118,306,799 110,540,279 15
496 (Less) Provision for Rate Refunds 16
444,526,200TOTAL: 115,980,142 412,413,734 113,577,440 118,306,799 110,540,279 17
Page 301FERC FORM NO. 2 (12-96)
Revenues from Transporation of Gas of Others Through Gathering Facilities (Account 489.1)
1. Report revenues and Dth of gas delivered through gathering facilities by zone of receipt (i.e. state in which gas enters respondent's system).
2. Revenues for penalties including penalties for unauthorized overruns must be reported on page 308.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Rate Schedule and
Zone of Receipt
(a)
Revenues for
GRI and ACA
Amount for
Current Year
(d)
Revenues for
Transition
Costs and
Take-or-Pay
Amount for
Current Year
(b)
Revenues for
Transaction
Costs and
Take-or-Pay
Amount for
Previous Year
(c)
Revenues for
GRI and ACA
Amount for
Current Year
(d)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
Page 302FERC FORM NO. 2 (12-96)
Revenues from Transporation of Gas of Others Through Gathering Facilities (Account 489.1)
3. Other Revenues in columns (f) and (g) include reservation charges received by the pipeline plus usage charges, less revenues reflected in columns (b) through (e).
4. Delivered Dth of gas must not be adjusted for discounting.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Dekatherm of
Natural Gas
Amount for
Current Year
(j)
Total
Operating
Revenues
Amount for
Current Year
(h)
Total
Operating
Revenues
Amount for
Previous Year
(i)
Dekatherm of
Natural Gas
Amount for
Previous Year
(k)
Other
Revenues
Amount for
Current Year
(f)
Other
Revenues
Amount for
Previous Year
(g)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
Page 303FERC FORM NO. 2 (12-96)
Revenues from Transportation of Gas of Others Through Transmission Facilities (Account 489.2)
1. Report revenues and Dth of gas delivered by Zone of Delivery by Rate Schedule. Total by Zone of Delivery and for all zones. If respondent does not have separate zones, provide
totals by rate schedule.
2. Revenues for penalties including penalties for unauthorized overruns must be reported on page 308.
3. Other Revenues in columns (f) and (g) include reservation charges received by the pipeline plus usage charges for transportation and hub services, less revenues reflected in
columns (b) through (e).
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Zone of Delivery,
Rate Schedule
(a)
Revenues for
GRI and ACA
Amount for
Current Year
(d)
Revenues for
Transition
Costs and
Take-or-Pay
Amount for
Current Year
(b)
Revenues for
Transition
Costs and
Take-or-Pay
Amount for
Previous Year
(c)
Revenues for
GRI and ACA
Amount for
Previous Year
(e)
1
Firm T-1 2,971,490 2,248,378 2
3
No-Notice - NNT 4
5
Interruptible T-2 6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
Page 304FERC FORM NO. 2 (12-96)
Revenues from Transportation of Gas of Others Through Transmission Facilities (Account 489.2)
4. Delivered Dth of gas must not be adjusted for discounting.
5. Each incremental rate schedule and each individually certificated rate schedule must be separately reported.
6. Where transportation services are bundled with storage services, report total revenues but only transportation Dth.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Dekatherm of
Natural Gas
Amount for
Current Year
(j)
Total
Operating
Revenues
Amount for
Current Year
(h)
Total
Operating
Revenues
Amount for
Previous Year
(i)
Dekatherm of
Natural Gas
Amount for
Previous Year
(k)
Other
Revenues
Amount for
Current Year
(f)
Other
Revenues
Amount for
Previous Year
(g)
1
252,355,641 293,892,904 66,135,571 73,565,005 66,135,571 71,316,627 2
3
2,118,945 2,118,945 2,118,945 2,118,945 4
5
22,891,330 18,867,800 1,320,569 1,318,068 1,320,569 1,318,068 6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
Page 305FERC FORM NO. 2 (12-96)
Revenues from Storing Gas of Others (Account 489.4)
1. Report revenues and Dth of gas withdrawn from storage by Rate Schedule and in total.
2. Revenues for penalties including penalties for unauthorized overruns must be reported on page 308.
3. Other revenues in columns (f) and (g) include reservation charges, deliverability charges, injection and withdrawal charges, less revenues reflected in columns (b) through (e).
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Rate Schedule
(a)
Revenues for
GRI and ACA
Amount for
Current Year
(d)
Revenues for
Transition
Costs and
Take-or-Pay
Amount for
Current Year
(b)
Revenues for
Transaction
Costs and
Take-or-Pay
Amount for
Previous Year
(c)
Revenues for
GRI and ACA
Amount for
Previous Year
(e)
FSS - Clay Basin Storage 65,671 78,279 1
PKS - Peaking Storage 2
ISS - Clay Basin Storage 3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
Page 306FERC FORM NO. 2 (12-96)
Revenues from Storing Gas of Others (Account 489.4)
4. Dth of gas withdrawn from storage must not be adjusted for discounting.
5. Where transportation services are bundled with storage services, report only Dth withdrawn from storage.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Dekatherm of
Natural Gas
Amount for
Current Year
(j)
Total
Operating
Revenues
Amount for
Current Year
(h)
Total
Operating
Revenues
Amount for
Previous Year
(i)
Dekatherm of
Natural Gas
Amount for
Previous Year
(k)
Other
Revenues
Amount for
Current Year
(f)
Other
Revenues
Amount for
Previous Year
(g)
124,617,586 120,426,196 32,827,131 33,009,558 32,761,460 32,931,278 1
3,477,223 4,821,853 6,501,431 6,553,495 6,501,431 6,553,495 2
9,071,954 6,517,447 321,346 228,076 321,346 228,076 3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
Page 307FERC FORM NO. 2 (12-96)
Other Gas Revenues (Account 495)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Description of Transaction
(a)
1. For transactions with annual revenues of $250,000 or more, describe, for each transaction, commissions on sales of distributions
of gas of others, compensation for minor or incidental services provided for others, penalties, profit or loss on sales of material and
supplies, sales of steam, water, or electricity, miscellaneous royalties, revenues from dehydration, other processing of gas of others,
and gains on settlements of imbalance receivables. Separately report revenues from cash-out penalties.
Revenues
(in dollars)
(b)
148,484Imbalance and Misc Revenue 1
134,500Aircraft Revenues 2
79,285Revenue From Contract Work For Others 3
22,863Gasoline System Revenues 4
2,860Misc. Revenues 5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
387,992Total 25
Page 308FERC FORM NO. 2 (12-96)
Gas Operation and Maintenance Expenses
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
0 01. PRODUCTION EXPENSES 1
0 0A. Manufactured Gas Production 2
0 0 Manufactured Gas Production (Submit Supplemental Statement) 3
0 0B. Natural Gas Production 4
0 0B1. Natural Gas Production and Gathering 5
0 0 Operation 6
0 0 750 Operation Supervision and Engineering 7
0 0 751 Production Maps and Records 8
0 0 752 Gas Well Expenses 9
0 0 753 Field Lines Expenses 10
0 0 754 Field Compressor Station Expenses 11
0 0 755 Field Compressor Station Fuel and Power 12
0 0 756 Field Measuring and Regulating Station Expenses 13
0 0 757 Purification Expenses 14
0 0 758 Gas Well Royalties 15
0 0 759 Other Expenses 16
0 0 760 Rents 17
0 0 TOTAL Operation (Total of lines 7 thru 17) 18
0 0 Maintenance 19
0 0 761 Maintenance Supervision and Engineering 20
0 0 762 Maintenance of Structures and Improvements 21
0 0 763 Maintenance of Producing Gas Wells 22
0 0 764 Maintenance of Field Lines 23
0 0 765 Maintenance of Field Compressor Station Equipment 24
0 0 766 Maintenance of Field Measuring and Regulating Station Equipment 25
0 0 767 Maintenance of Purification Equipment 26
0 0 768 Maintenance of Drilling and Cleaning Equipment 27
0 0 769 Maintenance of Other Equipment 28
0 0TOTAL Maintenance (Total of lines 20 thru 28) 29
0 0TOTAL Natural Gas Production and Gathering (Total of lines 18 and 29) 30
Page 317FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
0 0B2. Products Extraction 31
0 0 Operation 32
0 0 770 Operation Supervision and Engineering 33
0 0 771 Operation Labor 34
0 0 772 Gas Shrinkage 35
0 0 773 Fuel 36
0 0 774 Power 37
0 0 775 Materials 38
0 0 776 Operation Supplies and Expenses 39
0 0 777 Gas Processed by Others 40
0 0 778 Royalties on Products Extracted 41
0 0 779 Marketing Expenses 42
0 0 780 Products Purchased for Resale 43
0 0 781 Variation in Products Inventory 44
0 0(Less) 782 Extracted Products Used by the Utility-Credit 45
0 0 783 Rents 46
0 0TOTAL Operation (Total of lines 33 thru 46) 47
0 0 Maintenance 48
0 0 784 Maintenance Supervision and Engineering 49
0 0 785 Maintenance of Structures and Improvements 50
0 0 786 Maintenance of Extraction and Refining Equipment 51
0 0 787 Maintenance of Pipe Lines 52
0 0 788 Maintenance of Extracted Products Storage Equipment 53
0 0 789 Maintenance of Compressor Equipment 54
0 0 790 Maintenance of Gas Measuring and Regulating Equipment 55
0 0 791 Maintenance of Other Equipment 56
0 0TOTAL Maintenance (Total of lines 49 thru 56) 57
0 0TOTAL Products Extraction (Total of lines 47 and 57) 58
Page 318FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
0 0C. Exploration and Development 59
0 0 Operation 60
0 0 795 Delay Rentals 61
0 0 796 Nonproductive Well Drilling 62
0 0 797 Abandoned Leases 63
0 0 798 Other Exploration 64
0 0TOTAL Exploration and Development (Total of lines 61 thru 64) 65
0 0D. Other Gas Supply Expenses 66
0 0 Operation 67
0 0 800 Natural Gas Well Head Purchases 68
0 0 800.1 Natural Gas Well Head Purchases, Intracompany Transfers 69
0 0 801 Natural Gas Field Line Purchases 70
0 0 802 Natural Gas Gasoline Plant Outlet Purchases 71
0 0 803 Natural Gas Transmission Line Purchases 72
0 0 804 Natural Gas City Gate Purchases 73
0 0 804.1 Liquefied Natural Gas Purchases 74
0 0 805 Other Gas Purchases 75
0 0 (Less) 805.1 Purchases Gas Cost Adjustments 76
0 0TOTAL Purchased Gas (Total of lines 68 thru 76) 77
1,337,342 1,030,433 806 Exchange Gas 78
0 0 Purchased Gas Expenses 79
0 0 807.1 Well Expense-Purchased Gas 80
0 0 807.2 Operation of Purchased Gas Measuring Stations 81
0 0 807.3 Maintenance of Purchased Gas Measuring Stations 82
0 0 807.4 Purchased Gas Calculations Expenses 83
0 0 807.5 Other Purchased Gas Expenses 84
0 0TOTAL Purchased Gas Expenses (Total of lines 80 thru 84) 85
Page 319FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
3,476,128 2,425,177 808.1 Gas Withdrawn from Storage-Debit 86
4,813,500 3,455,610 (Less) 808.2 Gas Delivered to Storage-Credit 87
0 0 809.1 Withdrawals of Liquefied Natural Gas for Processing-Debit 88
0 0 (Less) 809.2 Deliveries of Natural Gas for Processing-Credit 89
0 0 Gas used in Utility Operation-Credit 90
5,345,472 17,985,008 810 Gas Used for Compressor Station Fuel-Credit 91
0 0 811 Gas Used for Products Extraction-Credit 92
175,712 243,562 812 Gas Used for Other Utility Operations-Credit 93
5,521,184 18,228,570TOTAL Gas Used in Utility Operations-Credit (Total of lines 91 thru 93) 94
( 3,412,192) 5,700,085 813 Other Gas Supply Expenses 95
( 8,933,406)( 12,528,485)TOTAL Other Gas Supply Exp. (Total of lines 77,78,85,86 thru 89,94,95) 96
( 8,933,406)( 12,528,485)TOTAL Production Expenses (Total of lines 3, 30, 58, 65, and 96) 97
0 02. NATURAL GAS STORAGE, TERMINALING AND PROCESSING EXPENSES 98
0 0A. Underground Storage Expenses 99
0 0 Operation100
( 16,673) 9,183 814 Operation Supervision and Engineering101
0 0 815 Maps and Records102
279,247 111,211 816 Wells Expenses103
33,674 9,333 817 Lines Expense104
513,794 507,245 818 Compressor Station Expenses105
0 0 819 Compressor Station Fuel and Power106
28,032 18,628 820 Measuring and Regulating Station Expenses107
134,659 176,841 821 Purification Expenses108
0 0 822 Exploration and Development109
0 0 823 Gas Losses110
( 14,177)( 12,592) 824 Other Expenses111
628,056 530,861 825 Storage Well Royalties112
1,774 1,774 826 Rents113
1,588,386 1,352,484TOTAL Operation (Total of lines of 101 thru 113)114
Page 320FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
0 0 Maintenance115
0 0 830 Maintenance Supervision and Engineering116
0 88 831 Maintenance of Structures and Improvements117
55,621 92,473 832 Maintenance of Reservoirs and Wells118
22,913 18,764 833 Maintenance of Lines119
1,140,223 1,401,074 834 Maintenance of Compressor Station Equipment120
141,503 106,897 835 Maintenance of Measuring and Regulating Station Equipment121
105,219 43,578 836 Maintenance of Purification Equipment122
5,693 8,520 837 Maintenance of Other Equipment123
1,471,172 1,671,394TOTAL Maintenance (Total of lines 116 thru 123)124
3,059,558 3,023,878TOTAL Underground Storage Expenses (Total of lines 114 and 124)125
0 0B. Other Storage Expenses126
0 0 Operation127
0 0 840 Operation Supervision and Engineering128
0 0 841 Operation Labor and Expenses129
0 0 842 Rents130
0 0 842.1 Fuel131
0 0 842.2 Power132
0 0 842.3 Gas Losses133
0 0TOTAL Operation (Total of lines 128 thru 133)134
0 0 Maintenance135
0 0 843.1 Maintenance Supervision and Engineering136
0 0 843.2 Maintenance of Structures137
0 0 843.3 Maintenance of Gas Holders138
0 0 843.4 Maintenance of Purification Equipment139
0 0 843.5 Maintenance of Liquefaction Equipment140
0 0 843.6 Maintenance of Vaporizing Equipment141
0 0 843.7 Maintenance of Compressor Equipment142
0 0 843.8 Maintenance of Measuring and Regulating Equipment143
0 0 843.9 Maintenance of Other Equipment144
0 0TOTAL Maintenance (Total of lines 136 thru 144)145
0 0TOTAL Other Storage Expenses (Total of lines 134 and 145)146
Page 321FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
0 0C. Liquefied Natural Gas Terminaling and Processing Expenses147
0 0 Operation148
0 0 844.1 Operation Supervision and Engineering149
0 0 844.2 LNG Processing Terminal Labor and Expenses150
0 0 844.3 Liquefaction Processing Labor and Expenses151
0 0 844.4 Liquefaction Transportation Labor and Expenses152
0 0 844.5 Measuring and Regulating Labor and Expenses153
0 0 844.6 Compressor Station Labor and Expenses154
0 0 844.7 Communication System Expenses155
0 0 844.8 System Control and Load Dispatching156
0 0 845.1 Fuel157
0 0 845.2 Power158
0 0 845.3 Rents159
0 0 845.4 Demurrage Charges160
0 0 (less) 845.5 Wharfage Receipts-Credit161
0 0 845.6 Processing Liquefied or Vaporized Gas by Others162
0 0 846.1 Gas Losses163
0 0 846.2 Other Expenses164
0 0TOTAL Operation (Total of lines 149 thru 164)165
0 0 Maintenance166
0 0 847.1 Maintenance Supervision and Engineering167
0 0 847.2 Maintenance of Structures and Improvements168
0 0 847.3 Maintenance of LNG Processing Terminal Equipment169
0 0 847.4 Maintenance of LNG Transportation Equipment170
0 0 847.5 Maintenance of Measuring and Regulating Equipment171
0 0 847.6 Maintenance of Compressor Station Equipment172
0 0 847.7 Maintenance of Communication Equipment173
0 0 847.8 Maintenance of Other Equipment174
0 0TOTAL Maintenance (Total of lines 167 thru 174)175
0 0TOTAL Liquefied Nat Gas Terminaling and Proc Exp (Total of lines 165 and 175)176
3,059,558 3,023,878TOTAL Natural Gas Storage (Total of lines 125, 146, and 176)177
Page 322FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
0 03. TRANSMISSION EXPENSES178
0 0 Operation179
2,331,808 3,205,589 850 Operation Supervision and Engineering180
522,296 364,076 851 System Control and Load Dispatching181
( 75,823)( 76,179) 852 Communication System Expenses182
1,177,596 1,024,803 853 Compressor Station Labor and Expenses183
8,178,566 11,040,681 854 Gas for Compressor Station Fuel184
0 0 855 Other Fuel and Power for Compressor Stations185
218,068 294,306 856 Mains Expenses186
513,088 774,034 857 Measuring and Regulating Station Expenses187
256,578 388,393 858 Transmission and Compression of Gas by Others188
2,773,432 3,474,965 859 Other Expenses189
37,158 33,874 860 Rents190
15,932,767 20,524,542TOTAL Operation (Total of lines 180 thru 190)191
0 0 Maintenance192
418,474 176,779 861 Maintenance Supervision and Engineering193
175 0 862 Maintenance of Structures and Improvements194
339,778 721,273 863 Maintenance of Mains195
1,157,680 1,166,706 864 Maintenance of Compressor Station Equipment196
879,980 845,566 865 Maintenance of Measuring and Regulating Station Equipment197
0 0 866 Maintenance of Communication Equipment198
10,955 86,675 867 Maintenance of Other Equipment199
2,807,042 2,996,999TOTAL Maintenance (Total of lines 193 thru 199)200
18,739,809 23,521,541TOTAL Transmission Expenses (Total of lines 191 and 200)201
0 04. DISTRIBUTION EXPENSES202
0 0 Operation203
0 0 870 Operation Supervision and Engineering204
0 0 871 Distribution Load Dispatching205
0 0 872 Compressor Station Labor and Expenses206
0 0 873 Compressor Station Fuel and Power207
Page 323FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
0 0 874 Mains and Services Expenses208
0 0 875 Measuring and Regulating Station Expenses-General209
0 0 876 Measuring and Regulating Station Expenses-Industrial210
0 0 877 Measuring and Regulating Station Expenses-City Gas Check Station211
0 0 878 Meter and House Regulator Expenses212
0 0 879 Customer Installations Expenses213
0 0 880 Other Expenses214
0 0 881 Rents215
0 0TOTAL Operation (Total of lines 204 thru 215)216
0 0 Maintenance217
0 0 885 Maintenance Supervision and Engineering218
0 0 886 Maintenance of Structures and Improvements219
0 0 887 Maintenance of Mains220
0 0 888 Maintenance of Compressor Station Equipment221
0 0 889 Maintenance of Measuring and Regulating Station Equipment-General222
0 0 890 Maintenance of Meas. and Reg. Station Equipment-Industrial223
0 0 891 Maintenance of Meas. and Reg. Station Equip-City Gate Check Station224
0 0 892 Maintenance of Services225
0 0 893 Maintenance of Meters and House Regulators226
0 0 894 Maintenance of Other Equipment227
0 0TOTAL Maintenance (Total of lines 218 thru 227)228
0 0TOTAL Distribution Expenses (Total of lines 216 and 228)229
0 05. CUSTOMER ACCOUNTS EXPENSES230
0 0 Operation231
0 0 901 Supervision232
0 0 902 Meter Reading Expenses233
0 0 903 Customer Records and Collection Expenses234
Page 324FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
0 0 904 Uncollectible Accounts235
0 0 905 Miscellaneous Customer Accounts Expenses236
0 0TOTAL Customer Accounts Expenses (Total of lines 232 thru 236)237
0 06. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES238
0 0 Operation239
0 0 907 Supervision240
0 0 908 Customer Assistance Expenses241
0 0 909 Informational and Instructional Expenses242
0 0 910 Miscellaneous Customer Service and Informational Expenses243
0 0TOTAL Customer Service and Information Expenses (Total of lines 240 thru 243)244
0 07. SALES EXPENSES245
0 0 Operation246
0 0 911 Supervision247
0 0 912 Demonstrating and Selling Expenses248
0 0 913 Advertising Expenses249
0 0 916 Miscellaneous Sales Expenses250
0 0TOTAL Sales Expenses (Total of lines 247 thru 250)251
0 08. ADMINISTRATIVE AND GENERAL EXPENSES252
0 0 Operation253
1,688,106 2,168,265 920 Administrative and General Salaries254
20,744,071 18,952,389 921 Office Supplies and Expenses255
2,055,424 2,032,379 (Less) 922 Administrative Expenses Transferred-Credit256
2,757,948 5,409,894 923 Outside Services Employed257
251,896 352,656 924 Property Insurance258
63,010 38,076 925 Injuries and Damages259
1,853,039 3,107,545 926 Employee Pensions and Benefits260
0 0 927 Franchise Requirements261
780,737 627,033 928 Regulatory Commission Expenses262
0 0 (Less) 929 Duplicate Charges-Credit263
6,189 0 930.1General Advertising Expenses264
2,555,174 1,661,261 930.2Miscellaneous General Expenses265
694,718 699,795 931 Rents266
29,339,464 30,984,535TOTAL Operation (Total of lines 254 thru 266)267
0 0 Maintenance268
0 0 932 Maintenance of General Plant269
29,339,464 30,984,535TOTAL Administrative and General Expenses (Total of lines 267 and 269)270
42,205,425 45,001,469TOTAL Gas O&M Expenses (Total of lines 97,177,201,229,237,244,251, and 270)271
Page 325FERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
Schedule Page: 317 Line No.: 101 Column: b
GAS OPERATION AND MAINTENANCE EXPENSE
In order to comply with a FERC audit exception, the operation and maintenance expenses on pages 317 to 332
are restated to reflect employee pension and benefits in Account 926. Respondant's ledger, includes pension
and benefit expenses as cleared to each individual account on the basis of labor charges to the account to more
accurately associate cost with the function being served. The unadjusted numbers along with the adjustments
are stated below.
Questar Pipeline Company
Form 2 - Pages 320 to 325
Adjustment per FERC Audit
Total per Books Adjustment Form 2
Other Gas Supply Expense
Operation
800 0 0
801 0 0
803 0 0
0 0 0
Purchased Gas Expenses
806 1,030,433 1,030,433
808 -1,030,433 -1,030,433
810 -17,985,008 -17,985,008
812 -243,562 -243,562
813 5,700,085 5,700,085
-12,528,485 0 -12,528,485
Total Gas Supply Expenses -12,528,485 0 -12,528,485
Total Production Expenses -12,528,485 0 -12,528,485
Underground Storage Expense
Operation
814 12,038 2,855 9,183
815 0 0
816 156,000 44,789 111,211
817 11,846 2,513 9,333
818 571,970 64,725 507,245
819 0 0
820 24,675 6,047 18,628
821 236,729 59,888 176,841
822 0 0
823 0 0
824 -12,592 -12,592
825 530,861 530,861
826 1,774 1,774
Total Operation 1,533,301 180,817 1,352,484
Maintenance
830 0 0 0
831 88 88
832 106,413 13,940 92,473
833 25,000 6,236 18,764
FERC FORM NO. 2 (12-96)Page 552
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
834 1,710,486 309,412 1,401,074
835 146,072 39,175 106,897
836 56,680 13,102 43,578
837 12,332 3,812 8,520
Total Maintenance 2,057,071 385,677 1,671,394
Total Underground Storage Expenses 3,590,372 566,494 3,023,878
Total Natural Gas Storage 3,590,372 566,494 3,023,878
Transmission Expenses
Operation
850 4,135,339 929,750 3,205,589
851 364,076 0 364,076
852 -76,179 -76,179
853 1,157,365 132,562 1,024,803
854 11,040,681 11,040,681
856 352,275 57,969 294,306
857 908,850 134,816 774,034
858 388,393 388,393
859 3,486,328 11,363 3,474,965
860 33,874 33,874
Total Operation 21,791,002 1,266,460 20,524,542
Maintenance
861 253,600 76,821 176,779
862 0 0
863 903,800 182,527 721,273
864 1,414,517 247,811 1,166,706
865 1,046,316 200,750 845,566
866 0 0
867 106,524 19,849 86,675
Total Maintenance 3,724,757 727,758 2,996,999
Total Transmission Expenses 25,515,759 1,994,218 23,521,541
Administrative and General Expenses
Operation
920 2,168,265 2,168,265
921 18,952,389 18,952,389
922 -2,032,379 -2,032,379
923 5,409,894 5,409,894
924 352,656 352,656
925 59,370 21,294 38,076
926 525,539 -2,582,006 3,107,545
927 0 0
928 627,033 627,033
929 0 0
930.1 0 0
930.2 1,661,261 1,661,261
931 699,795 699,795
Total Operation 28,423,823 -2,560,712 30,984,535
Maintenance
935 0 0
Total Maintenance 0 0 0
Total Administrative and General Expenses 28,423,823 -2,560,712 30,984,535
Total Gas O. and M. Exp 45,001,469 0 45,001,469
FERC FORM NO. 2 (12-96)Page 552.1
Exchange and Imbalance Transactions
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Line
No.Zone/Rate Schedule
(a)
Gas Received
from Others
Amount
(b)
1. Report below details by zone and rate schedule concerning the gas quantities and related dollar amount of imbalances associated with system balancing and
no-notice service. Also, report certificated natural gas exchange transactions during the year. Provide subtotals for imbalance and no-notice quantities for exchanges.
If respondent does not have separate zones, provide totals by rate schedule. Minor exchange transactions (less than 100,000 Dth) may be grouped.
Gas Delivered
to Others
Dth
(e)
Gas Received
from Others
Dth
(c)
Gas Delivered
to Others
Amount
(d)
1
Balance Gas Imbalance 1,990,304 4,774,261 1,987,051 4,766,458 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
1,990,304 4,774,261 1,987,051 4,766,458Total 25
Page 328FERC FORM NO. 2 (12-96)
Gas Used in Utility Operations
1. Report below details of credits during the year to Accounts 810, 811, and 812.
2. If any natural gas was used by the respondent for which a charge was not made to the appropriate operating expense or other account, list separately in column (c) the Dth of gas
used, omitting entries in column (d).
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Purpose for Which Gas
Was Used
(a)
Natural Gas
Amount of
Credit
(in dollars)
(d)
Account
Charged
(b)
Natural Gas
Gas Used
Dth
(c)
Natural Gas
Amount of
Credit
(in dollars)
(d)
Natural Gas
Amount of
Credit
(in dollars)
(d)
( 11,040,681)( 2,928,993)854810 Gas Used for Compressor Station Fuel - Credit 1
811 Gas Used for Products Extraction - Credit 2
( 6,944,326)( 2,448,881)859/183
Gas Shrinkage and Other Usage in Respondent's
Own Processing
3
Gas Shrinkage, etc. for Respondent's Gas
Processed by Others
4
( 243,562)( 87,129)859/184
812 Gas Used for Other Utility Operations - Credit
(Report separately for each principal use. Group
minor uses.)
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
( 18,228,569)( 5,465,003)25 Total
Page 331FERC FORM NO. 2 (12-96)
Transmission and Compression of Gas by Others (Account 858)
1. Report below details concerning gas transported or compressed for respondent by others equalling more than 1,000,000 Dth and amounts of payments for such services during the
year. Minor items (less than 1,000,000) Dth may be grouped. Also, include in column (c) amounts paid as transition costs to an upstream pipeline.
2. In column (a) give name of companies, points of delivery and receipt of gas. Designate points of delivery and receipt so that they can be identified readily on a map of respondent's
pipeline system.
3. Designate associated companies with an asterisk in column (b).
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Name of Company and Description of Service Performed
(a)
Dth of Gas
Delivered
(d)
*
(b)
Amount of
Payment
(in dollars)
(c)
75,888 147,982Canyon Creek Compression Company 1
13,610,058 238,176Overthrust Pipeline Company 2
2,235Miscellaneous 3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
13,685,946 388,39325 Total
Page 332FERC FORM NO. 2 (12-96)
Other Gas Supply Expenses (Account 813)
1. Report other gas supply expenses by descriptive titles that clearly indicate the nature of such expenses. Show maintenance expenses, revaluation of monthly encroachments
recorded in Account 117.4, and losses on settlements of imbalances and gas losses not associated with storage separately. Indicate the functional classification and purpose of property
to which any expenses relate. List separately items of $250,000 or more.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description
(a)
Amount
(in dollars)
(b)
5,700,085Gas Lost and Unaccounted For 1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
5,700,08525 Total
Page 334FERC FORM NO. 2 (12-96)
Miscellaneous General Expenses (Account 930.2)
1. Provide the information requested below on miscellaneous general expenses.
2. For Other Expenses, show the (a) purpose, (b) recipient and (c) amount of such items. List separately amounts of $250,000 or more however, amounts less than $250,000 may be
grouped if the number of items of so grouped is shown.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description
(a)
Amount
(in dollars)
(b)
Industry association dues. 1
Experimental and general research expenses. 2
1,571,937a. Gas Research Institute (GRI)
b. Other
Publishing and distributing information and reports to stockholders, trustee, registrar, and transfer 3
agent fees and expenses, and other expenses of servicing outstanding securities of the respondent
1,623Other expenses 4
26,603Administrative and General Expenses - Questar Corporation 5
14,400Administrative and General Expenses - Questar Regulated Services 6
( 33,200)Directors Fees and Expenses 7
79,898Directors Deferred Stock Adjustment 8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
1,661,26125 Total
Page 335FERC FORM NO. 2 (12-96)
Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 404.1, 404.2, 404.3, 405) (Except Amortization of
Acquisition Adjustments)
1. Report in Section A the amounts of depreciation expense, depletion and amortization for the accounts indicated and classified according to the plant functional groups shown.
2. Report in Section B, column (b) all depreciable or amortizable plant balances to which rates are applied and show a composite total. (If more desirable, report by plant account,
subaccount or functional classifications other than those pre-printed in column (a). Indicate in a footnote the manner in which column (b) balances are
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Functional Classification
(a)
Amortization of
Underground Storage
Land and Land
Rights
(Account 404.2)
(d)
Depreciation
Expense
(Account 403)
(b)
Amortization and
Depletion of
Producing Natural
Gas Land and Land
Rights
(Account 404.1)
(c)
Section A. Summary of Depreciation, Depletion, and Amortization Charges
1 Intangible plant
2 Production plant, manufactured gas
3 Production and gathering plant, natural gas
4 Products extraction plant
2,509 3,231,646 5 Underground gas storage plant
6 Other storage plant
7 Base load LNG terminaling and processing plant
11,215,827 8 Transmission plant
9 Distribution plant
387,971 10 General plant
11 Common plant-gas
2,509 14,835,444 12 TOTAL
Page 336FERC FORM NO. 2 (12-96)
Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 404.1, 404.2, 404.3, 405) (Except Amortization of
Acquisition Adjustments) (continued)
obtained. If average balances are used, state the method of averaging used. For column (c) report available information for each plant functional classification listed in column (a). If
composite depreciation accounting is used, report available information called for in columns (b) and (c) on this basis. Where the unit-of-production method is used to determine
depreciation charges, show in a footnote any revisions made to estimated gas reserves.
3. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state in a footnote the amounts and nature of the
provisions and the plant items to which related.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Total
(b to f)
(g)
Amortization of
Other Limited-term
Gas Plant
(Account 404.3)
(e)
Amortization of
Other Gas Plant
(Account 405)
(f)
Functional Classification
(a)
Section A. Summary of Depreciation, Depletion, and Amortization Charges
( 633,484)( 633,484) 1 Intangible plant
2 Production plant, manufactured gas
3 Production and gathering plant, natural gas
4 Products extraction plant
3,234,155 5 Underground gas storage plant
6 Other storage plant
7 Base load LNG terminaling and processing plant
11,215,827 8 Transmission plant
9 Distribution plant
387,971 10 General plant
11 Common plant-gas
14,204,469( 633,484) 12 TOTAL
Page 337FERC FORM NO. 2 (12-96)
Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 404.1, 404.2, 404.3, 405) (Except Amortization of
Acquisition Adjustments) (continued)
4. Add rows as necessary to completely report all data. Number the additional rows in sequence as 2.01, 2.02, 3.01, 3.02, etc.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Applied Depreciation
or Amortization Rates
(percent)
(c)
Plant Bases
(in thousands)
(b)
Functional Classification
(a)
Section B. Factors Used in Estimating Depreciation Charges
Production and Gathering Plant 1
Offshore 2
2.01
2.02
2.03
Onshore 3
3.01
3.02
3.03
3.04
3.00 115,357Underground Gas Storage Plant 4
4.01
4.02
4.03
Transmission Plant 5
Offshore 6
6.01
6.02
6.03
3.00 425,220Onshore 7
7.01
7.02
7.03
7.04
0.00 25,606General Plant 8
8.01
8.02
8.03
8.04
8.05
8.06
8.07
8.08
8.09
8.10
8.11
8.12
8.13
8.14
8.15
20.00 6,364Intangible Plant (Account 404.3) 9
3.00 84Peaking Storage Leasehold (Account 404.2) 10
8.33 1,963Line 4.01 Underground Gas Storage - EFM 11
12
8.33 10,803Line 7.01 Transmission Plant - EFM 13
14
15
Page 338FERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
Schedule Page: 336 Line No.: 8 Column: c
Schedule Page: 338 Line No.: 8 Column: c
Applied Depreciation Rate(s) Percent
General Plant 3% to 33.3%
FERC FORM NO. 2 (12-96)Page 552
Particulars Concerning Certain Income Deductions and Interest Charges Accounts
Report the information specified below, in the order given, for the respective income deduction and interest charges accounts.
(a) Miscellaneous Amortization (Account 425)-Describe the nature of items included in this account, the contra account charged, the total of amortization charges for the year, and the
period of amortization.
(b) Miscellaneous Income Deductions-Report the nature, payee, and amount of other income deductions for the year as required by Accounts 426.1, Donations; 426.2, Life Insurance;
426.3, Penalties; 426.4, Expenditures for Certain Civic, Political and Related Activities; and 426.5, Other Deductions, of the Uniform System of Accounts. Amounts of less than $250,000
may be grouped by classes within the above accounts.
(c) Interest on Debt to Associated Companies (Account 430)-For each associated company that incurred interest on debt during the year, indicate the amount and interest rate
respectively for (a) advances on notes, (b) advances on open account, (c) notes payable, (d) accounts payable, and (e) other debt, and total interest. Explain the nature of other debt on
which interest was incurred during the year.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Item
(a)
Amount
(b)
426.1 Questar Corporation Allocations of A & G Expenses 125,620 1
Total Donations 125,620 2
426.4 Questar Corporation Allocations of A & G Expenses 2,019 3
Total Expenditures for Certain Civic Political and Related Activities 2,019 4
430 Questar Corporation Various Borrowings With Various Interest Rates 290,805 5
Total Interest On Debt to Affiliated Companies 290,805 6
431 Various Bank Charges 75,638 7
Various Miscellaneous Interest Charges 762,824 8
Total Other Expenses 838,462 9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
Page 340FERC FORM NO. 2 (12-96)
Regulatory Commission Expenses (Account 928)
1. Report below details of regulatory commission expenses incurred during the current year (or in previous years, if being amortized) relating to formal cases before a regulatory body,
or cases in which such a body was a party.
2. In column (b) and (c), indicate whether the expenses were assessed by a regulatory body or were otherwise incurred by the utility.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description
(Furnish name of regulatory commission
or body, the docket number, and a
description of the case.)
(a)
Total
Expenses
to Date
(d)
Assessed by
Regulatory
Commission
(b)
Expenses
of
Utility
(c)
Deferred in
Account 182.3
at Beginning
of Year
(e)
1,051,534 592,041 592,041FERC--ACA - Transmission 1
( 628,238) 65,782 65,782FERC--ACA - Clay Basin Storage 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
423,296 657,823 657,823Total25
Page 350FERC FORM NO. 2 (12-96)
Regulatory Commission Expenses (Account 928)
3. Show in column (k) any expenses incurred in prior years that are being amortized. List in column (a) the period of amortization.
4. Identify separately all annual charge adjustments (ACA).
5. List in column (f), (g), and (h) expenses incurred during year which were charges currently to income, plant, or other accounts.
6. Minor items (less than $250,000) may be grouped.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Amortized
During Year
Contra
Account
(j)
Expenses
Incurred
During Year
Charged
Currently To
Amount
(h)
Expenses
Incurred
During Year
Deferred to
Account
182.3
(i)
Deferred in
Account 182.3
End of Year
(l)
Expenses
Incurred
During Year
Charged
Currently To
Department
(f)
Expenses
Incurred
During Year
Charged
Currently To
Account No.
(g)
Amortized
During Year
Amount
(k)
2,192,268 592,041 548,693928 1
( 484,116) 65,782 78,340928 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
1,708,152 657,823 627,03325
Page 351FERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
Schedule Page: 350 Line No.: 13 Column: b
Footnote: Deferral is in 186002, not 182.3 Accts
Schedule Page: 350 Line No.: 1 Column: e
Footnote: Deferral is in 186002, not 182.3 Accts
Schedule Page: 350 Line No.: 1 Column: l
Footnote: Deferral is in 186002, not 182.3 Accts
FERC FORM NO. 2 (12-96)Page 552
Distribution of Salaries and Wages
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals,
and Other Accounts, and enter such amounts in the appropriate lines and columns provided.
In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used. When
reporting detail of other accounts, enter as many rows as necessary numbered sequentialy starting with 75.01, 75.02, etc.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Classification
(a)
Total
(d)
Direct Payroll
Distribution
(b)
Allocation of
Payroll Charged
for Clearing
Accounts
(c)
Electric 1
Operation 2
Production 3
Transmission 4
Distribution 5
Customer Accounts 6
Customer Service and Informational 7
Sales 8
Administrative and General 9
TOTAL Operation (Total of lines 3 thru 9) 10
Maintenance 11
Production 12
Transmission 13
Distribution 14
Administrative and General 15
TOTAL Maintenance (Total of lines 12 thru 15) 16
Total Operation and Maintenance 17
Production (Total of lines 3 and 12) 18
Transmission (Total of lines 4 and 13) 19
Distribution (Total of lines 5 and 14) 20
Customer Accounts (line 6) 21
Customer Service and Informational (line 7) 22
Sales (line 8) 23
Administrative and General (Total of lines 9 and 15) 24
TOTAL Operation and Maintenance (Total of lines 18 thru 24) 25
Gas 26
Operation 27
Production - Manufactured Gas 28
Production - Natural Gas(Including Exploration and Development) 29
Other Gas Supply 30
386,709 5,287 381,422 Storage, LNG Terminaling and Processing 31
2,784,733 38,072 2,746,661 Transmission 32
Distribution 33
Customer Accounts 34
Customer Service and Informational 35
Sales 36
1,174,113 16,052 1,158,061 Administrative and General 37
4,345,555 59,411 4,286,144 TOTAL Operation (Total of lines 28 thru 37) 38
Maintenance 39
Production - Manufactured Gas 40
Production - Natural Gas(Including Exploration and Development) 41
Other Gas Supply 42
832,243 11,378 820,865 Storage, LNG Terminaling and Processing 43
1,568,445 21,443 1,547,002 Transmission 44
Distribution 45
Page 354_FERC FORM NO. 2 (12-96)
Distribution of Salaries and Wages (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Classification
(a)
Total
(d)
Direct Payroll
Distribution
(b)
Allocation of
Payroll Charged
for Clearing
Accounts
(c)
Administrative and General 46
2,400,688 32,821 2,367,867 TOTAL Maintenance (Total of lines 40 thru 46) 47
Gas (Continued) 48
Total Operation and Maintenance 49
Production - Manufactured Gas (Total of lines 28 and 40) 50
Production - Natural Gas (Including Expl. and Dev.)(ll. 29 and 41) 51
Other Gas Supply (Total of lines 30 and 42) 52
1,218,952 16,665 1,202,287 Storage, LNG Terminaling and Processing (Total of ll. 31 and 43) 53
4,353,178 59,515 4,293,663 Transmission (Total of lines 32 and 44) 54
Distribution (Total of lines 33 and 45) 55
Customer Accounts (Total of line 34) 56
Customer Service and Informational (Total of line 35) 57
Sales (Total of line 36) 58
1,174,113 16,052 1,158,061 Administrative and General (Total of lines 37 and 46) 59
6,746,243 92,232 6,654,011Total Operation and Maintenance (Total of lines 50 thru 59) 60
Other Utility Departments 61
Operation and Maintenance 62
6,746,243 92,232 6,654,011 TOTAL ALL Utility Dept. (Total of lines 25, 60, and 62) 63
Utility Plant 64
Construction (By Utility Departments) 65
Electric Plant 66
1,040,279 14,222 1,026,057 Gas Plant 67
Other 68
1,040,279 14,222 1,026,057 TOTAL Construction (Total of lines 66 thru 68) 69
Plant Removal (By Utility Departments) 70
Electric Plant 71
Gas Plant 72
Other 73
TOTAL Plant Removal (Total of lines 71 thru 73) 74
Other Accounts (Specify) 75
20,322 278 20,044400 - Operating Revenue 75.01
1,242,399 16,986 1,225,413146 - Accts. Rec. Affiliated Companies 75.02
1,276 17 1,259163 - Stores Expense 75.03
75.04
75.05
75.06
75.07
75.08
75.09
75.10
75.11
75.12
75.13
75.14
75.15
75.16
75.17
75.18
75.19
1,263,997 17,281 1,246,716TOTAL Other Accounts 76
9,050,519 123,735 8,926,784TOTAL SALARIES AND WAGES 77
Page 355`FERC FORM NO. 2 (12-96)
Charges for Outside Professional and Other Consultative Services
1. Report the information specified below for all charges made during the year included in any account (including plant accounts) for outside consultative and other professional
services. These services include rate, management, construction, engineering, research, financial, valuation, legal, accounting, purchasing, advertising, labor relations, and public
relations, rendered for the respondent under written or oral arrangement, for which aggregate payments were made during the year to any corporation partnership, organization of
any kind, or individual (other than for services as an employee or for payments made for medical and related services) amounting to more than $250,000, including payments for
legislative services, except those which should be reported in Account 426.4 Expenditures for Certain Civic, Political and Related Activities.
(a) Name of person or organization rendering services.
(b) Total charges for the year.
2. Designate associated companies with an asterisk in column (b).
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description
(a)
*
(b)
Amount
(in dollars)
(c)
1,196,027Cook-Sanders & Associates: LLC 1
827,746Elkhorn Construction 2
484,047ENSR Corporation 3
1,025,699Essex Environmental 4
290,250Forsgren Associates Incorporated 5
1,606,092Gas Research Institute 6
945,626Greene's Welding & Const. Inc. 7
901,960H & H X-Ray Services Inc. 8
2,605,165Holme Roberts & Owen LLP 9
2,913,423KCI Compression Company LP 10
416,373KW Land Specialists Inc 11
5,163,596Mountain West Fabrication 12
477,546Navigant Consulting Inc 13
543,853Park Acres Construction Co 14
2,534,480*Questar Corporation 15
3,793,467*Questar InfoComm 16
11,994,749*Questar Regulated Services 17
2,791,145Rocky Mountain Inspection, Inc. 18
34,429,191Sterling Construction 19
348,361SWCA Environmental Consultants 20
3,722,683T H Russell Company 21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
Page 357FERC FORM NO. 2 (12-96)
Compressor Stations
1. Report below details concerning compressor stations. Use the following subheadings: field compressor stations, products extraction compressor stations, underground storage
compressor stations, transmission compressor stations, distribution compressor stations, and other compressor stations.
2. For column (a), indicate the production areas where such stations are used. Group relatively small field compressor stations by production areas. Show the number of stations
grouped. Identify any station held under a title other than full ownership. State in a footnote the name of owner or co-owner, the nature of respondent's title, and percent of ownership if
jointly owned.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Name of Station and Location
(a)
Plant Cost
(d)
Number of
Units at
Station
(b)
Certificated
Horsepower for
Each Station
(c)
Underground storage: Underground Storage Compressors 1
538,244 550 1Underground storage: Utah - Chalk Creek 2
2,686,691 1,600 1Underground storage: Utah - Coalville 3
43,369,648 32,500 8Underground storage: Utah - Clay Basin 4
2,115,005 3,830 1Underground storage: Wyoming - Leroy 5
48,709,588 38,480 11Underground storage: Total Underground Storage Compressor Stations 6
Transmission: Transmission Compressor Stations 7
1Transmission: Colorado - Dove Creek 8
961,377 650 2Transmission: Colorado - Rifle 9
3,106,712 100 1Transmission: Colorado - Skull Creek Dew Point Plant 10
917,459 1,085 1Transmission: Colorado - State Line 11
14,667,981 3,370 3Transmission: Utah - Fidlar 12
15,961,519 20,889 3Transmission: Utah - Oak Spring 13
2,604,331 1Transmission: Utah - Price Dew Point Plant 14
15,677,049 6,530 2Transmission: Wyoming - Coleman 15
Transmission: Wyoming - Davis Plant/greasewood 16
22,485,124 15,525 5Transmission: Wyoming - Eakin/Muddy Creek 17
Transmission: Wyoming - Horseshoe Draw/Nitchie Gulch 18
6,586,798 7,160 4Transmission: Wyoming - Kanda 19
4,669,625 6,140 3Transmission: Wyoming - Nightingale 20
1,672,930 3,350 1Transmission: Wyoming - Simon 21
3,670,977 2,464 2Transmission: Wyoming - Skull Creek 22
1,043,358 1,040 3Transmission: Wyoming - South Baxter 23
6,000,000Transmission: Utah - Kastler Dew Point Plt FG 24
100,025,240Transmission: Total Transmission Compressor Stations 25
Page 508FERC FORM NO. 2 (12-96)
Compressor Stations
Designate any station that was not operated during the past year. State in a footnote whether the book cost of such station has been retired in the books of account, or what disposition
of the station and its book cost are contemplated. Designate any compressor units in transmission compressor stations installed and put into operation during the year and show in a
footnote each unit's size and the date the unit was placed in operation.
3. For column (e), include the type of fuel or power, if other than natural gas. If two types of fuel or power are used, show separate entries for natural gas and the other fuel or power.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Date of
Station
Peak
(j)
Operation Data
Total Compressor
Hours of Operation
During Year
(h)
Operation Data
Number of
Compressors
Operated at Time
of Station Peak
(i)
Gas for
Compressor
Fuel in Dth
(g)
Expenses (except
depreciation and
taxes)
Fuel or Power
(e)
Expenses (except
depreciation and
taxes)
Other
(f)
1
02/07/2001 938 16,110 2
04/08/2001 541 66,252 99,803 381,099 3
11/29/2001 8 31,959 1,668,405 4
01/03/2001 1 1,992 79,040 5
66,252 1,863,358 381,099 6
7
16,807 58,196 8
03/30/2001 1 733 1,900 12,603 6,511 9
02/06/2001 21,291 12,969 74,794 10
11/17/2001 1 899 13,111 31,221 40,671 11
05/24/2001 3 20,710 448,774 224,757 1,720,708 12
10/25/2001 5,621 317,146 40,537 1,144,467 13
11 746 22 14
12/03/2001 2 9,654 281,629 665,804 921,685 15
10/05/2001 477,465 1,589,300 16
01/19/2001 7 19,233 480,178 524,865 1,858,755 17
1,118 4,665 18
10/11/2001 3 9,586 226,742 199,645 824,183 19
11/27/2001 2 8,919 477,491 162,252 1,914,800 20
04/10/2001 1 3,488 95,865 127,014 495,075 21
06/01/2001 2 616 77,341 22
01/19/2001 2 13,730 140,331 23
3,193 5,750 24
25
Page 509FERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
Schedule Page: 508 Line No.: 10 Column: a
The Skull Creek Dew Point Plant compressor does not compress natural gas. Instead it compresses propane
refrigerant.
Schedule Page: 508 Line No.: 14 Column: a
The Price Dew Point Plant compressor does not compress natural gas. Instead it compresses propane
refrigerant.
Schedule Page: 508 Line No.: 16 Column: a
The Davis Plant / Greasewood does not compress natural gas. Instead it compresses propane refrigerant.
Schedule Page: 508 Line No.: 25 Column: a
The Kastler Dew Point Plant compressor does not compress natural gas. Instead it compresses propane
refrigerant.
FERC FORM NO. 2 (12-96)Page 552
Gas Storage Projects
1. Report injections and withdrawals of gas for all storage projects used by respondent.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Item
(a)
Total
Amount
(Dth)
(d)
Gas
Belonging to
Respondent
(Dth)
(b)
Gas
Belonging to
Others
(Dth)
(c)
STORAGE OPERATIONS (in Dth)
Gas Delivered to Storage 1
1,201,739 1,112,536 89,203January 2
2,077,319 1,950,493 126,826February 3
6,158,778 5,794,986 363,792March 4
7,239,852 6,812,967 426,885April 5
9,195,038 8,749,587 445,451May 6
8,091,030 7,946,304 144,726June 7
8,654,561 8,363,918 290,643July 8
9,266,010 9,149,004 117,006August 9
8,674,896 7,846,147 828,749September 10
5,082,767 4,847,314 235,453October 11
4,218,962 3,980,532 238,430November 12
2,760,072 2,596,517 163,555December 13
72,621,024 69,150,305 3,470,719TOTAL (Total of lines 2 thru 13) 14
Gas Withdrawn from Storage 15
14,275,649 13,890,538 385,111January 16
6,752,788 6,102,572 650,216February 17
3,366,123 3,290,991 75,132March 18
2,581,100 1,777,098 804,002April 19
1,546,879 965,235 581,644May 20
1,456,448 466,248 990,200June 21
1,231,368 364,042 867,326July 22
2,424,539 1,995,811 428,728August 23
635,590 408,632 226,958September 24
4,745,722 4,636,540 109,182October 25
7,259,455 7,026,604 232,851November 26
12,868,811 12,405,196 463,615December 27
59,144,472 53,329,507 5,814,965TOTAL (Total of lines 16 thru 27) 28
Page 512_FERC FORM NO. 2 (12-96)
Gas Storage Projects
1. On line 4, enter the total storage capacity certificated by FERC.
2. Report total amount in Dth or other unit, as applicable on lines 2, 3, 4, 7. If quantity is converted from Mcf to Dth, provide conversion factor in a footnote.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Item
(a)
Total Amount
(b)
STORAGE OPERATIONS
36,146,275Top or Working Gas End of Year 1
79,811,848Cushion Gas (Including Native Gas) 2
115,958,123Total Gas in Reservoir (Total of line 1 and 2) 3
148,546,200Certificated Storage Capacity 4
57Number of Injection - Withdrawal Wells 5
21Number of Observation Wells 6
652,490Maximum Days' Withdrawal from Storage 7
11/29/2001Date of Maximum Days' Withdrawal 8
LNG Terminal Companies (in Dth) 9
Number of Tanks 10
Capacity of Tanks 11
LNG Volume 12
Received at "Ship Rail" 13
Transferred to Tanks 14
Withdrawn from Tanks 15
"Boil Off" Vaporization Loss 16
Page 513_FERC FORM NO. 2 (12-96)
Transmission Lines
1. Report below, by state, the total miles of transmission lines of each transmission system operated by respondent at end of year.
2. Report separately any lines held under a title other than full ownership. Designate such lines with an asterisk, in column (b) and in a footnote state the name of owner, or co-owner,
nature of respondent's title, and percent ownership if jointly owned.
3. Report separately any line that was not operated during the past year. Enter in a footnote the details and state whether the book cost of such a line, or any portion thereof, has been
retired in the books of account, or what disposition of the line and its book costs are contemplated.
4. Report the number of miles of pipe to one decimal point.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Designation (Identification)
of Line or Group of Lines
(a)
*
(b)
Total Miles
of Pipe
(c)
64.00
Colorado Transmission Lines - Northern System 1
104.60
Colorado Transmission Lines - Southern System 2
332.20
Utah Transmission Lines - Northern System 3
378.60
Utah Transmission Lines - Southern System 4
82.00
Fidlar Compressor to Main Line 58 Connection System 5
744.10
Wyoming Transmission Lines 6
1,705.50
Total Miles 7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
Page 514FERC FORM NO. 2 (12-96)
Transmission System Peak Deliveries
1. Report below the total transmission system deliveries of gas (in Dth), excluding deliveries to storage, for the period of system peak deliveries indicated below, during the 12 months
embracing the heating season overlapping the year's end for which this report is submitted. The season's peak normally will be reached before the due date of this report, April 30, which
permits inclusion of the peak information required on this page. Add rows as necessary to report all data. Number additional rows 6.01, 6.02, etc.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description
Total
(b) + (c)
(d)
Dth of Gas
Delivered to
Interstate Pipelines
(b)
Dth of Gas
Delivered to
Others
(c)
SECTION A: SINGLE DAY PEAK DELIVERIES
Date: 01-30-02 1
Volumes of Gas Transported 2
6,564 6,564 No-Notice Transportation 3
1,316,555 1,041,330 275,225 Other Firm Transportation 4
103,181 98,917 4,264 Interruptible Transportation 5
Other (Describe) 6
6.01
6.02
6.03
6.04
6.05
1,426,300 1,146,811 279,489TOTAL 7
Volumes of gas Withdrawn form Storage under Storage Contract 8
11,089 11,089 No-Notice Storage 9
372,745 324,745 48,000 Other Firm Storage 10
Interruptible Storage 11
Other (Describe) 12
12.01
12.02
12.03
12.04
12.05
383,834 335,834 48,000TOTAL 13
Other Operational Activities 14
64,097 64,097 Gas Withdrawn from Storage for System Operations 15
Reduction in Line Pack 16
Other (Describe) 17
17.01
17.02
17.03
17.04
17.05
64,097 64,097TOTAL 18
SECTION B: CONSECUTIVE THREE-DAY PEAK DELIVERIES 19
Dates:01-29-02 01-30-02 01-31-02 20
Volumes of Gas Transported 21
152,676 152,676 No-Notice Transportation 22
3,837,788 3,003,659 834,129 Other Firm Transportation 23
324,247 311,456 12,791 Interruptible Transportation 24
Other (Describe) 25
25.01
25.02
25.03
25.04
25.05
4,314,711 3,467,791 846,920TOTAL 26
Volumes of Gas Withdrawn from Storage under Storage Contract 27
167,099 167,099 No-Notice Storage 28
785,674 653,090 132,584 Other Firm Storage 29
Interruptible Storage 30
Page 518FERC FORM NO. 2 (12-96)
Transmission System Peak Deliveries (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Description
Total
(b) + (c)
(d)
Dth of Gas
Delivered to
Interstate Pipelines
(b)
Dth of Gas
Delivered to
Others
(c)
Other (Describe) 31
31.01
31.02
31.03
31.04
31.05
952,773 820,189 132,584TOTAL 32
Other Operational Activities 33
93,867 93,867 Gas Withdrawn from Storage for System Operations 34
Reduction in Line Pack 35
Other (Describe) 36
36.01
36.02
36.03
36.04
36.05
93,867 93,867TOTAL 37
Page 518aFERC FORM NO. 2 (12-96)
Auxiliary Peaking Facilities
1. Report below auxiliary facilities of the respondent for meeting seasonal peak demands on the respondent's system, such as underground storage projects, liquefied petroleum gas
installations, gas liquefaction plants, oil gas sets, etc.
2. For column (c), for underground storage projects, report the delivery capacity on February 1 of the heating season overlapping the year-end for which this report is submitted.
For other facilities, report the rated maximum daily delivery capacities.
3. For column (d), include or exclude (as appropriate) the cost of any plant used jointly with another facility on the basis of predominant use, unless the auxiliary peaking facility is a
separate plant as contemplated by general instruction 12 of the Uniform System of Accounts.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Location of
Facility
(a)
Was Facility
Operated on Day
of Highest
Transmission Peak
Delivery?
Maximum Daily
Delivery Capacity
of Facility
Dth
(c)
Cost of
Facility
(in dollars)
(d)
Type of
Facility
(b)
Summit County, Utah 1
18,642,580 105,115Underground StorageChalk Creek and Coalville Storage 2 Yes
Uinta County, Wyoming 3
17,897,611 79,575Underground StorageLeroy Storage Project 4 Yes
Dagget County, Utah 5
81,134,258 812,430Underground StorageClay Basin Storage Project 6 Yes
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
Page 519FERC FORM NO. 2 (12-96)
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 Dth as reported in the schedules indicated for the items of receipts and deliveries.
4. Indicate in a footnote the quantities of bundled sales and transportation gas and specify the line on which such quantities are listed.
5. If the respondent operates two or more systems which are not interconnected, submit separate pages for this purpose. Use copies of pages 520.
6. Also 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.
7. Also 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.
8. 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
rows as necessary to report all data, numbered 14.01, 14.02, etc.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Item
(a)
Amount of
Dth
(c)
Ref.
Page
No.
(b)
01 Name of System:
GAS RECEIVED 2
Gas Purchases (Accounts 800-805) 3
Gas of Others Received for Gathering (Account 489.1)303 4
Gas of Others Received for Transmission (Account 489.2)305 314,458,558 5
Gas of Others Received for Distribution (Account 489.3)301 6
Gas of Others Received for Contract Storage (Account 489.4)307 7
Exchanged Gas Received from Others (Account 806)328 8
Gas Received as Imbalances (Account 806)328 1,987,051 9
Receipts of Respondent's Gas Transported by Others (Account 858)332 10
Other Gas Withdrawn from Storage (Explain) 1,236,568 11
Gas Received from Shippers as Compressor Station Fuel 12
Gas Received from Shippers as Lost and Unaccounted for 13
Other Receipts (Specify) 14
14.01
14.02
14.03
14.04
14.05
14.06
14.07
14.08
14.09
14.10
Total Receipts (Total of lines 3 thru 14.?) 317,682,177 15
GAS DELIVERED 16
Gas Sales (Accounts 480-484) 17
Deliveries of Gas Gathered for Others (Account 489.1)303 18
Deliveries of Gas Transported for Others (Account 489.2)305 312,760,704 19
Deliveries of Gas Distributed for Others (Account 489.3)301 20
Deliveries of Contract Storage Gas (Account 489.4)307 21
Exchange Gas Delivered to Others (Account 806)328 22
Gas Delivered as Imbalances (Account 806)328 1,990,304 23
Deliveries of Gas to Others for Transportation (Account 858)332 24
Other Gas Delivered to Storage (Explain) 25
Gas Used for Compressor Station Fuel 509 2,928,973 26
Other Deliveries (Specify) 27
Page 520FERC FORM NO. 2 (12-96)
Gas Account - Natural Gas (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
Year of Report
Dec. 31, Questar Pipeline Company X
12/31/2001 2001
Item
(a)
Amount of
Dth
(c)
Ref.
Page
No.
(b)
27.01
27.02
27.03
27.04
27.05
27.06
27.07
27.08
27.09
27.10
Total Deliveries (Total of lines 17 thru 27.?) 317,679,981 28
GAS UNACCOUNTED FOR 29
Production System Losses 30
Gathering System Losses 31
Transmission System Losses 2,196 32
Distribution System Losses 33
Storage System Losses 34
Other Losses (Specify) 35
Total Unaccounted For (Total of lines 30 thru 35) 2,196 36
Total Deliveries & Unaccounted For (Total of lines 28 and 36) 317,682,177 37
Page 520aFERC FORM NO. 2 (12-96)
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
FOOTNOTE DATA
Schedule Page: 520 Line No.: 19 Column: c
GAS ACCOUNT NATURAL GAS
The 69,150,305 (Dth) of natural gas received to underground storage includes volumes that are reported on line 14 on
page 512, gas of others received for contract storage, and should not be included in volumes for computation of the
Annual Charge Adjustment (ACA).
Pursuant to section 4 (f) of Rate Schedule FSS and Section 3 (d) of respondant's FERC Gas Tariff, First Revised Volume
No. 1, the ACA is only applicable to 36,243,615 Dth of gas transported to storage by Northwest Pipeline Corporation.
Total volume subject to ACA is 349,004,319 Dth, which is the sum of line 19 on Page 520 and 36,243,615 Dth of gas
transported to storage by Northwest Pipeline Corporation.
FERC FORM NO. 2 (12-96)Page 552
Name of Respondent
Questar Pipeline Company
This Report is:
(1) X An Original
(2) A Resubmission
Date of Report
(Mo, Da, Yr)
12/31/2001
Year of Report
Dec 31, 2001
System Maps
1. Furnish five copies of a system map (one with each filed copy of this report) of the facilities operated by the respondent for the production,
gathering, transportation, and sale of natural gas. New maps need not be furnished if no important change has occurred in the facilities operated
by the respondent since the date of the maps furnished with a previous year's annual report. If, however, maps are not furnished for this reason,
reference should be made in the space below to the year's annual report with which the maps were furnished.
2. Indicate the following information on the maps:
(a) Transmission lines.
(b) Incremental facilities.
(c) Location of gathering areas.
(d) Location of zones and rate areas.
(e) Location of storage fields.
(f) Location of natural gas fields.
(g) Location of compressor stations.
(h) Normal direction of gas flow (indicated by arrows).
(i) Size of pipe.
(j) Location of products extraction plants, stabilization plants, purification plants, recycling areas, etc.
(k) Principal communities receiving service through the respondent's pipeline.
3. In addition, show on each map: graphic scale of the map; date of the facts the map purports to show; a legend giving all symbols and
abbreviations used; designations of facilities leased to or from another company, giving name of such other company.
4. Maps not larger than 24 inches square are desired. If necessary, however, submit larger maps to show essential information. Fold the
maps to a size not larger then this report. Bind the maps to the report.
FERC FORM NO. 2 (REV. 12-96)Page 522
INDEX
Accrued and prepaid taxes 262-263
Accumulated provision for depreciation of
gas utility plant 219
utility plant (summary) 200-201
Advance to associated companies 222
Associated companies
advances from 256
advances to 222-223
control over respondent 102
corporations controlled by respondent 103
investment in 222-223
service contracts charges 357
Attestation 1
Balance Sheet, comparative 110-113
Bonds 256-257
Capital Stock 250-251
discount 254
expense 254
premiums 252
reacquired 251
subscribed 252
Cash flows, statement of 120-121
Changes -- important during the year 108
Compressor Stations 508-509
Construction
overhead procedures, general description of 218
work in progress -- other utility departments 200-201
Contracts, service charges 357
Control
corporations controlled by respondent 103
over respondent 102
security holders and voting powers 107
CPA Certification, this report form i
Current and accrued
liabilities, miscellaneous 268
Deferred
credits, other 269
debits, miscellaneous 233
income taxes, accumulated 234-235
income taxes, accumulated-other property 274-275
income taxes, accumulated-other 276-277
regulatory expenses 350-351
Definitions, this report form iv
Depletion
amortization and depreciation of gas plant 336-338
and amortization of producing natural gas land and land rights 336-338
Depreciation
gas plant 336-338
gas plant in service 219
Discount on Capital Stock 254
Dividend appropriations 118-119
Earnings, retained 118-119
Exchange and imbalance transactions 328
Expenses, gas operation and maintenance 320-325
Extraordinary property losses 230
Filing Requirements, this report form i-iii
Footnote Data 551-552
Gas account -- natural 520
Gas
exchanged, natural 328
received 328
stored underground 220
used in utility operations, credit 331
plant in service 204-209
Gathering revenues 302-303
General description of construction overhead procedures 218
General information 101
Income
deductions -- details 256-259, 340
statement of, for year 114-116
Installments received on capital stock 252
Interest
on debt to associated companies 340
on long-term from investment, advances, etc. 256-257
Instructions for filing the FERC Form No. 2 i-iii
Investment
in associated companies 222-223
other 222-223
subsidiary companies 224-225
securities disposed of during year 222-223
temporary cash 222-223
Law, excerpts applicable to this report form iv
List of Schedules, this report form 2-3
Legal proceedings during year 108
Long-term debt 256-257
assumed during year 255
retained during year 255
Management and engineering contracts 357
Map, system 522
Miscellaneous general expense 335
Notes
Payable, advances from associated companies 256-257
to balance sheet 122
to financial statement 122
to statement of income for the year 122
Operating
expenses -- gas 317-325
revenues -- gas 300-301
Other
donations received from stockholders 253
gains on resale or cancellation of reacquired capital stock 253
miscellaneous paid-in capital 253
other supplies expense 334
paid-in capital 253
reduction in par or stated value of capital stock 253
regulatory assets 232
regulatory liabilities 278
Peak deliveries, transmission system, 518
Peaking facilities, auxiliary 519
Plant -- gas
construction work in progress 216
held for future use 214
leased from others 212
leased to others 213
Plant --Utility
accumulated provisions (summary) 200-201
leased to others, income from 213
Premium on capital stock 252
Prepaid taxed 262-263
Prepayments 230
Professional services, charges for 357
Property losses, extraordinary 230
Reacquired
capital stock 250-251
long-term debt 256-257
Receivers’ certificate 256-257
Reconciliation of reported net income with taxable income from Federal income taxes 261
Regulatory commission expenses 350-351
Regulatory commission expenses -- deferred 232
Retained earnings
appropriated 118-119
statement of 118-119
unappropriated 118-119
Revenues
from storing gas of others 306-307
from transportation of gas through gathering facilities 302-303
from transportation of gas through transmission facilities 304-305
gas operating 300
Salaries and wages, distribution of 354-355
Sales 300-301
Securities
disposed of during year 222-223
holders and voting powers 107
investment in associated companies 222-223
investment, others 222-223
issued or assumed during year 255
refunded or retired during year 255
registered on a national exchange 250-251,
256-257
Stock liability for conversion 252
Storage
of natural gas, underground 512-513
revenues 306-307
Taxes
accrued and prepaid 262-263
charged during the year 262-263
on income, deferred -- accumulated 222-223,
234-235
reconciliation of net income for 261
Transmission
and compression of gas by others 332
lines 514
revenues 304-305
system peak deliveries 518
Unamortized
debt discount and expense 258-259
loss and gain on reacquired debt 260
premium on debt 258-259
Underground
storage of natural gas, expense, operating data, plant 512-513
Unrecovered plant and regulatory study costs 230