144 FERC ¶ 61,049

UNITED STATES OF AMERICA

FEDERAL ENERGY REGULATORY COMMISSION

18 CFR Part 357

[Docket No. RM12-18-000; Order No. 783]

Revisions to Page 700 of FERC Form No. 6

(Issued July 18, 2013)

AGENCY: Federal Energy Regulatory Commission.

ACTION: Final rule.

SUMMARY: The Federal Energy Regulatory Commission (Commission) is modifying 

Page 700 of FERC Form No. 6 (Form 6) to facilitate the calculation of an oil pipeline’s 

actual return on equity for preliminary screening purposes. The Commission will expand 

the information provided regarding Rate Base (line 5), Rate of Return (line 6), Return on 

Rate Base (line 7), and Income Tax Allowance (line 8). 

EFFECTIVE DATE: This rule will become effective [insert date 60 days after 

publication in the FEDERAL REGISTER].

FOR FURTHER INFORMATION CONTACT:

James Sarikas (Technical Information)

Office of Energy Market Regulation

888 First Street, NE

Washington, DC 20426

(202) 502-6831

James.Sarikas@ferc.gov

Brian Holmes (Technical Information)

Office of Enforcement

888 First Street, NE

Washington, DC 20426
Docket No. RM12

-18-000 - 2 -

(202) 502-6008

Brian.Holmes@ferc.gov

Andrew Knudsen (Legal Information)

Office of the General Counsel

888 First Street, NE

Washington, DC 20426

(202) 502-6527

Andrew.Knudsen@ferc.gov

SUPPLEMENTARY INFORMATION

:
144 FERC ¶ 61,049

UNITED STATES OF AMERICA

FEDERAL ENERGY REGULATORY COMMISSION

Revisions to Page 700 of FERC Form No. 6 Docket No. RM12-18-000

FINAL RULE

ORDER NO. 783

TABLE OF CONTENTS

Paragraph Numbers

I. Introduction .............................................................................................................................1.

II. Background ............................................................................................................................2.

III. NOPR Comments...................................................................................................................6.

IV. Discussion..............................................................................................................................7.

A. Rate Base............................................................................................................................9.

1. NOPR ............................................................................................................................9.

2. Comments........................................................................................................................10.

3. Commission Determination ............................................................................................11.

B. Rate of Return.....................................................................................................................12.

1. NOPR ............................................................................................................................12.

2. Comments........................................................................................................................13.

3. Commission Determination ............................................................................................15.

C. Return on Rate Base...........................................................................................................19.

1. NOPR ............................................................................................................................19.

2. Comments........................................................................................................................20.

3. Commission Determination ............................................................................................21.

D. Composite Income Tax Rate .............................................................................................22.

1. NOPR.............................................................................................................................22.

2. Comments........................................................................................................................24.

3. Commission Determination ............................................................................................26.

E. Calculation of Actual Rate of Return on Equity.................................................................29.

1. NOPR.............................................................................................................................29.

2. Comments........................................................................................................................31.
Docket No. RM12-18-000 ii

3. Commission Determination ............................................................................................36.

F. Miscellaneous Recommendations .....................................................................................41.

1. Comments........................................................................................................................41.

2. Commission Determination ............................................................................................45.

G. Conclusion ..........................................................................................................................46.

H. Effective Date ....................................................................................................................47.

V. Information Collection Statement...........................................................................................48.

A. The NOPR..........................................................................................................................48.

B. Comments............................................................................................................................50.

C. Commission Determination................................................................................................51.

VI. Environmental Analysis.........................................................................................................52.

VII. Regulatory Flexibility Act...................................................................................................53.

VIII. Document Availability........................................................................................................55.

IX. Effective Date and Congressional Notification.....................................................................58.
144 FERC ¶ 61,049

UNITED STATES OF AMERICA

FEDERAL ENERGY REGULATORY COMMISSION

Before Commissioners: Jon Wellinghoff, Chairman;

 Philip D. Moeller, John R. Norris,

Cheryl A. LaFleur, and Tony Clark.

Revisions to Page 700 of FERC Form No. 6 Docket No. RM12-18-000

FINAL RULE

ORDER NO. 783

(Issued July 18, 2013)

I. Introduction 

1. The Federal Energy Regulatory Commission (Commission) is issuing this Final 

Rule to modify the reporting requirements on Page 700, Annual Cost of Service Based 

Analysis Schedule, of FERC Form No. 6, Annual Report of Oil Pipeline Companies 

(Form 6), to facilitate the calculation of an oil pipeline’s actual rate of return on equity 

based upon Page 700 data for preliminary screening purposes. The modifications to Page 

700 include requiring additional information regarding rate base, rate of return, return on 

rate base, and income taxes.

II. Background 

2. The Commission is responsible for regulating the rates, terms and conditions that 

oil pipelines charge for transportation under the Interstate Commerce Act (ICA).1

 The 

 1 49 App. USC 1-85 (2000).
Docket No. RM12-18-000 - 2 -

ICA prohibits oil pipelines from charging rates that are unjust and unreasonable and 

permits shippers and the Commission to challenge both pre-existing and newly filed 

rates.2

 

3. To assist the Commission in the administration of its jurisdictional responsibilities, 

the ICA authorizes the Commission to prescribe annual or other periodic reports. 3

 

Through Form 6, the Commission collects annual financial information from crude and 

refined product pipelines

4 subject to the Commission’s jurisdiction, as prescribed in 

section 357.2 of the Commission’s regulations.5

 

4. Page 700 of Form 6 provides a simplified presentation of an oil pipeline’s 

jurisdictional cost-of-service. Page 700 serves as a preliminary screening tool to evaluate 

oil pipeline rates.6

 However, “Page 700 information alone is not intended to show what a 

 2 49 USC 13(1), 15(1), (7). Just and reasonable rate are “rates yielding sufficient 

revenue to cover all proper costs, including federal income taxes, plus a specified return 

on invested capital.” City of Charlottesville v. FERC, 774 F.2d 1205, 1207 (D.C. 

Cir. 1985).

3 49 App. USC 1-85 (2000).

4 Hereafter, the term oil pipeline shall include both crude and refined product oil 

pipelines.

5 18 CFR 357.2 (2012).

6 All jurisdictional oil pipelines, except the Trans-Alaskan oil pipeline System 

(TAPS) oil pipelines, are required to file Page 700, including oil pipelines exempt from 

filing the full Form 6. 18 CFR sections 357.2(a)(2) and (a)(3) (2012). Section 

1804(2)(B) of the Energy Policy Act of 1992 excludes from the provisions of the Act, for 

ratemaking purposes, TAPS and any oil pipeline delivering oil directly or indirectly to 

TAPS. Therefore, the Commission exempted the TAPS entities from having to submit 

the information required on Page 700. Cost of Service Requirements and Filing 

 

(continued...)
Docket No. RM12-18-000 - 3 -

just and reasonable rate should be.”7

 Currently, oil pipelines are required to provide the 

following on Page 700: Operating and Maintenance Expenses (line 1), Depreciation 

Expense (line 2), AFUDC Depreciation (line 3), Amortization of Deferred Earnings 

(line 4), Rate Base (line 5), Rate of Return (line 6), Return on Rate Base (line 7), Income 

Tax Allowance (line 8), Total Cost of Service (line 9), Total Interstate Operating 

Revenues (line 10), Total Interstate Throughput in Barrels (line 11), and Total Interstate 

Throughput in Barrel-Miles (line 12).

5. On September 20, 2012, consistent with its obligation to ensure oil pipeline rates 

are just and reasonable, the Commission issued a Notice of Proposed Rulemaking 

(NOPR) proposing to modify the reporting requirements on Page 700 of Form 6 to allow 

shippers and interested entities to more easily calculate an oil pipeline’s actual rate of 

return on equity for preliminary screening purposes.8

 The NOPR reasoned the actual rate 

of return on equity is particularly useful information when using Page 700 to make a 

preliminary evaluation of an oil pipeline’s rates consistent with the Commission’s 

mandate under the ICA. To this end, the NOPR proposed to make changes to Page 700 

to include additional supporting information the Commission anticipates is already

 

Requirements for Oil Pipelines, Order No. 571, FERC Stats. & Regs. ¶ 31,006, at 31,175

(1995), on reh’g, Order No. 571-A, FERC Stats. & Regs. ¶ 31,012 (1994). 

7 Order No. 571-A, FERC Stats. & Regs. ¶ 31,012 at 31,254.

8 Revisions to Page 700 of FERC Form No. 6, 77 FR 59343 (Sept. 9, 2012), FERC 

Stats. & Regs. ¶ 32,692 (2012) (NOPR).
Docket No. RM12-18-000 - 4 -

developed in the preparation of the rate base, rate of return, return on rate base, and 

income taxes reported on Page 700.

III. NOPR Comments

6. The Association of Oil Pipelines (AOPL),9 the Kansas Corporation Commission 

(KCC), R. Gordon Gooch (Mr. Gooch), Airlines for America (A4A)10 and the National 

Propane Gas Association (NPGA),11 the Canadian Association of Petroleum Producers 

(CAPP), Suncor Energy Marketing Inc. (Suncor), ConocoPhillips Co. (ConocoPhillips), 

BP West Coast Products, LLC and Western Refining Company, L.P. (collectively, BP), 

and Valero Marketing and Supply Company (Valero) filed comments in response to the 

Commission’s NOPR. Suncor and AOPL filed reply comments. The comments are 

addressed below.

IV. Discussion

7. The majority of commenters support the NOPR. In contrast, the Association of 

Oil Pipelines (AOPL) believes the proposed modifications are unnecessary. We address 

AOPL’s arguments below. 

 9 AOPL is a trade association that represents the interests of common carrier oil 

pipelines. AOPL’s members transport almost 85 percent of the crude oil and refined 

petroleum products shipped through oil pipelines in the U.S.

10 A4A is an airline trade association whose members account for more than 

90 percent of the passenger and cargo traffic carried by U.S. airlines.

11 NPGA is a trade association of the U.S. propane industry with a membership of 

about 3,000 companies, including 38 affiliated state and regional associations 

representing members in all 50 states.
Docket No. RM12-18-000 - 5 -

8. As discussed below, the Commission adopts, with minor modifications to the 

labeling of the additional lines on Page 700, the NOPR’s proposal to enhance the 

information provided on Page 700 related to rate base, rate of return, return on rate base, 

and income tax allowance. 

A. Rate Base

1. NOPR

9. The NOPR observed that “[c]omponents of an oil pipeline’s rate base are 

governed by the trended original cost methodology adopted in Opinion No. 154-B.”

12 

Under this methodology, an oil pipeline’s rate base consists of: (1) the depreciated 

original cost rate base, (2) any unamortized amounts from the oil pipeline’s starting rate 

base write-up (SRB), and (3) accumulated net deferred earnings. Consistent with 

Opinion No. 154-B,13 the NOPR proposed to enhance the reporting of the total trended 

original cost (TOC) rate base information provided on line 5 of page 700 by requiring the 

reporting of the three subparts of the TOC rate base: (1) Rate Base – Original Cost 

(proposed line 5a); (2) Rate Base – Unamortized Starting Rate Base Write-Up (proposed 

line 5b); and (3) Rate Base – Accumulated Net Deferred Earnings (proposed line 5c). 

Thus, the NOPR explained the sum of proposed lines 5a, 5b, and 5c comprise the oil 

pipeline’s TOC Rate Base. Consequently, the NOPR proposed to move the TOC rate 

 12 NOPR, FERC Stats. & Regs. ¶ 32,692 at P 9.

13 Williams Pipe Line Co., Opinion No. 154-B, 31 FERC ¶ 61,377 (1985).
Docket No. RM12-18-000 - 6 -

base from line 5 to line 5d and to label line 5d as Total Rate Base – Trended Original 

Cost – (line 5a + line 5b + line 5c).

2. Comments

10. AOPL requests clarification as to proposed line 5a. AOPL seeks clarification that 

line 5a is intended to reflect the respondent’s depreciated original cost rate base, 

consistent with the methodology contained in Opinion No. 154-B, et al.14 

3. Commission Determination

11. The Commission adopts the NOPR proposal to enhance the rate base information 

provided on Page 700 by adding lines 5a, 5b, and 5c to Page 700 to provide the three 

subparts of the TOC rate base. The new line 5 series will reflect the following additions 

as proposed in the NOPR: (1) Rate Base – Depreciated Original Cost (line 5a); (2) Rate 

Base – Unamortized Starting Rate Base Write-up (line 5b); and (3) Rate Base –

Accumulated Net Deferred Earnings (line 5c). The sum of lines 5a, 5b, and 5c comprise 

the oil pipeline’s TOC rate base, which is currently reported on line 5 and which will now 

move to line 5d and be entitled Total Rate Base – Trended Original Cost – (line 5a + line 

5b + line 5c). As requested by AOPL, the Commission affirms new line 5a is intended to 

reflect the respondent’s depreciated original cost rate base consistent with Opinion 

No. 154-B and it will be titled to reflect such intent. The depreciated original cost rate 

base will be added to the other two subparts, which will comprise the oil pipeline’s total 

TOC rate base.

 14 AOPL Comments at 21 (citing Opinion No. 154-B, 31 FERC ¶ 61,377).
Docket No. RM12-18-000 - 7 -

B. Rate of Return

1. NOPR

12. The NOPR proposed to require oil pipelines to report the cost of equity, cost of 

debt, and the capital structure supporting the overall weighted cost of capital currently 

reported as Rate of Return on line 6, Page 700. Specifically, the NOPR proposed to 

include additional information related to debt and equity capital structure ratios, i.e. 

(1) Rate of Return – Adjusted Capital Structure Ratio for Long Term Debt (proposed line 

6a), (2) Rate of Return – Adjusted Capital Structure Ratio for Proprietary Capital 

(proposed line 6b).15 The NOPR further proposed to add information related to the cost 

of debt and the cost of equity, specifically: (1) Rate of Return – Cost of Long Term Debt 

Capital (proposed line 6c) and (2) Rate of Return – Real Cost of Proprietary Capital 

(proposed line 6d). This additional information forms the basis for the Rate of Return –

Weighted Average Cost of Capital (the sum of the product of line 6a x line 6c added to 

the product of line 6b x line 6d), which is now reported as Rate of Return on line 6 on 

Page 700 and which the NOPR proposed to move to line 6e.

2. Comments

13. AOPL seeks clarification as to proposed lines 6b and 6d. AOPL notes that the 

term Proprietary Capital is not defined and does not appear in any Commission 

regulations governing oil pipelines.

16 Therefore, to the extent the Commission 

 15 NOPR, FERC Stats. & Regs. ¶ 32,692 at P 9 n.13 (citing ARCO Pipe Line Co., 

Opinion No. 351-A, 53 FERC ¶ 61,398 at 62,388-89 (1990)). 

 

16 AOPL Comments at 21.
Docket No. RM12-18-000 - 8 -

determines it is appropriate to provide additional information regarding the weighted 

average cost of capital, AOPL requests that the Commission “clarify line 6b is to provide 

the adjusted equity capital ratio computed in a manner consistent with the Commission’s 

prior findings in Opinion No. 351-A, and that line 6d is to provide the allowed real return 

on equity referenced in the Commission’s policy statement regarding the determination 

of oil pipeline equity returns.”

17 

14. In contrast, A4A and the NPGA submitted comments agreeing that the proposed 

information is necessary to understand both the return on rate base composition and an oil

pipeline’s actual rate of return on equity.

18 However, A4A and NPGA propose that the 

Commission revise its Rate of Return - Real Cost of Propriety Capital of 14.25 percent

that appears in proposed line 6d, “because the figure seems anomalously large as a real 

rate of return on equity.”

19 

3. Commission Determination

15. The Commission adopts the NOPR proposal to enhance the rate of return 

information on Page 700 by adding to line 6 of Page 700, as modified below. The 

NOPR’s use of the term Proprietary Capital was not meant to create a new ratemaking 

concept. The Commission borrowed the term Proprietary Capital from the listing of 

 17 Id. at 22 (citing Opinion No. 351-A, 53 FERC at 62,388-89; Composition of

Proxy Groups for Determining Gas and Oil Pipeline Return on Equity, 123 FERC 

¶ 61,048, at P 62 (2008)).

18 A4A and NPGA Comments at 8.

19 Id.
Docket No. RM12-18-000 - 9 -

balance sheet chart of accounts in the Uniform System of Accounts (USofA) for the 

natural gas and electric industries.20 The corresponding title for the oil industry as shown 

in account 797, Form of Balance Sheet Statement is Stockholder’s Equity.21

16. To be consistent with the language of the USofA for the oil pipeline industry, the 

Commission will change the term Proprietary Capital in the line 6 series to Stockholder’s 

Equity. The Commission also grants AOPL’s clarification that the adjusted equity capital 

ratio should be calculated in a manner consistent with the Commission’s prior findings in 

Opinion No. 351-A. Likewise, the Commission notes that AOPL is correct that line 6d is 

intended to provide the allowed real return on equity referenced in the Commission’s 

Return on Equity Policy Statement. 

17. The Commission adopts the NOPR proposal to enhance the rate of return 

information on Page 700 by adding data to line 6 of Page 700. The new line 6 series will 

reflect a wording change as clarified above and will include additional information 

related to debt and equity capital structure ratios in the following manner: (1) Rate of 

Return – Adjusted Capital Structure Ratio for Long Term Debt (line 6a), (2) Rate of 

Return – Adjusted Capital Structure Ratio for Stockholder’s Equity (line 6b). The 

Commission further adds information related to the cost of debt and the cost of equity, 

specifically: (1) Rate of Return – Cost of Long Term Debt Capital (line 6c), (2) Rate of 

Return – Real Cost of Stockholder’s Equity (line 6d). This additional information forms 

 20 18 CFR Part 201 and 18 CFR Part 101 (2012), respectively.

21 18 CFR Part 352, Account 797 – Form of Balance Sheet Statement –

Stockholder’s Equity (2012).
Docket No. RM12-18-000 - 10 -

the basis for the Rate of Return – Weighted Average Cost of Capital (the sum of the 

product line 6a and line 6c added to the product of line 6b and 6d), which is now reported 

as Rate of Return on line 6 on Page 700 and which the Commission proposes to move to 

line 6e, and label Rate of Return – Weighted Average Cost of Capital – (line 6a x line 6c 

+ line 6b x line 6d).

18. The Commission denies A4A’s and NPGA’s request to change the 14.25 percent 

figure in Appendix B. The inputs contained in Appendix B were solely used for 

illustrative purposes and should not be viewed as having any precedential value.

C. Return on Rate Base

1. NOPR

19. The NOPR proposed to require oil pipelines to report additional information 

related to the Return on Rate Base in line 7.22 The Return on Rate Base currently 

reported on line 7 combines the oil pipeline’s real return on equity and the portion of the 

oil pipeline’s return allocated to paying its cost of debt. The NOPR proposed to require 

the oil pipeline to include on Page 700 the Return on Rate Base – Debt Component 

(proposed line 7a)23 and to require the oil pipeline to report its weighted average cost of 

capital consisting of debt and equity to one rate base. The real cost of capital excludes 

the inflationary component of the nominal return that is added to the Net Deferred 

 22 NOPR, FERC Stats. & Regs. ¶ 32,692 at P 10.

23 Return on Rate Base – Debt Component will be the equivalent of the weighted 

average cost of debt (product of proposed lines 6a and 6c) multiplied by the Trended 

Original Cost Rate Base (proposed line 5d).
Docket No. RM12-18-000 - 11 -

Earnings and subsequently amortized pursuant to the TOC methodology. Proposed line 

7b is the Return on Rate Base – Equity Component. The NOPR proposed that oil 

pipelines report on proposed line 7c, the Total Return on Rate Base – (line 7a + line 7b), 

which is the same information currently reported on line 7.

2. Comments

20. A4A and NPGA request that instructions to Page 700 recognize that the Return on 

Rate Base – Debt Component (line 7a) will equal the product of the Trended Original 

Cost Rate Base (proposed line 5d) and the weighted average cost of debt (itself the 

product of proposed lines 6a and 6c), while the Return on Rate Base – Equity Component

(line 7b) will equal the product of the Trended Original Cost Rate Base (proposed line 

5d) and the weighted average cost of equity (product of proposed lines 6b and 6d). 

3. Commission Determination

21. The Commission adopts the NOPR proposal and grants the requested 

clarifications. The Commission will change the proposed wording for lines 7a and 7b to 

include a parenthetical formula as described by A4A and NPGA. The title for the new 

line 7a will read “Return on Rate Base – Debt Component – (line 5d x line 6a x line 6c).” 

The title for new line 7b will read “Return on Rate Base – Equity Component – (line 5d x 

line 6b x line 6d).” 
Docket No. RM12-18-000 - 12 -

D. Composite Income Tax Rate

1. NOPR

22. The NOPR proposed to modify Page 700 to include the Composite Tax Rate used 

to determine the Income Tax Allowance.24 (Line 8 of Page 700 currently requires each 

oil pipeline to report the total dollar amount attributable to the Income Tax Allowance in 

its cost-of-service.). The NOPR proposed to add a new line 8a which will require an oil

pipeline to report its Composite Tax Rate Percentage.25 The NOPR defined the 

Composite Tax Rate Percentage as the sum, adjusted consistent with Commission policy, 

of (a) the applicable state income tax rate and (b) a federal income tax rate. As filed on 

Page 700, the NOPR stated the Composite Tax Rate Percentage should reflect the income 

tax rate used pursuant to Commission policy to determine the Income Tax Allowance 

reported on line 8.

23. The NOPR surmised “[t]he Composite Tax Rate Percentage will create a better 

understanding of the differential between an oil pipeline’s Total Interstate Operating 

Revenues (line 10) and the oil pipeline’s Total Cost of Service (line 9).”26 Specifically, 

the NOPR predicted the Composite Tax Rate Percentage may be used to determine the 

 24 NOPR, FERC Stats. & Regs. ¶ 32,692 at P 11. See also Inquiry Regarding 

Income Tax Allowances, 111 FERC ¶ 61,139, at P 32 (2005) (The Commission’s income 

tax policy permits “an income tax allowance for all entities or individuals owning public 

utility assets, provided that entity or individual has an actual or potential income tax 

liability to be paid on that income from those assets.”). 

25 NOPR, FERC Stats. & Regs. ¶ 32,692 at P 11.

26 Id. P 13.
Docket No. RM12-18-000 - 13 -

portion of this differential that is attributable to income taxes under Commission policy, 

and the portion that may be treated as part of an oil pipeline’s actual return on equity. 

2. Comments

24. Several entities filed comments. AOPL requests the Commission clarify what is 

represented by the Composite Tax Rate to be included in proposed line 8a (combined 

federal and state tax rate or something different). ConocoPhillips requests the 

Commission clarify how the income tax allowance reported on line 8 of the illustrative 

Page 700 provided as Appendix B to the NOPR was calculated.

25. A4A and NPGA request that the Commission provide guidance in its order that 

will ensure oil pipelines include a reasonably calculated income tax allowance on Page 

700. A4A and NPGA note that the Commission may want to consider requiring the oil 

pipeline to report the income taxes associated with the collection of equity allowance for 

funds used during construction (AFUDC) depreciation as a separate row to allow parties 

to be able to more easily gauge the reasonableness of the Income Tax Allowance 

calculation, or alternatively, shippers can use 50 percent of the Adjusted Capital Structure 

ratio for Proprietary Capital (row 6b) as an imperfect proxy for the equity portion or 

share of the AFUDC depreciation reported in Line 3. A4A and NPGA also request that 

the Commission clarify how comparable rate of return comparisons should be performed. 

3. Commission Determination

26. The Commission adopts the NOPR’s proposal with AOPL’s requested 

clarification. The Commission clarifies that what is represented by the Composite Tax 

Rate to be included in line 8a is the combined federal and state tax rate as adjusted 

consistent with Commission policy. The Commission simply seeks the tax rate that 
Docket No. RM12-18-000 - 14 -

represents the amount of additional taxes the oil pipeline would be required to pay if it 

earned its exact weighted average cost of capital as reported on line 6e and it collected an 

additional dollar of revenue.

27. As to ConocoPhillips’ request to show how the income tax allowance depicted on 

line 8 of the illustrative Page 700 provided in Appendix B was calculated, the 

Commission declines to do so. As ConocoPhillips’ acknowledges, Appendix B was 

included merely for illustrative purposes and is not precedential.

28. Lastly, the Commission declines to require oil pipelines to report on a separate 

row the income taxes associated with the collection of equity AFUDC depreciation. 

There has been no showing the separate identification of this subcomponent of the total 

income tax allowance will enhance the usefulness of Page 700 in the preliminary 

screening process. Review of an oil pipeline’s calculation of an income tax allowance is 

done in a ratemaking proceeding, and the additional data provided by the Final Rule is 

sufficient for a shipper or interested entity to use Page 700 as a preliminary screening 

tool.

E. Calculation of Actual Rate of Return on Equity

1. NOPR

29. The NOPR proposed modifications to Page 700 that will provide information that 

may be used to calculate an oil pipeline's actual rate of return on equity. The NOPR 

detailed that, for Page 700 purposes, the actual rate of return on equity is determined by 

dividing (a) the actual return on equity by (b) the equity portion of Trended Original Cost 

Rate Base reported on line 5d. The NOPR further pointed out for Page 700 purposes, the 

actual return on equity is the sum of three components that can be derived using the 
Docket No. RM12-18-000 - 15 -

proposed modifications to Page 700: (a) the return on equity embedded in an oil

pipeline’s Page 700 Total Cost of Service (line 7b); (b) the difference, adjusted for taxes, 

between an oil pipeline’s Total Interstate Operating Revenues (line 10) and an oil

pipeline’s Total Cost of Service (line 9);27 and (c) the current year’s inflation related 

earnings that are deferred for subsequent collection, e.g., the contribution to Net Deferred 

Earnings, which is calculated by multiplying the equity portion of the Trended Original 

Cost Rate Base (line 5d) by the current year’s Department of Labor’s consumer price 

index for all urban areas (CPI-U). 

30. Once the actual return on equity has been derived, the NOPR suggested that for 

Page 700 purposes, it may be divided by the equity portion of TOC rate base. Finally, the 

NOPR stated the equity portion of the TOC rate base consists of the TOC rate base 

(proposed line 5d) multiplied by the equity component of capital structure (proposed line 

6b). 

2. Comments

31. AOPL requests that the Commission clarify that the methodology set forth in the

NOPR for calculating the actual rate of return on equity will have no precedential effect, 

and that the proposed calculation is not intended to demonstrate whether oil pipeline rates 

are just and reasonable on the merits within the meaning of the ICA. AOPL points out, 

“the Commission has consistently emphasized the original, limited purpose of Page 700” 

in that Page 700 is only a “preliminary screening tool and is not to be used to demonstrate 

 27 NOPR, FERC Stats. & Regs. ¶ 32,692 at P 14 and n.19.
Docket No. RM12-18-000 - 16 -

the justness and reasonableness of oil pipeline rates.”28 AOPL also observes the 

Commission has stated Form 6 “provide[s] sufficient information to allow shippers to file 

a complaint requesting a determination of the justness and reasonableness of an oil

pipeline’s rates.”29 Therefore, AOPL contends that shippers already have enough 

information with what is already available on Page 700.

32. AOPL argues Form 6 includes historic accounting data that (1) does not contain 

the forward-looking adjustments made during ratemaking; (2) may include non-recurring

items that should be excluded for ratemaking purposes; and (3) might not properly reflect 

the allocation of overhead costs from parent to affiliated companies.30 

33. AOPL further states it is concerned that the ratemaking formula discussed in the 

NOPR does not reflect Commission precedent and established ratemaking principles for 

oil pipelines.

31 For example, AOPL claims that in Opinion No. 351, the Commission 

found that the regulatory method for determining a company’s return allowance is based 

on a weighted cost of capital applied to a single rate base, yet the NOPR purportedly 

references a separate debt and equity rate base component for purposes of computing an 

actual return on equity, which it claims is inconsistent with prior Commission findings. 

Likewise, AOPL disagrees with the statement that “the current year’s contribution to Net 

 28 AOPL Comments at 4 and 12-13.

29 AOPL Comments at 7 (citing Review of FERC Form Nos. 6 and 6-Q, Notice 

Terminating Proceeding, FERC Stats. & Regs. ¶ 35,561, at P 9 (2008)).

30 Id. at 12.

31 Id. at 18-20 (citing NOPR, FERC Stats. & Regs. ¶ 32,692 at PP 14-15).
Docket No. RM12-18-000 - 17 -

Deferred Earnings represents equity return the carrier has collected in its current rates.”

32 

To this end, AOPL suggests that under the TOC methodology the current year’s 

contribution to deferred earnings is not collected in the current period, but is instead 

accrued in rate base and amortized over the remaining life of the asset. 

34. AOPL asserts that the additional information is not necessary or appropriate for 

ensuring that Page 700 can be used for its intended purpose of allowing a shipper to make 

a threshold determination as to whether to challenge an oil pipeline’s rates. AOPL states 

that the proposed additional line items do not further the Commission’s objective of 

ensuring that page 700 is a useful preliminary screening tool. 

35. Mr. Gooch states that the NOPR’s calculation of the actual return on equity allows

for an income tax allowance prior to the calculation of a profit, to which Mr. Gooch 

strongly objects. Mr. Gooch states that consumers would essentially be paying the 

income taxes that might be incurred on unlawful and prohibited revenues, violating the 

ICA.

3. Commission Determination

36. The Commission will adopt the NOPR’s use of a calculation of an actual rate of 

return on equity. As the NOPR reasoned, the actual rate of return on equity is 

particularly useful information when using Page 700 as a preliminary screen to evaluate 

whether additional proceedings may be necessary to challenge rates consistent with the 

Commission’s mandate under the ICA. 

 32 Id. at 19-20.
Docket No. RM12-18-000 - 18 -

37. The proposed formula for calculating the actual return on equity in the NOPR does 

not have precedential effect for ratemaking purposes nor does it demonstrate alone 

whether a pipeline’s rates are just and reasonable. Consistent with the historic purpose of 

Page 700 as a preliminary screening tool, the Commission affirms the NOPR’s method 

for calculating the actual rate of return on equity is for preliminary screening purposes 

only. The proposal does not establish a formula for setting oil pipeline rates in a 

particular rate case.

38. Accordingly, the calculation of the actual rate of return formula on Page 700 does 

not change the Commission’s ratemaking policies. The Commission agrees with AOPL 

that Opinion No. 351 outlined how the total return on equity should be calculated for the 

purpose of setting oil pipeline rates. 33 Here, in contrast, the proposed calculation is for 

the calculation of an actual return on equity only. The Commission’s actions in this Final 

Rule do not change the Commission’s ratemaking policies in Opinion No. 351. Nor does 

the formula, which is for preliminary screening purposes only, alter the Commission’s

 33 Opinion No. 351-A, 53 FERC at 62,388-89. The Commission clarified the 

Opinion No. 154-B methodology for calculating a total return for oil pipeline ratemaking 

purposes in Opinion No. 351. 
Docket No. RM12-18-000 - 19 -

ratemaking policies regarding test period adjustments, net deferred earnings,34 or the 

calculation of an oil pipeline’s return. Nor do the changes to Page 700 alter the standards 

and burdens of proof applied by the Commission when it rules on complaints, petitions, 

or other requests for relief based on a full record and substantial evidence. Finally, the 

Commission emphasizes that the additions to Page 700 neither affect existing rates nor 

change any rate on file. Rather, the requested data provide the Commission and 

interested entities with information that will help them make a reasonable assessment of 

an oil pipeline's actual rate of return on equity for preliminary screening purposes at any 

particular time.

39. The Commission rejects Mr. Gooch’s contention that the NOPR’s calculation of 

the actual return on equity inappropriately adjusts for income taxes. The difference 

between an oil pipeline’s Total Interstate Operating Revenues (line 10) and an oil

pipeline’s Total Cost of Service (line 9) may be subject to income taxes. Any portion of 

this differential attributable to income taxes is an expense and is not part of the return to 

the oil pipeline’s owners. Thus, the NOPR correctly removed the portion attributable to 

income taxes from the calculation of the oil pipeline’s actual return on equity. 

 34 In a rate proceeding to set oil pipeline rates, the Commission recognizes that the 

inflation related return is earned in the current period but the collection thereof is deferred 

to later periods through an amortization process over the remaining life of an oil pipeline. 

This is similar to the calculation of a regulatory asset, which may be recognized for 

financial purposes in the current period but included in rate base and collected over the 

life of the asset for ratemaking purposes. 
Docket No. RM12-18-000 - 20 -

40. In discussing the NOPR’s estimate of an actual return on equity, AOPL states that 

Page 700 may not properly reflect the allocation of overhead costs from parent and 

affiliated companies.35 The instructions to Page 700 state that reported information “shall 

be computed consistent with the Commission’s Opinion No. 154-B et al. methodology.” 

The Commission expects Form 6 respondents to properly populate each entry to reflect 

Commission precedent.

F. Miscellaneous Recommendations

1. Comments

41. Commenters raised a number of additional issues. Mr. Gooch advocates 

compelling oil pipelines to report excess profits in footnotes to Page 700. Mr. Gooch 

also advocates that the oil pipelines be required to state, under oath, that all of their rates 

are just and reasonable under the Commission’s definition. 

42. All the commenters except AOPL advocate for companies that file Form 6 for 

multiple oil pipeline systems to file separate Page 700s for each segment, service, or rate 

schedule.36 Similarly, several commenters advocate for the Commission to require oil

pipelines to file or make available workpapers.

37 CAPP also asked the Commission to

clarify the relationship between the entity that files Page 700 and the oil pipeline services 

 35 AOPL Comments at 13-15.

36 CAPP Comments at 4; A4A and NPGA Comments at 15-23; Valero Comments 

at 21-24; ConocoPhillips Comments at 3-4; Suncor Comments at 2-3; and BP Comments 

at 2-3.

37 A4A and NPGA Comments at 24; and ConocoPhillips Comments at 4.
Docket No. RM12-18-000 - 21 -

for which a return on equity is intended to be generated. A4A and NPGA also request 

that the Commission require oil pipelines to file Form 6 before they can file for an index 

rate increase.

38 Valero requests that Page 700 be amended to include Jurisdictional 

Allowance Oil Revenue, storage, demurrage revenue, rental revenue, and incidental 

revenue. Valero also requests that an oil pipeline identify and justify the exclusion of any 

such revenue as non-jurisdictional.39

43. Parties also raised issues not involving Form 6. For example, Mr. Gooch raises 

issues related to alleged over-recoveries by certain oil pipelines.

40 A4A and NPGA as 

noted above request that the Commission require oil pipelines to file Form 6 before they 

can file for an index rate increase; they also ask that the interest rate applicable to refunds 

and reparations reflect the oil pipeline’s rate of return as reported on page 700.41 

44. In its reply comments, AOPL objects that many of the comments are beyond the 

scope of the NOPR. AOPL adds that many of the proposed revisions have been raised in 

other proceedings such as (1) proposals to segregate Form 6 and Page 700 data by oil 

pipeline system and (2) proposals to require oil pipelines to file their Page 700 

 38 A4A and NPGA Comments at 25.

39 Valero Comments at 11-16. In its reply comments, Suncor requests that the 

Commission amend line 10 of Page 700 as Valero suggests. Suncor Reply Comments at 

3.

40 Mr. Gooch Comments at 1-8.

41 A4A and NPGA Comments at 23-26.
Docket No. RM12-18-000 - 22 -

workpapers with Form 6, and the Commission has rejected them.

42 As to the proposals to 

add workpapers, AOPL further suggests that the commenters have not raised any new

arguments and the Commission should again reject the proposals.43 Finally, AOPL asks 

the Commission to reject Valero’s proposed changes because Valero is attempting to 

relitigate the outcomes of previous index rate proceedings.44

2. Commission Determination

45. In this Final Rule, the Commission modifies Page 700 to require entities to 

provide additional information regarding rate base, rate of return, return on rate base, and 

income tax allowance on Page 700. These revisions provide increased transparency and 

information to assist the Commission and the public in calculating an oil pipeline’s return 

on equity for preliminary screening purposes. Given the limited nature of the NOPR, the 

Commission is not adopting additional changes to Form 6, such as the segregation of data 

or changing Commission policy to make available oil pipeline cost-of-service 

workpapers. Other issues, such as the Commission’s indexing policies, may be addressed 

as they arise in actual proceedings.

G. Conclusion

46. As discussed herein, the proposed modifications will facilitate the calculation of 

the actual rate of return on equity based upon Page 700 data. The actual rate of return on 

 42 AOPL Reply Comments at 8-22.

43 Id. at 24-26.

44 Id. at 24.
Docket No. RM12-18-000 - 23 -

equity is particularly useful information when using Page 700 to conduct a preliminary 

evaluation of an oil pipeline’s rates. The additional information proposed to be reported 

will impose almost no additional burden on oil pipelines because oil pipelines already 

must develop cost of service supporting the information reported on Page 700. 

H. Effective Date

47. The changes to Form 6 are to be effective for reporting in the 2013 Form 6. The 

2013 Form 6 must be filed on or before April 18, 2014.45 The new schedule appearing on 

Page 700 therefore will be required for Form 6 filings as of April 18, 2014, for the 

reporting year ending December 31, 2013.

V. Information Collection Statement

A. The NOPR

48. In the NOPR, in accordance with the Paperwork Reduction Act and the

requirements of the Office of Management and Budget (OMB), the Commission solicited 

comment on the Commission’s need for this information, whether the information will 

have practical utility, the accuracy of provided burden estimates, ways to enhance the 

quality, utility, and clarity of the information to be collected, and any suggested methods 

for minimizing the respondent’s burden, including the use of automated information 

techniques.46 The Commission also informed respondents that they will not be penalized

 45 18 CFR 357.1.

46 NOPR, FERC Stats. & Regs. ¶ 32,692 at P 20.
Docket No. RM12-18-000 - 24 -

for failing to respond to this collection of information unless the collection displays a 

valid OMB control number.

49. The Commission estimated the additional average annual Public Reporting cost 

imposed on oil pipelines providing interstate services related to this Final Rule to be 

$3,037.47 The Commission estimated the additional Public Reporting Burden related to 

this Final Rule for the recurring effort involved in filing the data on proposed lines 5a-5c, 

6a-6e, 7a-7c, and 8a of Page 700 for 2013 and future years, to be 0.5 hours per year per 

respondent. The Commission estimated there are 153 filers that will be affected each 

year by the change in filing requirements.

48 The number of filers is reduced from 166 to 

153 through 2012 filers and exclusion of TAPS oil pipelines. 

B. Comments

50. No entity directly commented on the Commission’s initial burden estimates that 

were included in the NOPR. 

C. Commission Determination

51. The Commission has reviewed the burdens imposed by this Final Rule. The 

Commission did not impose any additional filing requirements as proposed by various 

commenters to require the oil pipelines to file additional information beyond that 

 47 Id.

48 The TAPS oil pipelines are exempt from filing Page 700. Section 1804(2)(B) of 

the Energy Policy Act of 1992 excludes from the provisions of the Act, for ratemaking 

purposes, TAPS and any oil pipeline delivering oil directly or indirectly to TAPS. 

Therefore, the Commission exempted the TAPS entities from having to submit the 

information required on Page 700. Order No. 571, FERC Stats. & Regs. ¶ 31,006 at 

31,175.
Docket No. RM12-18-000 - 25 -

included in the NOPR. The additional lines included in the NOPR and Final Rule are 

needed steps to calculate information already reported in the Form 6. Therefore, there is 

no additional Public Reporting Burden associated with the Final Rule. The 

Commission’s estimate of the Public Reporting Burden imposed on oil pipelines by this 

Final Rule is the same as shown in the NOPR and copied in the table below.

RM12-18-000, 

FERC Form 6

Annual No. 

of Filers

Estimated 

Additional 

Burden per 

Filer (Hr.)

Total 

Estimated 

Additional 

Burden 

(Hr.)

Estimated 

Additional 

Cost per 

Filer ($)49

Total 

Estimated 

Additional 

Cost ($)

Filing new 

proposed lines 

on page 700 153 0.5 77 $34.51 $2,657.88

Title: FERC Form 6, Annual Report of Oil Pipeline Companies

Action: Revisions to the FERC Form 6

OMB Control No: 1902-0022

Respondents: Oil pipelines

Frequency of Responses: Annual.

Necessity of the Information: This action ensures the availability of data 

consistent with the Commission’s obligation to regulate interstate oil and 

petroleum product oil pipeline rates and the intent of Page 700, to enable the 

Commission and shippers to monitor and analyze interstate oil pipeline costs.

 49 Based on an estimated average cost per employee for 2012 (including salary 

plus benefits) of $143,540, the estimated average hourly cost per employee is $69.01. 

The average work year is 2,080 hours.
Docket No. RM12-18-000 - 26 -

Internal review: The Commission has reviewed the changes and has determined 

that the changes are necessary. These requirements conform to the Commission’s 

need for efficient and sufficient information collection, communication, and 

management with regard to the oil pipeline sector of the energy industry. The 

Commission has, by means of internal review, assured itself that there is specific, 

objective support for the burden estimates associated with the information 

collection requirements.

Interested persons may obtain information on the reporting requirements by contacting: 

Federal Energy Regulatory Commission, 888 First Street, NE, Washington, DC 20426 

[Attention: Ellen Brown, Office of the Executive Director, email: DataClearance@ferc.gov, Phone: (202) 502-8663, fax: (202) 273-0873]. 

Comments on the requirements of this rule may also be sent to the Office of Information 

and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 

[Attention: Desk Officer for the Federal Energy Regulatory Commission]. For security 

reasons, comments should be sent by e-mail to OMB at oira_submission@omb.eop.gov. 

Please reference OMB Control No. 1902-0022, FERC-6 and the docket number of this

rulemaking in your submission.

VI. Environmental Analysis

52. The Commission is required to prepare an Environmental Assessment or an 

Environmental Impact Statement for any action that may have a significant adverse effect 

on the human environment. The actions taken here fall within categorical exclusions in 
Docket No. RM12-18-000 - 27 -

the Commission’s regulations for information gathering, analysis, and dissemination. 50 

Therefore, an environmental assessment is unnecessary and has not been prepared in this 

rulemaking. 

VII. Regulatory Flexibility Act

53. The Regulatory Flexibility Act of 1980 (RFA) generally requires agencies to 

prepare certain statements, descriptions, and analyses of proposed rules that will have a 

significant economic impact on a substantial number of small business entities.51 

Agencies are not required to make such an analysis if a rule would not have such an 

effect. 

54. The Commission does not believe that this Final Rule will have an adverse impact 

on small entities, nor will it impose upon them any significant costs of compliance. The 

Commission identified 29 small entities as respondents to the requirements in the Final 

Rule.

52 As explained above, the Commission estimates that the change to Page 700 will 

increase the paperwork burden of preparing Page 700 by approximately $34.51 per 

respondent. The Commission does not estimate that there are any other regulatory 

burdens associated with this proposed rule. Therefore the Commission certifies that the 

 50 18 CFR 380.4(a)(5).

51 5 USC 601-12.

52 The RFA definition of small entity refers to the definition provided in the Small 

Business Act, which defines a small business concern as a business that is independently 

owned and operated and that is not dominant in its field of operation. 15 USC 632. The 

Small Business Size Standards component of the North American Industry Classification 

System defines a small oil pipeline company as one with less than 1,500 employees. See

13 CFR 121, 201. 
Docket No. RM12-18-000 - 28 -

proposed rule will not have a significant impact on a substantial number of small entities. 

Accordingly, no regulatory flexibility analysis is required.

VIII. Document Availability

55. In addition to publishing the full text of this document in the Federal Register, the 

Commission provides all interested persons an opportunity to view and/or print the 

contents of this document via the Internet through FERC's Home Page 

(http://www.ferc.gov) and in FERC's Public Reference Room during normal business 

hours (8:30 a.m. to 5:00 p.m. Eastern time) at 888 First Street, NE, Room 2A, 

Washington DC 20426.

56. From FERC's Home Page on the Internet, this information is available on 

eLibrary. The full text of this document is available on eLibrary in PDF and Microsoft 

Word format for viewing, printing, and/or downloading. To access this document in 

eLibrary, type the docket number excluding the last three digits of this document in the 

docket number field.

57. User assistance is available for eLibrary and the FERC’s website during normal 

business hours from FERC Online Support at (202) 502-6652 (toll free at 1-866-208-

3676) or email at ferconlinesupport@ferc.gov, or the Public Reference Room at (202) 

502-8371, TTY (202) 502-8659. E-mail the Public Reference Room 

at public.referenceroom@ferc.gov.
Docket No. RM12-18-000 - 29 -

IX. Effective Date and Congressional Notification

58. In the NOPR the Commission proposed that the changes to Form 6 to be effective 

for reporting in the 2013 FERC Form No.6. The 2013 Form 6 must be filed on or before 

April 18, 2014.53 The new schedule appearing on Page 700 therefore would not be 

required for Form 6 filings until April 18, 2014, for the reporting year ending 

December 31, 2013. The Final Rule is effective sixty (60) days after the rule is published 

in the Federal Register.

59. The Commission has determined, with the concurrence of the Administrator of the 

Office of Information and Regulatory Affairs of OMB that this rule is not a major rule as 

defined in section 351 of the Small Business Regulatory Enforcement Fairness Act of 

1996.

By the Commission.

( S E A L )

Kimberly D. Bose,

Secretary.

 53 18 CFR 357.2(b)(2).
Docket No. RM12-18-000 - 30 -

Note: Appendix A will not be published in the Code of Federal Regulations.

Appendix A- Summary of Proposed Changes to FERC Form 6, Page 700

Line 5a is added to read as follows:

Rate Base – Original Cost

Line 5b is added to read as follows:

Rate Base – Unamortized Starting Rate Base Write-Up

Line 5c is added to read as follows:

Rate Base – Accumulated Net Deferred Earnings

Line 5d is added to read as follows:

Total Rate Base – Trended Original Cost – (line 5a + line 5b+ line 5c)

Line 6a is added to read as follows:

Rate of Return – Adjusted Capital Structure Ratio for Long Term Debt

Line 6b is added to read as follows:

Rate of Return – Adjusted Capital Structure Ratio for Stockholders’ Equity

Line 6c is added to read as follows:

Rate of Return – Cost of Long Term Debt Capital

Line 6d is added to read as follows:

Rate of Return – Real Cost of Stockholders’ Equity

Line 6e is added to read as follows:

Rate of Return – Weighted Average Cost of Capital – (line 6a x line 6c + line 6b x line 

6d)

Line 7 is edited to read as follows:

Return on Trended Original Cost Rate Base

Line 7a is added to read as follows:

Return on Rate Base – Debt Component – (line 5d x line 6a x line 6c)

Line 7b is added to read as follows:

Return on Rate Base – Equity Component – (line 5d x line 6b x line 6d)

Line 7c is added to read as follows:

Total Return on Rate Base – (line 7a + line 7b)

Line 8a is added to read as follows:
Docket No. RM12-18-000 - 31 -

Composite Tax Rate % (37.50% - 37.50)
Docket No. RM12-18-000 - 32 -

Note: Appendix B will not be published in the Code of Federal Regulations.

Appendix B: Revised Page 700 to Form 6

Name of Respondent This Report Is:

□ (1) An Original

□ (2) A Resubmission

Date of Report

(Mo, Da, Yr)

/ /

Year/Period of Report

End of ________

Annual Cost of Serv ice Based Analysis Schedule

1.) Use footnotes when particulars are required or for any explanations.

2.) Enter on lines 1-9, columns (b) and (c), the value the respondent's Operating & Maintenance Expenses, Depreciation Expense, 

AFUDC Depreciation, Amortization of Deferred Earnings, Rate Base, Rate of Return, Return, Income Tax Allowance, and Total Cost 

of Service, respectively, for the end of the current and previous calendar years. The values shall be computed consistent with the 

Commission's Opinion No. 154-B et al. methodology. Any item(s) not applicable to the filing, the oil pipeline company shall report 

nothing in columns (b) and (c).

3.) Enter on line 10, columns (b) and (c), total interstate operating revenue, as reported on page 301, for the current and previous 

calendar years.

4.) Enter on line 11, columns b and c, the interstate throughput in barrels for the current and previous calendar years.

5.) Enter on line 12, columns b and c, the interstate throughput in barrel-miles for the current and previous calendar years.

6.) If the company makes major changes to its application of the Opinion No. 154-B et al. methodology, it must describe such changes in 

a footnote, and calculate the amounts in columns (b) and (c) of lines No. 1-12 using the changed application.

7.) A respondent may be requested by the Commission or its staff to provide its workpapers which support the data reported on page 

700.

Line 

No.

Item 

(a)

Current Year Amount 

(in dollars) 

(b) 

Prior Year Amount 

(in dollars) 

(c)

1 Operating and Maintenance Expenses 25,000,000 24,500,000 

2 Depreciation Expense 6,500,000 6,450,000 

3 AFUDC Depreciation 500,000 510,000 

4 Amortization of Deferred Earnings 800,000 840,000 

5 Rate Base

5a Rate Base – Original Cost 90,000,000 94,000,000 

5b Rate Base – Unamortized Starting Rate Base Write-Up

5c Rate Base – Accumulated Net Deferred Earnings 20,000,000 21,000,000 

5d Total Rate Base –Trended Original Cost – (line 5a + line 5b + line 5c) 110,000,000 115,000,000 

6 Rate of Return % (10.25% - 10.25)

6a Rate of Return – Adjusted Capital Structure Ratio for Long Term Debt 36.00 36.00 

6b Rate of Return – Adjusted Capital Structure Ratio for Stockholders’ 

Equity 64.00 64.00 

6c Rate of Return – Cost of Long Term Debt Capital 8.00 8.00 

6d Rate of Return – Real Cost of Stockholders’ Equity 14.25 14.25 

6e Rate of Return – Weighted Average Cost of Capital – (line 6a x line 6c + 

line 6b x line 6d) 12.00 12.00 

7 Return on Trended Original Cost Rate Base

7a Return on Rate Base – Debt Component – (line 5d x line 6a x line 6c) 3,168,000 3,312,000 

7b Return on Rate Base – Equity Component – (line 5d x line 6b x line 6d) 10,032,000 10,488,000 

7c Total Return on Rate Base – (line 7a + line 7b) 13,200,000 13,800,000 

8 Income Tax Allowance 9,000,000 9,400,000 

8a Composite Tax Rate % (37.50% - 37.50) 37.50 37.50 

9 Total Cost of Service 55,000,000 55,500,000 

10 Total Interstate Operating Revenues 60,000,000 57,000,000 

11 Total Interstate Throughput in Barrels 80,000,000 79,000,000 

12 Total Interstate Throughput in Barrel-Miles 40,000,000,000 39,000,000,000 

FERC Form No. 6 (REV 12/12) Page 700