Columbia Gas Transmission, LLC tel fax...

October 6, 2017 Ms. Kimberly D. Bose, Secretary Federal Energy Regulatory Commission 888 First Street, N.E. Washington, D.C. 20426

Columbia Gas Transmission, LLC 700 Louisiana Street, Suite 700 Houston, Texas 77002-2700 John A. Roscher Director, Rates & Tariffs tel 832.320.5675 fax 832.320.6675 email [email protected] web www.columbiapipeinfo.com/infopost/

Re: Columbia Gas Transmission, LLC

Compliance Filing, Docket No. CP15-514-000 Docket No. RP18-_____-_____ Dear Ms. Bose: Pursuant to Section 4 of the Natural Gas Act (“NGA”) and Part 154 of the Federal Energy

Regulatory Commission’s (“FERC” or “Commission”) regulations,1 Columbia Gas Transmission,

LLC (“Columbia”) hereby submits for filing certain tariff sections2 to be part of its FERC Gas

Tariff, Fourth Revised Volume No. 1 (“Tariff”). These revised tariff sections are being submitted

to comply with the Commission’s January 19, 2017, Order Issuing Certificates and Approving

Abandonment in Docket No. CP15-514-000.3 Columbia respectfully requests that the

Commission accept the proposed tariff sections, included in the instant filing as Appendix A, to

become effective November 6, 2017.

1 18 C.F.R. Part 154 (2017). 2 Specifically, Part I. Table of Contents (“Table of Contents”); and Part V.21. Currently Effective Rates, FTS-LXP Rates (“FTS-LXP Rates”). 3 Columbia Gas Transmission, LLC, 158 FERC ¶ 61,046 (2017) (“January 19 Order”).

2

Correspondence The names, titles, mailing addresses, and telephone numbers of those persons to whom

correspondence and communications concerning this filing should be addressed are as follows:

*

John A. Roscher Director, Rates & Tariffs Joan F. Collins Manager, Tariffs and Compliance Columbia Gas Transmission, LLC 700 Louisiana Street, Suite 700 Houston, Texas 77002-2700 Tel. (832) 320-5651 E-mail: [email protected]

* William A. Sala, Jr. Senior Counsel Columbia Gas Transmission, LLC 700 Louisiana Street, Suite 700 Houston, Texas 77002-2700 Tel. (832) 320-5067 E-mail: [email protected]

* Persons designated for official service pursuant to Rule 2010.

Statement of the Nature, Reasons and Basis for Filing On June 8, 2015, Columbia filed an abbreviated application pursuant to sections 7(b) and 7(c) of

the NGA4 and Part 157 of the Commission’s regulations (“Application”),5 requesting

authorization to construct and operate the Leach XPress Project (“LXP”),6 in order to provide up

to 1,530,000 dekatherms (“Dth”) per day of firm transportation service on Columbia’s system from

the Appalachian Basin to certain Ohio markets, Columbia’s TCO Pool, and an interconnection

with Columbia Gulf Transmission, LLC (“Columbia Gulf”) near Leach, Kentucky.7 As part of its

Application, Columbia submitted a pro forma tariff section, FTS-LXP Rates, which set forth an

initial incremental recourse rate designed to recover costs associated with transportation service

provided on LXP facilities.

4 15 U.S.C. § 717f(b), (c) (2012). 5 18 C.F.R. Part 157 (2017). 6 LXP, located in West Virginia, Pennsylvania, and Ohio, includes two greenfield pipeline segments, two natural gas pipeline loops, three greenfield compressor stations, and three additional compressor units at existing stations, with certain of these pipeline and compression facilities designed to replace existing facilities proposed to be abandoned as part of LXP. 7 On July 29, 2015, Columbia Gulf filed an application in Docket No. CP15-539-000, requesting authorization to construct and operate the Rayne XPress Project, designed to provide additional firm transportation service from the Leach, Kentucky interconnect with Columbia.

3

The Commission’s January 19 Order directed Columbia to:

1. classify certain LXP-related expenses as variable costs consistent with a

straight-fixed-variable rate design, recalculate its LXP incremental recourse reservation

charge to recover only fixed costs, and recover any variable costs through a usage charge;8

2. reflect in its recalculated incremental LXP recourse charge a reduced cost allocation

associated with the Lone Oak Compressor Station;9

3. utilize billing determinants of 1,530,000 Dth per day when recalculating the LXP

incremental reservation charge,10 and

4. charge Columbia’s currently-applicable system usage charge for the project.11

To comply with the Commission’s January 19 Order and the conditions included therein and

enumerated above, Columbia is submitting revised Exhibits K, N, and P12 that reflect a

recalculated LXP incremental recourse rate. The recalculated recourse reservation rate reflects the

removal of certain non-labor Operation and Maintenance expenses, a reduced cost allocation

associated with the Lone Oak Compressor Station, and an increase to the billing determinants

utilized for LXP, all in accordance with the Commission’s directives in the January 19 Order. As

a result of these changes, the recalculated reservation charge reflects an overall reduction from

$14.033 per Dth to $13.569 per Dth. Additionally, as directed by the January 19 Order, Columbia

will utilize its currently-applicable system usage charge for the project, as the calculated

incremental LXP usage charge reflected in the revised Exhibit P submitted herein is lower than

the Columbia usage charge currently in effect. As further required by the January 19 Order,

Columbia is submitting, as part of Appendix A, live tariff section FTS-LXP Rates to place into

8 January 19 Order at P 36. In the Application, Columbia, as part of its cost of service, allocated a total of $2,984,220 in non-labor Operation and Maintenance expenses as fixed costs when, more appropriately, the expenses should be classified as variable costs. 9 January 19 Order at P 37. Columbia’s estimated utilization of the third compressor unit at the Lone Oak Compressor Station dropped from approximately 62 percent capacity, as reflected in the Application, to 54 percent, as reflected in a February 24, 2016, data response. 10 January 19 Order at P 38. In the Application, Columbia designed its initial incremental reservation charge based on billing determinants of 1,500,000 Dth per day. However, as constructed, the LXP facilities provide 1,530,000 Dth per day of additional firm transportation service. 11 January 19 Order at P 40. 12 Exhibit K-Cost of Facilities; Exhibit N-Revenue, Expenses, and Income; and Exhibit P-Tariff.

4

effect the recalculated incremental reservation charges applicable to the LXP shippers.13

Additionally, Columbia is submitting a revised Table of Contents herein as part of Appendix A to

reflect the addition of FTS-LXP Rates14 within the Currently Effective Rates portion of its Tariff.

Columbia respectfully requests that the Commission accept the FTS-LXP Rates and Table of

Contents sections submitted herein as Appendix A to become effective November 6, 2017.

Effective Date Columbia respectfully requests that the Commission accept the tariff sections included as

Appendix A to become effective as requested herein.

Other Filings Which May Affect This Proceeding There are no other filings before the Commission that may significantly affect the changes

proposed herein.

Contents of Filing In accordance with Section 154.7 of the Commission’s regulations, Columbia is submitting the

following via its electronic tariff filing:

1. This transmittal letter;

2. A clean version of the tariff sections (Appendix A);

3. A marked version of the tariff sections (Appendix B); and

4. Revised Exhibits K, N, and P (Appendix C).

13 January 19 Order at ordering paragraph (F). As Columbia anticipates an in-service date of November 6, 2017, the instant filing meets the requirement set forth in the January 19 Order that Columbia file actual tariff records with the recalculated incremental charge no earlier than 60 days, and no later than 30 days, prior to the date the project facilities go into service. 14 Additionally, FTS-LXP Rates reflects the most recently approved: a) Transportation Costs Rate Adjustment (TCRA), Columbia Gas Transmission, LLC, Docket No. RP17-473-000 (March 16, 2017) (unpublished Director’s Letter Order); b) Electric Power Costs Adjustment (EPCA), Columbia Gas Transmission, LLC, Docket No. RP17-466-000 (March 29, 2017) (unpublished Director’s Letter Order); and c) Operational Transaction Rate Adjustment (OTRA), Columbia Gas Transmission, LLC, Docket No. RP17-588-000 (April 25, 2017) (unpublished Director’s Letter Order).

5

Certificate of Service As required by Sections 154.7(b) and 154.208 of the Commission’s regulations, copies of this

filing are being served upon all parties in this proceeding, all of Columbia’s existing customers

and interested state regulatory agencies. A copy of this letter, together with any attachments, is

available for public inspection during regular business hours at Columbia’s principal place of

business.

Pursuant to Section 385.2005 and Section 385.2011, the undersigned has read this filing and knows

its contents, and the contents are true as stated, to the best of his knowledge and belief. The

undersigned possesses full power and authority to sign such filing.

Any questions regarding this filing may be directed to Joan Collins at (832) 320-5651.

Respectfully submitted, COLUMBIA GAS TRANSMISSION, LLC

John A. Roscher Director, Rates & Tariffs Enclosures

Appendix A

Columbia Gas Transmission, LLC - FERC Gas Tariff, Fourth Revised Volume No. 1

Clean Tariff

Tariff Section Version Part I. – Table of Contents 13.0.0 Part V.21. – Currently Effective Rates, FTS-LXP Rates 0.0.0

Columbia Gas Transmission, LLC Part I.

FERC Tariff Table of Contents

Fourth Revised Volume No. 1 Version 13.0.0

Issued On: October 6, 2017 Effective On: November 6, 2017

TABLE OF CONTENTS

Volume No. 1

Part I. Table of Contents

Part II. Preliminary Statement

Part III. Map of Market Areas

Part IV. Index of Market Areas

Part V. Currently Effective Rates

Section 1. FTS

Section 2. FTS-APX

Section 3. NTS and NTS-S

Section 4. ITS

Section 5. GTS

Section 6. OPT

Section 7. TPS

Section 8. SST

Section 9. FSS

Section 10. ISS

Section 11. SIT

Section 12. FBS

Section 13. PAL

Section 14. Gathering

Section 15. FT-C





Section 16. LNG

Section 17. Retainage

Section 18. FTS-GC

Section 19. FTS-ESE

Section 20. NTS-ESE

Section 21. FTS-LXP

Part VI. Rate Schedules

Section 1. Firm Transportation Service (FTS)

Section 2. No Notice Transportation Service (NTS)

Section 3. Summer Hourly No Notice Transportation Service (NTS-S)

Section 4. Interruptible Transportation Service (ITS)

Section 5. General Transportation Service (GTS)

Section 6. Off-Peak Firm Transportation Service (OPT)

Section 7. Third Party Storage Transportation (TPS)

Section 8. Storage Service Transportation (SST)

Section 9. Firm Storage Service (FSS)

Section 10. Firm Storage with Market-Based Rates (FSS-M)

Section 11. Interruptible Storage Service (ISS)

Section 12. Interruptible Storage Service with Market-Based Rates (ISS-M)

Section 13. Storage In Transit Service (SIT)

Section 14. Firm Balancing Service (FBS)

Section 15. Parking and Lending Service (PAL)





Section 16. Aggregation Service (AS)

Section 17. Interruptible Paper Pools (IPP)

Section 18. Merchant Sales Service (MS)

Section 19. LNG Storage Service (LSS)

Section 20. Firm Transportation Service – Commonwealth (FT-C)





Part VII. General Terms and Conditions

Part VIII. Form of Service Agreement for Service Under:

Section 1. Rate Schedules FTS, NTS, NTS-S, SST, OPT, ITS, GTS, and TPS

Section 2. Rate Schedule FSS

Section 3. Rate Schedule FSS-M

Section 4. Rate Schedule ISS

Section 5. Rate Schedule ISS-M

Section 6. Rate Schedule SIT

Section 7. Rate Schedule FBS

Section 8. Rate Schedule PAL

Section 9. Rate Schedule Auto PAL

Section 10. Rate Schedule AS

Section 11. Rate Schedule IPP

Section 12. Reference to Customers Having Non-Conforming Service

Agreements Pursuant to Section 154.112(B) of the Commission's

Regulations

Section 13. Rate Schedule FT-C

Part IX. Multi-Party Form of Service Agreement for Service Under:

Section 1. Rate Schedules FTS, NTS, NTS-S, TPS and OPT

Section 2. Reserved for Future Use








Volume No. 2

Special Rate Schedules

X-2 Transportation Agreement with Kentucky West Virginia Gas Company

X-20 Agreement for the sale of natural gas from Well No. A-584 to Consolidated Gas Supply

Corporation

X-35 Exchange Agreement with Consolidated Gas Supply Corporation

X-36 Exchange Agreement with Texas Eastern Transmission Corporation

X-39 Exchange Agreement with Washington Gas Light Company

X-54 Transportation Agreement with City of Somerset, Kentucky


X-97 Transportation Agreement with Orange and Rockland Utilities, Inc.

X-99 Transportation and Exchange Agreement with Equitable Gas Company

X-103 Exchange Agreement with Transcontinental Gas Pipe Line Corporation

X-123 Transportation and Exchange Agreement with Tennessee Gas Pipeline Company


X-131 Liquefied Natural Gas Storage Service Agreement with the City of Richmond, Virginia

X-132 Liquefied Natural Gas Storage Service Agreement with Commonwealth Gas Services,

Inc.

X-133 Liquefied Natural Gas Storage Service Agreement with Virginia Natural Gas, Inc.

Columbia Gas Transmission, LLC V.21.

FERC Tariff Currently Effective Rates

Fourth Revised Volume No. 1 FTS-LXP Rates

Version 0.0.0


Currently Effective Rates

Applicable to Rate Schedule FTS-LXP

Incremental Leach XPress Service

Rate Per Dth

Base Tariff

Rate

1/ 2/

TCRA

Rates

EPCA

Rates

OTRA

Rates

CCRM

Rates

Total

Effective Rate

2/

Daily

Rate

2/

Rate Schedule FTS-LXP

Reservation Charge 3/ $ 13.569 0.205 0.065 0.112 0.000 13.951 0.4587

Commodity

Maximum ¢ 1.04 0.03 1.04 0.00 0.00 2.11 2.11

Minimum ¢ 1.04 0.03 1.04 0.00 0.00 2.11 2.11

Overrun

Maximum ¢ 45.65 0.70 1.25 0.37 0.00 47.98 47.98

Minimum ¢ 1.04 0.03 1.04 0.00 0.00 2.11 2.11

1/ Excludes Account 858 expenses and Electric Power Costs which are recovered through Columbia's Transportation Costs Rate

Adjustment (TCRA) and Electric Power Costs Adjustment (EPCA), respectively.

2/ Excludes the Annual Charge Adjustment (ACA) Surcharge. An ACA Commodity surcharge per Dth shall be assessed where

applicable pursuant to Section 154.402 of the Commission’s Regulations and in accordance with Section 34 of the GTC of

Transporter’s FERC Gas Tariff. The ACA unit charge authorized for each fiscal year (commencing October 1) by the

Commission and posted on its website (http://www.ferc.gov) is incorporated herein by reference.

3/ Minimum reservation charge is $0.00.

Appendix B

Columbia Gas Transmission, LLC - FERC Gas Tariff, Fourth Revised Volume No. 1

Marked Tariff

Tariff Section Version Part I. – Table of Contents 13.0.0 Part V.21. – Currently Effective Rates, FTS-LXP Rates 0.0.0





TABLE OF CONTENTS

Volume No. 1

Part I. Table of Contents

Part II. Preliminary Statement

Part III. Map of Market Areas

Part IV. Index of Market Areas

Part V. Currently Effective Rates

Section 1. FTS

Section 2. FTS-APX

Section 3. NTS and NTS-S

Section 4. ITS

Section 5. GTS

Section 6. OPT

Section 7. TPS

Section 8. SST

Section 9. FSS

Section 10. ISS

Section 11. SIT

Section 12. FBS

Section 13. PAL

Section 14. Gathering

Section 15. FT-C





Section 16. LNG

Section 17. Retainage

Section 18. FTS-GC

Section 19. FTS-ESE

Section 20. NTS-ESE

Section 21. FTS-LXP

Part VI. Rate Schedules

Section 1. Firm Transportation Service (FTS)

Section 2. No Notice Transportation Service (NTS)

Section 3. Summer Hourly No Notice Transportation Service (NTS-S)

Section 4. Interruptible Transportation Service (ITS)

Section 5. General Transportation Service (GTS)

Section 6. Off-Peak Firm Transportation Service (OPT)

Section 7. Third Party Storage Transportation (TPS)

Section 8. Storage Service Transportation (SST)

Section 9. Firm Storage Service (FSS)

Section 10. Firm Storage with Market-Based Rates (FSS-M)

Section 11. Interruptible Storage Service (ISS)

Section 12. Interruptible Storage Service with Market-Based Rates (ISS-M)

Section 13. Storage In Transit Service (SIT)

Section 14. Firm Balancing Service (FBS)

Section 15. Parking and Lending Service (PAL)





Section 16. Aggregation Service (AS)

Section 17. Interruptible Paper Pools (IPP)

Section 18. Merchant Sales Service (MS)

Section 19. LNG Storage Service (LSS)

Section 20. Firm Transportation Service – Commonwealth (FT-C)





Part VII. General Terms and Conditions

Part VIII. Form of Service Agreement for Service Under:

Section 1. Rate Schedules FTS, NTS, NTS-S, SST, OPT, ITS, GTS, and TPS

Section 2. Rate Schedule FSS

Section 3. Rate Schedule FSS-M

Section 4. Rate Schedule ISS

Section 5. Rate Schedule ISS-M

Section 6. Rate Schedule SIT

Section 7. Rate Schedule FBS

Section 8. Rate Schedule PAL

Section 9. Rate Schedule Auto PAL

Section 10. Rate Schedule AS

Section 11. Rate Schedule IPP

Section 12. Reference to Customers Having Non-Conforming Service

Agreements Pursuant to Section 154.112(B) of the Commission's

Regulations

Section 13. Rate Schedule FT-C

Part IX. Multi-Party Form of Service Agreement for Service Under:

Section 1. Rate Schedules FTS, NTS, NTS-S, TPS and OPT









Volume No. 2

Special Rate Schedules

X-2 Transportation Agreement with Kentucky West Virginia Gas Company

X-20 Agreement for the sale of natural gas from Well No. A-584 to Consolidated Gas Supply

Corporation



X-39 Exchange Agreement with Washington Gas Light Company

X-54 Transportation Agreement with City of Somerset, Kentucky


X-97 Transportation Agreement with Orange and Rockland Utilities, Inc.

X-99 Transportation and Exchange Agreement with Equitable Gas Company

X-103 Exchange Agreement with Transcontinental Gas Pipe Line Corporation

X-123 Transportation and Exchange Agreement with Tennessee Gas Pipeline Company


X-131 Liquefied Natural Gas Storage Service Agreement with the City of Richmond, Virginia

X-132 Liquefied Natural Gas Storage Service Agreement with Commonwealth Gas Services,

Inc.

X-133 Liquefied Natural Gas Storage Service Agreement with Virginia Natural Gas, Inc.

Columbia Gas Transmission, LLC V.21.

FERC Tariff Currently Effective Rates

Fourth Revised Volume No. 1 FTS-LXP Rates

Version 0.0.0


Currently Effective Rates

Applicable to Rate Schedule FTS-LXP

Incremental Leach XPress Service

Rate Per Dth

Base Tariff

Rate

1/ 2/

TCRA

Rates

EPCA

Rates

OTRA

Rates

CCRM

Rates

Total

Effective Rate

2/

Daily

Rate

2/

Rate Schedule FTS-LXP

Reservation Charge 3/ $ 13.569 0.205 0.065 0.112 0.000 13.951 0.4587

Commodity

Maximum ¢ 1.04 0.03 1.04 0.00 0.00 2.11 2.11

Minimum ¢ 1.04 0.03 1.04 0.00 0.00 2.11 2.11

Overrun

Maximum ¢ 45.65 0.70 1.25 0.37 0.00 47.98 47.98

Minimum ¢ 1.04 0.03 1.04 0.00 0.00 2.11 2.11

1/ Excludes Account 858 expenses and Electric Power Costs which are recovered through Columbia's Transportation Costs Rate

Adjustment (TCRA) and Electric Power Costs Adjustment (EPCA), respectively.

2/ Excludes the Annual Charge Adjustment (ACA) Surcharge. An ACA Commodity surcharge per Dth shall be assessed where

applicable pursuant to Section 154.402 of the Commission’s Regulations and in accordance with Section 34 of the GTC of

Transporter’s FERC Gas Tariff. The ACA unit charge authorized for each fiscal year (commencing October 1) by the

Commission and posted on its website (http://www.ferc.gov) is incorporated herein by reference.

3/ Minimum reservation charge is $0.00.

Appendix C

Columbia Gas Transmission, LLC

Docket No. CP15-514-000

Leach XPress Project

Revised Exhibit K

Cost of Facilities

Revised Exhibit N

Revenue, Expenses, and Income

Revised Exhibit P

Tariff

LINE NO. DESCRIPTION Pipeline 1/ Compression 2/ Compresssion

Adjustment 4/Revised

Compression 4/

Regulating Stations & Odorization

Subtotal Subtotal 3/ Total Project 4/

$ $ $ $ $ $

1 MATERIALS 149,256,811 131,083,228 (969,342) 130,113,886 17,536,909 296,907,605 28,317,348 325,224,9532 LABOR 452,229,376 74,317,641 (986,710) 73,330,931 13,107,501 538,667,808 53,950,389 592,618,1983 RIGHTS-OF-WAY 14,519,256 666,400 0 666,400 132,600 15,318,256 1,593,944 16,912,2004 SURVEYS 7,594,340 471,667 0 471,667 723,040 8,789,047 826,353 9,615,4005 DAMAGES 12,934,327 2,975,128 (1,388) 2,973,740 357,500 16,265,567 1,898,700 18,164,2676 ENGINEERING & INSPECTION 37,854,279 18,708,531 (148,626) 18,559,905 4,163,819 60,578,003 6,007,451 66,585,4547 LEGAL FEES 1,289,672 1,759,967 (2,237) 1,757,730 746,122 3,793,524 326,926 4,120,4498 OUTSIDE SERVICES 8,097,057 3,090,465 (56,292) 3,034,173 888,148 12,019,378 908,718 12,928,0979 OTHER COSTS 7,695,261 2,087,126 (18,505) 2,068,621 236,980 10,000,862 741,936 10,742,79810 INTERNAL LABOR 11,540,836 9,316,038 (69,357) 9,246,681 3,411,420 24,198,937 2,149,641 26,348,57811 CONTINGENCY 147,561,876 51,388,020 (450,504) 50,937,516 7,895,905 206,395,297 20,346,685 226,741,98212 ESCALATION 82,258,327 27,467,459 (119,880) 27,347,579 4,745,229 114,351,135 11,547,963 125,899,09813 AGSEO 11,237,060 4,590,450 (104,616) 4,485,834 664,050 16,386,944 1,486,224 17,873,16814 SUBTOTAL COSTS 944,068,477 327,922,119 (2,927,457) 324,994,662 54,609,223 1,323,672,362 130,102,279 1,453,774,642

15 AFUDC 39,240,950 14,621,458 (150,983) 14,470,475 2,281,997 55,993,422 5,195,244 61,339,649

16 TOTAL ESTIMATED PROJECT COST 342,543,577 (3,078,440) 339,465,137 56,891,220 1,379,665,784 135,297,524 1,515,114,291

1/ Includes only Majorsville to Crawford, K-260, BM-111, R-801, and R501 Abandonment.2/ Includes only Crawford, Lone Oak (reduced for at-risk investment), Summerfield, Oak Hill, and 2/3 of Ceredo (reduced for at-risk investment).3/ Includes 1/3 Cost of Ceredo Electric Compression (reduced for at-risk investment).4/ Revised per the Order Issuing Certificate in Docket No. CP15-514-000, 158 FERC ¶ 61,046, (2017) ("Certificate Order") at P 37.

983,309,427

REVISED EXHIBIT K

LEACH XPRESS PROJECT

COST ALLOCATION

COLUMBIA GAS TRANSMISSION, LLC

EXPANSION COSTS ROLLED IN COSTS

REVISED EXHIBIT NPAGE 1 OF 2

LINE FULL YEAR OF OPERATIONNO. DESCRIPTION Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10 Total

(1) (2) (3) (4) (5) (6) (7) (8) (9) (10) (11)$ $ $ $ $ $ $ $ $ $ $

1 ESTIMATED ANNUAL NON-GAS2 REVENUES - ALL FACILITIES3 RATE SCHEDULE FTS4 DEMAND5 (1,530,000 * 12 * $13.569) 1/ 4/ 249,129,803 249,129,803 249,129,803 249,129,803 249,129,803 249,129,803 249,129,803 249,129,803 249,129,803 249,129,803 2,491,298,0346 COMMODITY7 (1,530,000 * 365 * $0.0104 * 0.85) 2/ 4/ 4,936,698 4,936,698 4,936,698 4,936,698 4,936,698 4,936,698 4,936,698 4,936,698 4,936,698 4,936,698 49,366,9808 TOTAL RATE SCHEDULE FTS 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 2,540,665,014

9 TOTAL PROJECT REVENUE 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 254,066,501 2,540,665,014

10 ESTIMATED COST:11 ANNUAL COST OF SERVICE FOR12 NEW FACILITIES 3/ 251,570,741 242,816,318 234,718,695 227,209,302 220,233,309 213,742,757 207,483,657 201,229,493 194,973,523 188,729,606 2,182,707,401

1/ Reflects the incremental recourse rate associated with the facilities. See Exhibit P, Page 1.2/ Reflects Columbia's current Rate Schedule FTS commodity rate. See Columbia's effective tariff. Commodity billing determinants reflect a 85% load factor.3/ See Exhibit N, Page 2, herein.4/ Revised per the Certificate Order at PP 36-38.


ANNUAL REVENUE AND COST FOR THE PROPOSED INCREMENTAL FACILITIES

REVISED EXHIBIT NPAGE 2 OF 2

LINENO. DESCRIPTION Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 Year 8 Year 9 Year 10

(1) (2) (3) (4) (5) (6) (7) (8) (9) (10)$ $ $ $ $ $ $ $ $ $

1 TRANSPORTATION PLANT2 NET ORIGINAL PLANT INVESTMENT OF FACILITIES3 REQUIRED TO PROVIDE NEW SERVICE LEVELS 1/ 4/ 1,379,665,784 1,379,665,784 1,379,665,784 1,379,665,784 1,379,665,784 1,379,665,784 1,379,665,784 1,379,665,784 1,379,665,784 1,379,665,784

4 COST OF SERVICE: 5/5 OPERATION AND MAINTENANCE EXPENSE 6,981,400 7,155,935 7,334,833 7,518,204 7,706,159 7,898,813 8,096,284 8,298,691 8,506,158 8,718,8126 DEPRECIATION EXPENSE @ 1.50% 2/ 20,694,987 20,694,987 20,694,987 20,694,987 20,694,987 20,694,987 20,694,987 20,694,987 20,694,987 20,694,9877 TAXES - OTHER THAN INCOME 49,903,654 49,155,099 48,406,545 47,657,990 46,909,435 46,160,880 45,412,325 44,663,771 43,915,216 43,166,6618 PRE-TAX RETURN 2/ 173,990,700 165,810,297 158,282,330 151,338,121 144,922,728 138,988,077 133,280,061 127,572,045 121,857,162 116,149,146

9 TOTAL COST OF SERVICE 3/ 251,570,741 242,816,318 234,718,695 227,209,302 220,233,309 213,742,757 207,483,657 201,229,493 194,973,523 188,729,606

1/ For Cost of Facilities, See Exhibit K, herein.2/ Reflects the last approved depreciation rates of 1.5% in Docket No. RP12-1021 and pre-tax multiplier of 12.98% in Docket No. RP95-408. See Exhibit P, Page 3 and Exhibit P, Page 6, respectively.3/ The difference in Total Cost of Service between this Exhibit N and Exhibit P, Page 1 herein, relates to the timeframe in which Total Cost of Service is calculated. More specifically, the Return and Related Income Taxes in Year 1 is different because Exhibit P, Page 1 assumesa day 1 calculation in deriving FTS-LXP rates, whereas this Exhibit N assumes a full year's valuation in calculating a pre-tax return and therefore, Accumulated Depreciation and ADIT are both taken into account.4/ Cost of facilities revised per the Certificate Order at P 37.5/ Revised per the Certificate Order at PP 36-38.

FULL YEAR OF OPERATION


COST OF SERVICE FOR THE PROPOSED INCREMENTAL FACILITIES

REVISED EXHIBIT PPAGE 1 OF 6

LINENO. DESCRIPTION TOTAL DEMAND COMMODITY

(1) (2) (3)$ $ $

1 COST OF SERVICE2 OPERATION AND MAINTENANCE EXPENSE 1/ 6/ 6,981,400 3,997,180 2,984,220

3 DEPRECIATION EXPENSE 2/ 7/ 20,694,987 20,694,987 -

4 TAXES - OTHER THAN INCOME TAXES 3/ 7/ 50,446,937 50,446,937 -

5 RETURN AND ASSOCIATED INCOME TAXES 4/ 7/ 173,990,700 173,990,700 -

6 TOTAL COST OF SERVICE 252,114,023 249,129,803 2,984,220

7 BILLING DETERMINANTS8 RATE SCHEDULE FTS -- INCREMENTAL9 DETERMINANTS 5/ 8/ Dth 18,360,000 474,682,500

10 INCREMENTAL RECOURSE TARIFF RATES11 RATE SCHEDULE FTS -- INCREMENTAL $ 13.569 0.006

12 UNIT RATE $ 0.452

1/ See Exhibit P, Page 2 for further detail.2/ See Exhibit P, Page 3 for further detail.3/ See Exhibit P, Page 4 for further detail.4/ See Exhibit P, Page 5 for further detail.5/ Commodity Determinants assume a 85% load factor.6/ Revised per the Certificate Order at P 36.7/ Revised per the Certificate Order at P 37.8/ Revised per the Certificate Order at P 38.


RATE SCHEDULE FTS-LXP DESIGN FOR INCREMENTAL FACILITIES


LINE TRANSPORTATIONNO. DESCRIPTION TOTAL DEMAND COMMODITY

(1) (2) (3)$ $ $

1 OPERATION AND MAINTENANCE EXPENSE2 FIELD SERVICES: TRANSMISSION 1/ 6,981,400 3,997,180 2,984,220

3 ADMINISTRATIVE AND GENERAL EXPENSES - - -

4 TOTAL ESTIMATED O & M EXPENSES 6,981,400 3,997,180 2,984,220

1/ Revised per the Certificate Order at P 36.


OPERATION AND MAINTENANCE EXPENSES SUMMARY FOR INCREMENTAL FACILITIES



(1) (2) (3)$ $ $

1 DEPRECIATION EXPENSE2 GAS PLANT IN SERVICE 2/3 COMPRESSION GAS PLANT IN SERVICE - 4 PIPELINE GAS PLANT IN SERVICE 1,323,672,3625 AFUDC 55,993,422

6 TOTAL GAS PLANT IN SERVICE 1,379,665,784

7 DEPRECIATION RATE 1.50% 1/

8 ANNUAL DEPRECIATION EXPENSE 20,694,987 20,694,987 -

1/ The depreciation rate of 1.5% was established in RP12-1021 which was filed on September 04, 2012 and approved by the FERC Commission on January 24, 2013.2/ Revised per the Certificate Order at P 37.


DEPRECIATION EXPENSE SUMMARY FOR INCREMENTAL FACILITIES



(1) (2) (3)$ $ $

1 TAXES - OTHER THAN INCOME2 PROPERTY TAXES3 PLANT BY STATE

4 OHIO5 PLANT IN SERVICE 1,069,900,000 6 ACCUMULATED RESERVES (16,048,500) 7 NET BOOK VALUE 1,053,851,500 8 OHIO TAX PERCENTAGE 4.36%9 TOTAL OHIO TAX 45,947,925

10 WEST VIRGINIA 1/11 PLANT IN SERVICE 346,024,560 12 ACCUMULATED RESERVES (5,190,368) 13 NET BOOK VALUE 340,834,192 14 WEST VIRGINIA TAX PERCENTAGE 1.32%15 TOTAL WEST VIRGINIA TAX 4,499,011

16 TAXES - OTHER THAN INCOME 50,446,937 50,446,937 -


TAXES - OTHER THAN INCOME SUMMARY FOR INCREMENTAL FACILITIES




(1) (2) (3)$ $ $

1 RATE BASE CALCULATION 2/2 GAS PLANT IN SERVICE 1,379,665,784 3 LESS: ACCUMULATED RESERVES (20,694,987) 4 LESS: ACCUMULATED DEFERRED TAXES (18,518,564)

5 NET RATE BASE 1,340,452,234

6 RETURN AND ASSOCIATED INCOME TAXES 173,990,700 1/ 173,990,700 -

7 TOTAL RETURN AND ASSOCIATED TAXES 173,990,700 173,990,700 -


RATE OF RETURN AND ASSOCIATED INCOME TAXES SUMMARY FOR INCREMENTAL FACILITIES


1/ Net Rate Base multiplied by Columbia's last approved Pre-tax Multiplier of 12.98% in Docket No. RP95-408, et al. (See Exhibit P, Page 7).


LINE SETTLEMENTNO. DESCRIPTION AMOUNT

(1)

1 COLUMBIA'S LAST APPROVED PRE-TAX MULTIPLIER 1/ 12.98%


RATE OF RETURN SUMMARY FOR INCREMENTAL FACILITIES

1/ The pre-tax rate of return of 12.98% was established in Phase l of the Settlement for RP95-408 which was filed with FERC on November 22, 1996; was certificated as uncontested on January 15, 1997 and approved by FERC on April 17, 1997.

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