energy - KY PSC Home cases/2012-00287... · 6/29/2012 · June 28, 2012 Mr. Jeff Derouen,...

energy

June 28, 2012

Mr. Jeff Derouen, Executive Director Kentucky Public Service Commission 21 1 Sower Boulevard P.O. Box 615 Frankfort, KY 40602

IV JUN 2 9 2012

PUBLIC SERVICE COMMlSSlON

Re: Case No. 2012-00000

Dear Mr. Derouen:

We are filing the enclosed original and ten ('lo) copies of a notice under the provisions of our Gas Cost Adjustment Clause, Case No. 09-00354. This filing contains a Petition of Confidentiality and confidential documents.

Please indicate receipt of this filing by stamping and dating this letter and returning a scanned copy by E-ma i I to ant ho n y. croissa nt @at mosenerg y . co m .

If you have any questions, feel free to call me at 972-855-31 15.

Sincerely,

Anthony Croissant Rates Administration Analyst

Enclosures

In the Matter of:

GAS COST ADJUSTMENT )

ATMOS ENERGY CORPORATION ) FILING OF )

Case No. 2012-00000

NOTICE

QUARTERLY FILING

For The Period

August 1,2012 - October 31 2012

Attorney for Applicant

Mark R. Hutchinson 61 1 Frederica Street Owensboro, Kentucky 42301

June 28,2012

Atmos Energy Corporation, ("the Company"), is duly qualified under the laws of the Commonwealth of Kentucky to do its business. The Company is an operating public utility engaged in the business of purchasing, transporting and distributing natural gas to residential, commercial and industrial users in western and central Kentucky. The Company's principal operating office and place of business is 3275 Highland Pointe Drive, Owensboro, Kentucky 42303. Correspondence and communications with respect to this notice should be directed to:

Mark A. Martin Vice President of Rates & Regulatory Affairs Ke n t u c k y l M i d -S tat e s Division Atmos Energy Corporation 3275 Highland Pointe Drive Owensboro, Kentucky 42303

Mark R. Hutchinson Attorney for Applicant 61 1 Frederica Street Owensboro, Kentucky 42301

Victor Edwards Manager, Rate Administration Atmos Energy Corporation 5430 LBJ Freeway, Suite 700 Dallas, Texas 75240

Anthony Croissant Rate Administration Analyst Atmos Energy Corporation 5430 LBJ Freeway, Suite 700 Dallas, Texas 75240

2

The Company gives notice to the Kentucky Public Service Commission, hereinafter "the

Commission", pursuant to the Gas Cost Adjustment Clause contained in the Company's

settlement gas rate schedules in Case No. 09-00354.

The Company hereby files Fiftieth Revised Sheet No. 4, Fiftieth Revised Sheet No. 5 and

Fiftieth Revised Sheet No. 6 to its PSC No. I , Rates, Rules and Regulations for- Furnishinq

Natural Gas to become effective August 1, 2012.

The Gas Cost Adjustment (GCA) for firm sales service is $4.1 126 per Mcf and $3.0969 per Mcf

for interruptible sales service. The supporting calculations for the Fiftieth Revised Sheet No. 5

are provided in the following Exhibits:

Exhibit A - Comparison of Current and Previous Gas Cost Adjustment (GCA) Cases

Exhibit B - Expected Gas Cost (EGC) Calculation

Exhibit C - Rates used in the Expected Gas Cost (EGC)

Exhibit D -- Correction Factor (CF) Calculation

Exhibit E - Refund Factor (RF) Calculation

Exhibit E - Refund Factor (Refund Certificate of Compliance)

Since the Company's last GCA filing, Case No. 201 2-00121, the following changes have occurred in

its pipeline and gas supply commodity rates for the GCA period.

1. The commodity rates per Mcf used are based on historical estimates and/or current

data for the quarter of August 1, 2012 through October 31, 2012, as shown in Exhibit

C, page 1 of 2.

2. The G-I Expected Commodity Gas Cost will be approximately $4.4077 per Mcf for

the quarter of August 1, 2012 through October 31,2012, as compared to $3.9924 per

Mcf used for the quarter of May 1, 2012 through July 31, 2012. The G-2 Expected

Commodity Gas Cost will be approximately $3.3920 for the quarter of August 1, 2012

3

3.

4.

through October 31 , 2012, as compared to $2.9767 for the quarter of May 1 , 2012

through July 31 , 2012.

The Company’s notice sets out a new Correction Factor of ($0.3791) per Mcf which

will remain in effect until at least October 31 , 2012.

The Company’s notice also sets out a new Refund Factor of ($0.0462) per Mcf which

will remain in effect until at least October 31, 2012.

The GCA tariff as approved in Case No. 92-558 provides for a Correction Factor (CF) which

compensates for the difference between the expected gas cost and the actual gas cost for

prior periods. A revision to the GCA tariff effective December I , 2001 , Filing No. T62-1253,

provides that the Correction Factor be filed on a quarterly basis. In Case No. 2009-0354,

effective June I , 2010, the Company’s GCA tariff allows recovery of any gas cost which is

uncollectible, to be included in each February GCA filing.

The Company is filing its updated Correction Factor that is based upon the balance in the

Company’s I910 Account as of April 30, 2012 (May, 2012 general ledger). The calculation

for the Correction Factor is shown on Exhibit D, Page 1 of 6. Also beginning with the

February, 201 1 GCA filing in compliance with tariff page 24 from the Rate Case filing (Case

No. 2009-0354) the Company is allowed to recover the net uncollectible gas cost (net

uncollectible gas cost less subsequently collected gas cost).

4

WHEREFORE, Atmos Energy Corporation requests this Commission, pursuant to the

Commission's order in Case No. 99-070, to approve the Gas Cost Adjustment (GCA) as

filed in Fiftieth Revised Sheet No. 5; and Fiftieth Revised Sheet No. 6 setting out the

General Transportation Tariff Rate T-3 and T-4 for each respective sales rate for meter

readings made on and after August 1,2012.

DATED at Dallas, Texas this 28th Day of June, 2012.

ATMOS ENERGY CORPORATION

By:

Anthony Croissant Rate Administration Analyst Atmos Energy Corporation

5

For Entire Service Area P.S.C. No. 1

Fiftieth SHEET No. 4 Cancelling

Forty-Ninth SHEET No. 4


F Firm Service

---- -. _I .-

Current Rate Summary Case No. 2012-00000 -

Base Charge. Residential (G-I) Non-Residential (G-I ) Transportation (T-4)

Transportation Administration Fee

- $12.50 per meter per month - 30.00 per meter per month - 300.00 per delivery point per month - 50 00 per customer per meter

Rate per Mcf * Sales (G-I 1 Transportation (T-4) First 300 Mcf @ 5.2126 per Mcf @ 1.1000 per Mcf Next 14,700 ' Mcf @ 4.8826 per Mcf @ 0.7700 per Mcf Over 15,000 Mcf @ 4.6126 per Mcf @ 0.5000 per Mcf

Interruptible Service

Base Charge Transportation Administration Fee

- $300.00 per delivery point per month - 50.00 per customer per meter

Rate per Mcf Sales (G-2) Transportation (T-3) First 15,000 Mcf @ 3.7269 per Mcf @ 0.6300 per Mcf Over 15,000 Mcf @ 3 5069 per Mcf @ 0.4100 per Mcf

' All gas consumed by the customer (sales, transportation; firm and interruptible) will be considered for the purpose of determining whether the volume requirement of 15,000 Mcf has been achieved DSM, PRP and R&D Riders may also apply, where applicable. 2

ISSUED: June 28, 2012 Effective: August 1, 2012

(Issued by Authority of an Order of the Public Service Commission in Case No 2012-00000 )

ISSUED BY: Mark A. Martin - Vice President of Rates & Regulatory Affairs, KentilckylMidstates Division

For Entire Service Area P.S.C. No. 1




Current Gas Cost Adjustments Case No. 2012-00000

Applicable

For all Mcf billed under General Sales Service (G-I) and Interruptible Sales Service (G-2).

Gas Charge = GCA

GCA = EGC+ CF + RF + PBRRF

Gas Cost Adiustment Components G - 1

EGC (Expected Gas Cost Component) 4.4077

G-2

3.3920

CF (Correction Factor) (0.3791) (0.3791 )

RF (Refund Adjustment) (0.0462) (0.0462)

PBRRF (Performance Based Rate Recovery Factor) 0.1 302 0.1 302

ISSUED: June 28, 201 2 Effective: August 1, 2012

(Issued by Authority of an Order af the Public Service Commission in Case No. 2012-00000.)

ISSUED BY: Mark A. Martin - Vice President of Rates & Regulatory Affairs, KentuckylMidstates Division

For Entire Service Area P.S.C. No. I




Current Trans portat i on Case No. 2012-00000

'The Transportation Rates (T-3 and T-4) for each respective service net monthly rate is as follows:

System Lost and Unaccounted gas percentage: 1 "91 Oh

Simple Non- Gross

Transportation Service ' Firm Service (T-41 First 300 M cf Next 14,700 M cf All over 15.000 M cf

Interruptible Service (T-31 First 15,000 M cf All over 15,000 M cf

Excludes standby sales service 1

Margin Commodity Margin

@ $1.1000 + $0.0000 = $1.1000 per Mcf 0.7700 + 0.0000 = 0.7700 per Mcf @

@ 0.5000 +" 0.0000 = 0.5000 per Mcf

@ $0.6300 + $0.0000 = $0.6300 perMcf @ 0.4100 f 0.0000 = 0.4100 per Mcf

ISSUED: June 28,201 2 Effective: August 1, 2012

(Issued by Authority of an Order of the Public Service Commission in Case No. 2012-00000.)

ISSUED BY: Mark A. Martin - Vice President of Rates & Regulatory Affairs, KentiickylMidstates Division

Atmos Energy Corporation Comparison of Current and Previous Cases Sales Service

Exhibit A Page 1 of 2

(a) (b) (c) Line Case No. No. Description 201 2-001 21 201 2-00000 Difference -

$/Mcf $/Mcf $/Mcf 1 2 3 4 5 6 7 8 9

11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 47 48 49 50 51 52 53 54 55

10

- G - I

Distribution Charqe (Der Case No. 09-00354) First 300 Mcf Next 14,700 Mcf Over 15,000 Mcf

Gas Cost Adiustment ComDonents EGC (Expected Gas Cost):

Commodity Demand

Total EGC CF (Correction Factor) RF (Refund Adjustment) PBRRF (Performance Based Rate Recovery Factor)

GCA (Gas Cost Adjustment)

Rate Der Mcf (GCA included) First 300 Mcf Next 14,700 Mcf Over 15,000 Mcf

Distribution Charqe (Der Case No. 09-00354) First 15,000 Mcf Over 15,000 Mcf

Gas Cost Adiustment Components EGC (Expected Gas Cost):

Commodity Demand

Total EGC CF (Correction Factor) RF (Refund Adjustment) PBRRF (Performance Based Rate Recovery Factor)

GCA (Gas Cast Adjustment)

Rate per Mcf (GCA included) First 300 Mcf Over 14.700 Mcf

Refund Factor (RF)

Case No.

1 - 201 1-00400 2 - 201 1-00520 3 - 201 2-001 21 4 - 201 2-00000

Total Refund Factor (RF)

1.1000 1.1000 0.0000 0.7700 0.7700 0.0000 0.5000 0.5000 0.0000

2.7546 3.1699 0.41 53 1.2378 1.2378 0.0000 3.9924 4.4077 0.41 53 0.031 5 (0.3791) (0.4106)

(0.0283) (0.0462) (0.0179) 0.1302 0.1302 0.0000 4.125F 4.1 126 (0.01 32)

-

5.2258 5.2126 (0.0 132)

4.6258 4.6126 (0.0 1 32) 4.8958 4.8826 (0.01 32)

0.6300 0.6300 0.0000 0.4100 0.41 00 0.0000

2.7546 3.1699 0.41 53 0.2221 0.2221 0.0000 2.9767 3.3920 0.41 53 0.031 5 (0.3791 ) (0.4 1 06)

0.1302 0.0000 0.1302 3.1101 3.0969 (0.0132)

(0.0283) (0.0462) (0.01 79) ---

3.7269 (0.01 32) 3.7401 3.5201 3.5069 (0.01 32)

Effective Date RF

11/1/2011 (0.0070) 211 120 1 2 (0.0069) 5/1/2012 (0.0072) 811 120 1 2 (0.0251)

($0.0462)

Atmos Energy Corporation Comparison of Current and Previous Cases Transportation Service

Exhibit A Page 2 of 2

(a) (b) ( c ) Line Case No. No. Description 2012-00121 2012-00000 Difference

$/Mcf $lMcf $lMcf 1 2 3 4 5 6 7 8 9

10 11 12 13 14

T -4 Transportation Service I Firm Service (High Priority)

Simple Margin I Distribution Charge (per Case No. 09-00354) First 300 Mcf Next 14,700 Mcf Over 15,000 Mcf

1 .IO00 1,1000 0.0000 0.7700 0.7700 0.0000 0.5000 0.5000 0.0000

T - 3 / Interruptible Service (Low Priority)

Simple Margin I Distribution Charge (per Case No. 09-00354) First 15,000 Mcf 0.6300 0.6300 0.0000 Over 15,000 Mcf 0.41 00 0.41 00 0.0000

Atmos Energy Corporation Expected Gas Cost (EGC) Calculation Texas Gas Transmission - Non-Commodity

Exhibit B Page 1 of 8

(a) (b) (c) (4 (e) Non-Commodity

Line Tariff Annual No. Description Sheet No. Units Rate Total Demand --

MMbtu $/MMbtu $ $ 1 SL to Zone 2 2 NNS Contract # 3 BaseRate 4 5 Total SL to Zone 2 6 7 SL to Zone 3 8 NNS Contract # 9 Base Rate

10 11 FT Contract # 12 Base Rate 13 14 Total SL to Zone 3 15 16 Zone I to Zone 3 17 FT Contract # 18 Base Rate 10

29760

29762

29759

29761

20 Total Zone 1 to Zone 3 21 22 SL to Zone 4 23 NNS Contract # 29763 24 Base Rate 25 26 FT Contract # 29765 27 Base Rate 28 11 FT Contract # 31 097 12 Base Rate 19 29 Total SL to Zone 4 30 31 Total SL to Zone 2 32 Total SL to Zone 3 33 Total Zone 1 to Zone 3 34 35 Total Texas Gas 36 37

12,617,673 Section 4.4 - NNS

12,617,673 -

27,480,375 Section 4.4 - NNS

4,927,500 Section 4.1 - FT

32,407,875

1,093,740 Section 4.1 - FT

1,093,740

3,320,769 Section 4.4 - NNS

1,277,500 Section 4.1 - FT

547,500 Section 4.1 - FT

- 5,145,769

12,617,673 32,407,875

1,093,740

51,265,057

0.3088 3,896,337 3,896,337

3,896,337 3,896,337 ~-

---

0.3543 9,736,297 9,736,297

0.2494 1,228,919 1,228,919 --

10,965,216 10,965,216

0.21 94 239,967 239,967

239,967 239,967

0.41 90 1,391,402 1,391,402

0.3142 401,391 401,391

0.3142 172,025 172,025 - -

1,964,818 I ,964,818

3,896,337 3,896,337 10,965,216 10,965,216

239,967 239,967

17,066,338 17,066,338

17.066.338 17.066.338 38 Total Texas Gas Area Non-Commodity

Atmos Energy Corporation Expected Gas Cost (EGC) Calculation Tennessee Gas Pipeline - Non-Commodity


(a) (b) (c) (d l (e) Non-Commodity

Line Tariff Annual No. Description Sheet No. Units Rate Total Demand

MMbtu $/MMbtu $ $

I 0 to Zone 2 2 FT-G Contract # 2546.1 3 Base Rate 23 4 5 FT-G Contract # 2548.1 6 BaseRate 23 7 8 FT-G Contract # 2550.1 9 Base Rate 23

10 11 FT-G Contract# 2551.1 12 Base Rate 23 13 14 Total Zone 0 to 2 15 16 1 to Zone 2 17 FT-G Contract # 2546 18 Base Rate 23 19 20 FT-G Contract # 2548 21 BaseRate 23 22 23 FT-G Contract # 2550 24 Base Rate 23 25 26 FT-G Contract # 2551 27 Base Rate 23 28 29 Total Zone 1 to 2 and Zone 0 to 2 30 31 Gas Storage 32 Production Area: 33 Demand 61 34 Space Charge 61 35 Market Area: 36 Demand 61 37 Space Charge 61 38 Total Storage 39 40 Total Tennessee Gas Area FT-G Non-Commodity

12,844

4,363

5,739

4,446

27,392

114,156

44,997

59,741

45,059

- 291,345

34,968 4,916,148

237,408 10,846,308 16,034,832

16.3405 209,877 209,877

16.3405 71,294 71,294

16.3405 93,778 93.778

16.3405 72,650 72,650

447,599 447,599

1 1.1329 1,270,887 1,270,887

11.1329 500,947 500,947

1 I .I 329 665,091 665,091

11 .I329 501,637 501,637

3,386,161 3,386,161

2.8100 98,260 98,260 0.0286 140,602 140,602

1.5400 365,608 365,608 0.021 1 228,857 228,857

833,327 833.327

4,219,488 4,219,488

Atmos Energy Corporation Expected Gas Cost (EGC) Calculation Texas Gas Transmission - Commodity Purchases


(a) (b) (c) ( 4 (e) (f) Line Tariff No. Description Sheet No. Purchases Rate Total -

$ .-___

M cf MMbtu $/MM btu

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

No Notice Service Indexed Gas Cost Commodity (Zone 3) Fuel and Loss Retention @

Firm TransDortation Indexed Gas Cost Base (Weighted on MDQs) ACA Fuel and Loss Retention @

No Notice Storaae Net (Injections)/Withdrawals

Withdrawals Injections

Commodity (Zone 3) Fuel and Loss Retention @

Section 4.4 - NNS Section 4.18.1 3.50%

Section 4.1 - FT Section 4.18.1 3.50%

2,613,166 2.9080 7,599,087 0.0508 132,749 0.1055 275,689 3.0643 8,007,525

2,138,045 2.9080 6,217,435 0.0441 94,288 0.0018 3,848 0.1055 225,564 3.0594 6,54 1,135

-

3.7790 0 (1,152,345) 2.9080 ( 3 , 3 ~ ~ 1 9 )

Section 4.4 - NNS 0.0508 (58,539) 0.1055 121,573

(1,152,345) 3.0643 (2531730) Section 4.18. I 3.50% ~-

Total Purchases in Texas Area 3,598,866 3.0614 11,017,530

Used to allocate transportation non-commodity

Annualized MDQs in

Commodity Charge Weighted

.- Texas Gas SL to Zone 2 SL to Zone 3 1 to Zone 3 SL to Zone 4 Total

Tennessee Gas 0 to Zone 2 1 toZone2 Total

- MMbtu Allocation $/MMbtu Average 12,617,673 24.61% $0.0399 $ 0.0098 Section 4.1 - FT

Section 4.1 - FT 32,407,875 63.22% 0.0445 $ 0.0281 Section 4.1 - FT 1,093,740 2.13% 0.0422 $ 0.0009 Section 4.1 - FT 5,145,769 10.04% 0.0528 $ 0.0053

100.00% $ 0.0441 51,265,057

24 24

27,392 9.40% $0.0177 $ 0.0017 263,953 90.60% 0.0147 0.0133 291,345 100.00% $ 0.0150

Atmos Energy Corporation Expected Gas Cost (EGC) Calculation Tennessee Gas Pipeline - Commodity Purchases


Line Tariff No. Description Sheet No. Purchases Rate Total -

Mcf MMbtu $/MMbtu $

1 FT-A and FT-G 2 Indexed Gas Cost 3 Base Commodity (Weighted on MDQs) 4 ACA 5 Fuel and Loss Retention 6 7 8 FT-GS 9 Indexed Gas Cost

10 Base Rate 11 ACA 12 Fuel and Loss Retention 13 14 15 Gas StoraQe 16 FT-A & FT-G Market Area Withdrawals 17 FT-A & FT-G Market Area Injections 18 Withdrawal Rate 19 Injection Rate 20 Fuel and Loss Retention 21 Total 22 23 24 25 Total Tennessee Gas Zones

24 32 1.65%

26 24 32 1.65O/o

61 61

700,269 2.9080 2,036,382 0.01 50 10,491 0.0018 1,260

343 73 0.0488 2.9736 2,082,30F

-

34,711 100,940 2.9080

0.91 31 31,695 0,001 8 62

- 0.0488 1,694 134,391 3.871 7

3.7790 (498,039) 2.9080 (1,448,297)

0.0087 0 0.0087 (4,333)

61 1.59% 0.0001 (50) (498,039) 2.9168 (1,452,680)

236,941 3.2245 764,017

W :\Rate Adrninistration\5-,Jurisdictional Files\Kentucky\GCA Filing\Current Fiiing\Exhibit B (Expected Gas Cost EGC Calculation).xls

Atmos Energy Corporation Expected Gas Cost (EGC) Calculation Trunkline Gas Company


Line Tariff No. Description Sheet No. Purchases Rate Total

Mcf MMbtu $/MMbtu $

1 Firm Transportation 2 Expected Volumes 3 Indexed Gas Cost 4 Base Commodity 10 6 ACA 10 7 Fuel and Loss Retention 10 0.99% 8 9

10

Non-Commodity

Line Tariff No. Description Sheet No.

Injections 1 I FT-G Contract # 014573 12 Discount Rate on MDQs 13 14 Total Trunkline Area Non-Commodity

92,000 2.9080 267,536 0.0051 469 0.0018 166 0.0291 2,677 2.9440 270,848

Annual Units Rate Total Demand MMbtu $/MMbtu $ $

27,000 5.3776 145,195 145,195

145,195 145,195

W:\Rate Administration\5-Jurisdictional Files\Kentucky\GCA Filing\Current Filing\Exhibit B (Expected Gas Cost EGC Calculation).xls

Atmos Energy Corporation Expected Gas Cost (EGC) Calculation Demand Charge Calculation

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

T'otal Demand Cost: Texas Gas Transmission Midwestern Tennessee Gas Pipeline Trunkline Gas Company 'Total

Demand Cost Allocation: All Firm Total

Firm Service Sales:

G-I

Interruptible Service Sales: G-2

Transportation Service 'T-3 & T-4


$17,066,338 0

421 9,488 145,195

$21,431,021

Allocated Related Monthly Demand Charge Interruptible Factors Demand Volumes Firm

0.1 81 8 $3,896,160 17,543,818 0.2221 0.2221 0.81 82 17,534,861 17,263,240 1.01 57 I .0000 $21,431,021 1.2378 0.2221

Volumetric Basis for Annualized Monthly Demand Charge Mcf a14.65 All Firm

17,263,240 17,263,240 17,263,240 1.2378

1.2378 280,578 280,578

21 , I 85,357

38,729,175 17,543,818 17,263,240

0.2221

W:\Rate Administration\5-Jurisdictional Files\Kentucky\GCA Filing\Current Filing\Exhibit 8 (Expected Gas Cost EGC Calculation).xls

Atmos Energy Corporation Expected Gas Cost (EGC) Calculation Commodity - Total System


Line No. Description Purchases Rate Total

M cf MMbtu $/Mcf $

1 2 3 4 5 6 7 8 9

10 11 12

Texas Gas Area No Notice Service Firm Transportation No Notice Storage Total Texas Gas Area

Tennessee Gas Area FT-A and FT-G

Gas Storage lniections

FT-GS

Withdrawals 13 14 Trunkline Gas Area 15 Firm Transportation 16 17 ComRanv Owned Storane 18 Injections 19 Withdrawals 20 Net WKG Storage 21 22 23 Local Production 24 25

2,592,427 2,613,166 3.0888 8,007,525 2,121,076 2,138,045 3.0839 6,541 ,I 35

(1,143,199) (1,152,345) 3.0888 (3,531,130) 3,570,304 3,598,866 3.0859 11,017,530

685,061 700,269 3.0396 2,082,306 134,391 33,957 34'71 1 3.9577

(487,223) (498,039) 2.9816 (1,452,680) 0 0 0.0000 0 --

764,017 236,941 3.2961 - 231,795

91,725 92,000 2.9528 270,848

(1,931,363) (1,946,814) 2,9080 (5,918,275) 0 0 3.7790

(1,931,363) (1,946,814) 3.0643 (5,918,275)

159,904 162,143 2.9080 465,001

26

28 29 Lost & Unaccounted for @ 1.91 % 40,537 40,934

27 Total Commodity Purchases 2,122,365 2,143,136 3.1093 6,599,120

30 31 Total Deliveries 32 33

-- 2,081,828 2,102,202 3.1699 6,599,120

34 35 Total Expected Commodity Cost 2,081,828 2,102,202 3.1 6 9 9 6,599,120

36 37 38 Note: Column (c) is calculated by dividing column (d) by column (a) 39

W:\Rate Administration\5-,lurisdictional Files\Kentucky\GCA Filing\Current Filing\Exhibit B (Expected Gas Cost EGC Calculation).xls

Atmos Energy Corporation Expected Gas Cost (EGC) Calculation Load Factor Calculation for Demand Allocation


Line No. Description MCF

1 2 3 4 5 6 7 8 9 10 11 12

Annualized Volumes Subiect to Demand Charses Sales Volume Transportation Total Mcf Billed Demand Charges Divided by: DaysNear Average Daily Sales and Transport Volumes

17,543,818 0

17,543,818 365

48,065 -

Peak Day Sales and TransDortation Volume Estimated total company firm requirements for 5 degree average temperature days from Peak Day Book - with adjustments per rate filing 264,419 McflPeak Day

0.1818 New Load Factor (line 5 I line 9)

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Atmos Energy Corporation Correction Factor (CF) For the Three Months Ended April 2012 Case No 2012-00000

Exhibit D Page 1 of 6

Line No.

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

(a)

Month

February-I2

March-I 2

April-I2

Total Gas Cost

(b) (c) (dl Actual GCA

Actual Purchased Recoverable Recovered Volume (Mcf) Gas Cost Gas Cost

2,448,979 $1 0,706,216 63 $1 3,710,695.47

976,319 $5,357,431 “69 $9,834,340.40

737,991 $4,046,204.75 $3,602,078 05

(e) (f) (g ) Under (Over)

Recovery Amount Adjustments Total

($3,004,478.84) $0.00 ($3,004,478.84)

($4,476,908.7 1 ) $0.00 ($4,476,908.71 )

$444,126.70 $0 00 $444.1 26.70

Underl(0ver) Recovery

PBR Savings reflected in Gas Costs $599,474.00

Correction Factor - Part 1 (Over)/Under Recovered Gas Cost through January 2012 (February 2012 GL)

Recovery from outstanding Correction Factor (CF) (0ver)kJnder Recovered Gas Cost through April 2012 (May 2012 GL) (a) Divided By: Total Expected Customer Sales (b) 17,543,818 Mcf

Correction Factor - Part 1 ($0.4037) I Mcf

$121,708.88

(166,287.26) ($7,081,839.23)

Total Gas Cost Unded(0ver) Recovery for the three months ended April 2012 (7,037,260.85)

Correction Factor - Part 2 Net Uncollectible Gas Cost through November 2011 (c) Divided By: Total Expected Customer Sales (b)

430,808.29 17,543,818

Correction Factor - Part 2 - $0.0246 lMc f

Correction Factor - ‘Total (CF) Total Deferred Balance through January 2012 (February 2012 GL) including Net Uncol Gas $ (6,651,030.94) Divided By: Total Expected Customer Sales (b) 17,543,818

Correction Factor - Total (CF) ($0.3791) / Mcf

Atmos Energy Corporation Exhibit D Recoverable Gas Cost Calculation For the Three Months Ended April 2012 Case No. 2012-00000

Page 2 of 6

GL March-I 2 April-I 2 May-I 2

(a ) (b) (c) Line Month No. Description Unit February-I 2 March-I 2 April-I 2

1 Supply Volume 2 Pipelines: 3 Texas Gas Transmission ' Mcf 0 0 0 4 Tennessee Gas Pipeline Mcf

5 Trunkline Gas Company ' Mcf 0 0

0 0

0 0

6 Midwestern Pipeline ' Mcf 0 0 0 '7 Total Pipeline Supply Mcf 0 0 0 8 Total Other Suppliers Mcf 389,920 407 896,815 9 10 11 12 13 14 15 16 17

Off System Storage Texas Gas Transmission Mcf 0 0 0 Tennessee Gas Pipeline Mcf 0 0 0

System Storage Withdrawals Mcf 1,368,827 441,279 12,558 Injections Mcf (1,436) ( I ,951) (68,442)

Producers Mcf 20,702 26,548 35,402

Pipeline Imbalances cashed out Mcf Third Party Reimbursements Mcf (405) 0 (1 49)

18 System Imbalances Mcf 671,371 51 0,036 (138,193) 19 Total Supply Mcf 2,448,979 976,319 737,991 20 21 Change in Unbilled 22 Company Use 23 Unaccounted For 24 Total Purchases

Mcf Mcf 0 0 0 Mcf 0 0 0 Mcf 2,448,979 976,319 737,991

Includes settlement of historical imbalances and prepaid items. Includes Texas Gas No-Notice Service volumes and monthly imbalances related to transportation customer activities.

1

Atrnos Energy Corporation Exhibit D Recoverable Gas Cost Calculation For the Three Months Ended April 2012 Case No. 2012-00000

Page 3 of 6

GL March-I 2 April-I 2 May-I 2

Line No. Description Unit 1 Supply cost 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

Pipelines: Texas Gas Transmission ' Tennessee Gas Pipeline ' Trunkline Gas Company ANR Pipeline Company Midwestern Pipeline

Total Pipeline Supply Total Other Suppliers Hedging Settlements Off System Storage

1

Texas Gas Transmission Tennessee Gas Pipeline WKG Storage

System Storage Withdrawals Injections

Producers Third Party Reimbursements Pipeline Imbalances cashed out System Imbalances Sub-Total Pipeline Refund + Interest Change in Unbilled Company Use Recovered thru Transportation Total Recoverable Gas Cost

(a 1 (b) (c) Month

February-I 2 March-I 2 April-I 2

1,569,093 1,654,216 1,457,645

21,401 22,003 35,603 63,875 64,208

91 3

473,596 454,450 373,733

2,127,965.23 2,195,791 1,866,981 916,351.16 (72,296) 1,856,457

608,184 427,641 0

122,500 122,500 122,500

5,668,163 1,828,984 59,091 (3,889) (4,783) (149,941) 49,761 55,455 64,902 (2,497) (221 ) (1,093)

1,219,678 804,361 227,309 10,706,217 5,357,431.69 4,046,204.75

0 0 0 0 0 0

10,706,216.63 5,357,431.69 4,046,204.75

Includes demand charges, cost of settlement of historical imbalances and prepaid items. Includes Texas Gas No-Notice Service volumes and monthly imbalances related to transportation customer activities.

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Atmos Energy Corporation Detail Sheet for Supply Volumes & Costs Traditional and Other Pipelines

Exhibit D Page 5 of 6

Description - March, 2012 April, 2012 February, 2012

MCF cost MCF Cost MCF Cost

1 Texas Gas Pipeline Area 2 LG8E Natural 3 Texaco Gas Marketing 4 CMS 5 WESCQ 6 Southern Energy Company 7 Union Pacific Fuels 8 Atmos Energy Marketing, LLC 9 Engage 10 ERI 11 Prepaid 12 Reservation 13 14 15 Total 325,147 $81 8.51 7.60 0 $6,779 18 700,610 $1,419,723 59

16 17 18 Tennessee Gas Pipeline Area 19 Atmas Energy Marketing, LLC 20 Union Pacific Fuels 21 WESCO 22 Prepaid 23 Reservation 24 Fuel Adjustment 25 26 Total 27 28 29 Trunkline Gas Company 30 Atmos Energy Marketing, LLC 31 Engage 32 Prepaid 33 Reservation 34 Fuel Adjustment 35 36 Total 37 38 39 Midwestern Pipeline 40 Atmos Energy Marketing, LLC 41 LG&E Natural 42 Anadarko 43 Prepaid 44 Reservation 45 Fuel Adjustment 46 47 Total 48 49 50 ANR Pipeline 51 Atmos Energy Marketing, LLC 52 LG&E Natural 53 Anadarko 54 Prepaid 55 Reservation 56 Fuel Adjustment 57 58 Total 59 60 61 AllZones 62 Total 63 64 65

Hedging Costs - All Zones

63,538 $93,509 83 0 ($78,749 08) 166,298 $371,585 04

~- 1,720 $5.581.66 0 $7 00 30,044 $65.41 8.91

(485) ($1,257 93) 407 $0 00 (137) ($270 32)

0 $0 00 0 ($332.79) 0 $0.00

389,920 $916,351 16 407 ($72,295 69) 896,815

**** Detail of Volumes and Prices Has Been Filed Under Petition for Confidentiality ****

$1,856,457 22

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Atmos Energy Corporation Refund Factor Case No. 2012-00000 (RF)

Line No. Amounts Reported:

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

Tennessee Gas Pipeline PCB/HSL Refund, Docket Nos. RP91-203 & RP92-132 Tennessee Gas Pipeline Rate Case Refund, Docket No. RPI 1-1566 Carryover from Case No. 201 1-001 14 Less: amount related to specific end users Amount to flow-through

Average of the 3-Month Commercial Paper Rates for the immediately preceding 12-month period less 1/2 of 1% to cover the costs of refunding.

Exhibit E Page 1 of 2

AMOUNT

$ 121,920.98 318,516.39

23,423.02 0.00

$ 463,860.39

I 0.00%l

(1) (2) (3) Demand Commodity Total Allocation --

Balance to be Refunded

Total (wlo interest) Interest (Line 14 x Line 5) Total

Refund Calculation

Demand Allocator - All (See Exh. B, p. 8, line 12) Demand Allocator - Firm (1 - Demand Allocator - All) Firm Volumes (normalized) (See Exh. B, p. 6, col. 3, line 28) All Volumes (excluding Transportation) (See Exh. B, p. 6, col. 2, line 28)

0.1818

0.81 82

17,263,240

17,543,818

Demand Factor - All Demand Factor - Firm Commodity Factor Total Demand Firm Factor (Col. 2, lines 29 - 30) Total Demand Interruptible Factor (Col. 2, line 29) Total Firm Sales Factor (Col. 2, line 31 + col. 1, line 33)

$0 $ 463,860 $463,860 0 0 0

0 463,860 463,860 0 0 0

$0 $463,860 $463,860

$0 $0.0000 /MCF $0 $0.0000 /MCF

$463,860 $ 0.0264 /MCF

I $0.0000 I MCF I

COMMONWEALTH OF KENTUCKY BEFORE THE

KENTUCKY PUBLIC SERVICE COMMISSION

I n the Matter of:

REFUND PL.AN OF ) ATMOS E,NERGY CORPORATION )

Exhibit E Page 2 of" 2

Case No. 20 1 1-00 1 I 4

CERTIFICATE OF COMPLJANCE

We hcrcby certi% that thc refund directed to be made by Order in Case No. 20 I 1-00 1 14 has been completed in thc following inanncr:

Refund Detail

Customers Refund As Filed Interest Accrued Cany-over to next GCA Refund

Total

Rcfund by Class of Customer

Sales: Residential Coininercial Industrial Public Authority

Total

9; (1 2 1,92 1 .00)

23,423.02 9; (98,497.98)

9; 59,107.80 27,538.08

5,198.86 6,653.24

9; 98,497.98

energy - KY PSC Home cases/2012-00287... · 6/29/2012 · June 28, 2012 Mr. Jeff Derouen,...

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