case no.: u-13549-r witness: v.e. borra exhibit no.: a- 1

MICHCON GAS COMPANY 2003 Daily Average Temperatures for Metro Detroit

Normal vs Actual

0

10

20

30

40

50

60

70

80

90

1-Jan

15-Ja

n29

-Jan

12-F

eb26

-Feb

12-M

ar26

-Mar

9-Apr

23-A

pr7-M

ay21

-May

4-Jun

18-Ju

n2-J

ul16

-Jul

30-Ju

l13

-Aug

27-A

ug10

-Sep

24-S

ep8-O

ct22

-Oct

5-Nov

19-N

ov3-D

ec17

-Dec

31-D

ecD

egre

e, F

ahre

nhei

t

Daily Average Temperature for Detroit Metro Daily Actual Average Temperature

CASE NO.: U-13549-R WITNESS: V.E. BORRAEXHIBIT NO.: A- 1 (VEB - 1) PAGE NO.: 1 OF 1

Sources: 1971-2000 U.S. NOAA Daily Normals for Detroit Metropolitan Area

LINENBR.

1 DISPOSITION2 GCR MARKETS3 COMPANY USE & LOSSES4 TOTAL GCR SENDOUT5 GCC SENDOUT6 TOTAL SENDOUT78 FLOWING SUPPLY9 Total Purchases, @14.65 Delivered

10 Exchange/Gas in Kind11 New Haven (Withdrawals)12 TOTAL GCR SUPPLY13 TOTAL GCC SUPPLY14 TOTAL SUPPLY1516 MICHCON ONLY STORAGE ACTIVITY17 INITIAL STORAGE BALANCE18 STORAGE IN / (OUT)

20 GCC ONLY STORAGE21 INITIAL STORAGE BALANCE22 STORAGE IN / (OUT)2324 TOTAL GCR & GCC STORAGE25 INITIAL STORAGE BALANCE26 STORAGE IN / (OUT)2728 GAS IN TRANSMISSION MAINS29 GCR ENDING STORAGE BALANCE30 GCC ENDING STORAGE3132 TOTAL ENDING BALANCE3334 MONTHLY WEATHER (HDD'S)35 % Colder / (Warmer) Than Normal

CASE NO.: U-13549-RWITNESS: V.E. BORRAEXHIBIT NO.: A-2 (VEB - 2 )PAGE NO.: 1 of 1

MICHIGAN CONSOLIDATED GAS COMPANYPLANNED VERSUS ACTUALSOURCE AND DISPOSITION

2003

JANUARY - DECEMBER(A) (B) (C)

Projected Actual Variance

151,421 177,063 25,6426,122 6,959 837

157,543 184,022 26,47944,392 23,590 (20,802)

201,935 207,612 5,677

157,420 193,333 35,9133,551 3,287 (264)424 155 (269)

161,395 196,775 35,38045,256 24,770 (20,486)

206,651 221,545 14,894

53,100 47,286 (5,814)3,852 12,753 8,901

7,370 6,334 (1,036)864 1,180 316

60,470 53,620 (6,850)4,716 13,933 9,217

0 (22) (22)56,952 60,017 3,0878,234 7,514 (720)

65,186 67,531 2,367

6851 6802 (49)(0.7%)

All Volumes in MMcf @ 14.65 psig

Michigan Consolidated Gas CompanyGCR and GCC End of Month Storage Balance

2003 Plan vs Actual

-10.0

-5.0

0.0

5.0

10.0

15.0

20.0

25.0

30.0

35.0

40.0

45.0

50.0

55.0

60.0

65.0

70.0

75.0

80.0

DEC. 02

JAN

FEB

MAR

APR

MAY

JUN

JUL

AUG

SEP

OCT

NOV

DEC

Volu

mes

in B

cf

Plan GCR Balance Actual GCR BalancePlan GCC Balance Actual GCC Balance

CASE NO.: U-13549-R WITNESS: V.E. BORRAEXHIBIT NO.: A-3 (VEB -3) PAGE NO.: 1 OF 1

Sources: Exhibit A-___(VEB 4) pages 1-5, lines 29 and 30.


JANUARY - MARCH APRIL - OCTOBER NOVEMBER - DECEMBERLINE (A) (B) (C) (D) (E) (F) (G) (H) (I)NBR. Projected Actual Variance Projected Actual Variance Projected Actual Variance

1 DISPOSITION2 GCR MARKETS 74,469 80,029 5,560 40,500 55,055 14,555 36,452 41,979 5,5273 COMPANY USE & LOSSES 2,118 3,205 1,087 2,848 2,259 (589) 1,156 1,495 339

4 TOTAL GCR SENDOUT 76,587 83,234 6,647 43,348 57,314 13,966 37,608 43,474 5,866

5 GCC SENDOUT 18,656 17,502 (1,154) 12,456 1,180 (11,276) 13,280 4,908 (8,372)

6 TOTAL SENDOUT 95,243 100,736 5,493 55,804 58,494 2,690 50,888 48,382 (2,506)

78 FLOWING SUPPLY9 Total Purchases, @14.65 Delivered 40,277 44,731 4,454 95,347 122,060 26,713 21,796 26,542 4,74610 Exchange/Gas in Kind 1,022 (1,188) (2,210) 1,967 3,799 1,832 562 676 11411 New Haven (Withdrawals) 124 105 (19) 241 50 (191) 59 0 (59)

12 TOTAL GCR SUPPLY 41,423 43,648 2,225 97,555 125,909 28,354 22,417 27,218 4,801

13 TOTAL GCC SUPPLY 10,350 7,593 (2,757) 26,248 13,536 (12,712) 8,658 3,641 (5,017)

14 TOTAL SYSTEM SUPPLY 51,773 51,241 (532) 123,803 139,445 15,642 31,075 30,859 (216)1516 MICHCON ONLY STORAGE ACTIVITY17 INITIAL STORAGE BALANCE 53,100 47,286 (5,814) 17,936 7,700 (10,236) 72,143 76,295 4,15218 STORAGE IN / (OUT) (35,164) (39,586) (4,422) 54,207 68,595 14,388 (15,191) (16,278) (1,087)1920 GCC ONLY STORAGE21 INITIAL STORAGE BALANCE 7,370 6,334 (1,036) (936) (3,575) (2,639) 12,856 8,781 (4,075)22 STORAGE IN / (OUT) (8,306) (9,909) (1,603) 13,792 12,356 (1,436) (4,622) (1,267) 3,3552324 TOTAL GCR & GCC STORAGE25 INITIAL STORAGE BALANCE 60,470 53,620 (6,850) 17,000 4,125 (12,875) 84,999 85,076 7726 STORAGE IN / (OUT) (43,470) (49,495) (6,025) 67,999 80,951 12,952 (19,813) (17,545) 2,2682728 GAS IN TRANSMISSION MAINS 0 0 0 0 0 0 0 (22) (22)2930 GCR ENDING STORAGE BALANCE 17,936 7,700 (10,236) 72,143 76,295 4,152 56,952 60,017 3,06531 GCC ENDING STORAGE BALANCE (936) (3,575) (2,639) 12,856 8,781 (4,075) 8,234 7,514 (720)32 TOTAL ENDING STORAGE BALANCE 17,000 4,125 (12,875) 84,999 85,076 77 65,186 67,531 2,3453334 MONTHLY WEATHER (DDD'S) 3383 3552 169 1546 1543 (3) 1922 1707 (215)

35 % Colder / (Warmer) Than Normal 5.0% (0.2%) (11.2%)


2003

All Volumes in MMcf @14.65 psig.

CASE NO.: U-13549-RWITNESS: V.E. BORRAEXHIBIT NO.: A-4 (VEB - 4)PAGE NO.: 2 of 5


2003

LINE JANUARY FEBRUARY MARCHNBR. (A) (B) (C) (D) (E) (F) (G) (H) (I)

Projected Actual Variance Projected Actual Variance Projected Actual Variance1 DISPOSITION2 GCR MARKETS 28,067 32,299 4,232 25,009 27,381 2,372 21,393 20,349 (1,044)3 COMPANY USE & LOSSES 799 1,054 255 731 1,844 1,113 588 307 (281)4 TOTAL GCR SENDOUT 28,866 33,353 4,487 25,740 29,225 3,485 21,981 20,656 (1,325)5 GCC SENDOUT 6,988 6,004 (984) 6,234 5,618 (616) 5,434 5,880 4466 TOTAL SENDOUT 35,854 39,357 3,503 31,974 34,843 2,869 27,415 26,536 (879)78 FLOWING SUPPLY9 Total Purchases, @14.65 Delivered 13,887 15,038 1,151 12,571 15,258 2,687 13,819 14,435 616

10 Exchange/Gas in Kind 327 (1,451) (1,778) 382 (164) (546) 313 427 11411 New Haven (Withdrawals) 43 36 (7) 41 40 (1) 40 29 (11)12 TOTAL GCR SUPPLY 14,257 13,623 (634) 12,994 15,134 2,140 14,172 14,891 71913 TOTAL GCC SUPPLY 3,516 2,896 (620) 3,359 2,056 (1,303) 3,475 2,641 (834)14 TOTAL SUPPLY 17,773 16,519 (1,254) 16,353 17,190 837 17,647 17,532 (115)15 13,587 15,094 14,86216 MICHCON ONLY STORAGE ACTIVITY17 INITIAL STORAGE BALANCE 53,100 47,286 (5,814) 38,491 27,556 (10,935) 25,745 13,465 (12,280)18 STORAGE IN / (OUT) (14,609) (19,730) (5,121) (12,746) (14,091) (1,345) (7,809) (5,765) 2,044

14,652 19,766 5,114 12,787 14,131 1,344 7,849 5,794 (2,055)20 GCC ONLY STORAGE21 INITIAL STORAGE BALANCE 7,370 6,334 (1,036) 3,898 3,226 (672) 1,023 (336) (1,359)22 STORAGE IN / (OUT) (3,472) (3,108) 364 (2,875) (3,562) (687) (1,959) (3,239) (1,280)2324 TOTAL GCR & GCC STORAGE25 INITIAL STORAGE BALANCE 60,470 53,620 (6,850) 42,389 30,782 (11,607) 26,768 13,129 (13,639)26 STORAGE IN / (OUT) (18,081) (22,838) (4,757) (15,621) (17,653) (2,032) (9,768) (9,004) 7642728 GAS IN TRANSMISSION MAINS 0 0 0 0 0 0 0 0 029 GCR ENDING STORAGE BALANCE 38,491 27,556 (10,935) 25,745 13,465 (12,280) 17,936 7,700 (10,236)30 GCC ENDING STORAGE 3,898 3,226 (672) 1,023 (336) (1,359) (936) (3,575) (2,639)3132 TOTAL ENDING BALANCE 42,389 30,782 (11,607) 26,768 13,129 (13,639) 17,000 4,125 (12,875)3334 MONTHLY WEATHER (HDD'S) 1303 1391 88 1128 1209 81 952 952 035 % Colder / (Warmer) Than Normal 6.8% 7.2% 0.0%


LINENBR.




CASE NO.: U-13549-RWITNESS: V.E. BORRAEXHIBIT NO.: A-4 (VEB -4 )PAGE NO.: 3 of 5


2003

APRIL MAY JUNE(A) (B) (C) (D) (E) (F) (G) (H) (I)

Projected Actual Variance Projected Actual Variance Projected Actual Variance

12,022 15,394 3,372 6,571 13,035 6,464 3,392 3,170 (222)369 (440) (809) 404 (553) (957) 420 1,285 865

12,391 14,954 2,563 6,975 12,482 5,507 3,812 4,455 6433,461 1,519 (1,942) 1,733 (3,563) (5,296) 989 605 (384)

15,852 16,473 621 8,708 8,919 211 4,801 5,060 259

14,288 17,656 3,368 14,200 17,151 2,951 13,519 15,632 2,113288 174 (114) 288 1,315 1,027 328 (71) (399)38 29 (9) 37 21 (16) 36 0 (36)

14,614 17,859 3,245 14,525 18,487 3,962 13,883 15,561 1,6782,885 2,261 (624) 3,410 1,503 (1,907) 3,581 2,054 (1,527)

17,499 20,120 2,621 17,935 19,990 2,055 17,464 17,615 15117,830 18,466 15,561

17,936 7,700 (10,236) 20,159 10,605 (9,554) 27,709 16,610 (11,099)2,223 2,905 682 7,550 6,005 (1,545) 10,071 11,106 1,035

(2,185) (2,876) (691) (7,513) (5,984) 1,529 (10,035) (11,106) (1,071)

(936) (3,575) (2,639) (1,512) (2,833) (1,321) 165 2,233 2,068(576) 742 1,318 1,677 5,066 3,389 2,592 1,449 (1,143)

17,000 4,125 (12,875) 18,647 7,772 (10,875) 27,874 18,843 (9,031)1,647 3,647 2,000 9,227 11,071 1,844 12,663 12,555 (108)

0 0 0 0 0 0 0 0 020,159 10,605 (9,554) 27,709 16,610 (11,099) 37,780 27,716 (10,064)(1,512) (2,833) (1,321) 165 2,233 2,068 2,757 3,682 925

18,647 7,772 (10,875) 27,874 18,843 (9,031) 40,537 31,398 (9,139)

556 553 (3) 259 293 34 67 63 (4)(0.5%) 13.1% (6.0%)


LINENBR.






2003

JULY AUGUST SEPTEMBER(A) (B) (C) (D) (E) (F) (G) (H) (I)


2,824 3,964 1,140 2,914 4,370 1,456 3,771 4,224 453450 (292) (742) 435 627 192 390 560 170

3,274 3,672 398 3,349 4,997 1,648 4,161 4,784 623883 385 (498) 984 (44) (1,028) 1,307 651 (656)

4,157 4,057 (100) 4,333 4,953 620 5,468 5,435 (33)

13,705 17,196 3,491 13,542 18,167 4,625 12,834 17,171 4,337326 854 528 283 1,028 745 230 (395) (625)34 0 (34) 33 0 (33) 32 0 (32)

14,065 18,050 3,985 13,858 19,195 5,337 13,096 16,776 3,6803,963 2,091 (1,872) 4,036 1,628 (2,408) 4,084 1,965 (2,119)

18,028 20,141 2,113 17,894 20,823 2,929 17,180 18,741 1,56118,050 19,195 16,776

37,780 27,716 (10,064) 48,571 42,094 (6,477) 59,080 56,292 (2,788)10,791 14,378 3,587 10,509 14,198 3,689 8,935 11,992 3,057

(10,757) (14,378) (3,621) (10,476) (14,198) (3,722) (8,903) (11,992) (3,089)

2,757 3,682 925 5,837 5,388 (449) 8,889 7,060 (1,829)3,080 1,706 (1,374) 3,052 1,672 (1,380) 2,777 1,314 (1,463)

40,537 31,398 (9,139) 54,408 47,482 (6,926) 67,969 63,352 (4,617)13,871 16,084 2,213 13,561 15,870 2,309 11,712 13,306 1,594

0 0 0 0 0 0 0 0 048,571 42,094 (6,477) 59,080 56,292 (2,788) 68,015 68,284 2695,837 5,388 (449) 8,889 7,060 (1,829) 11,666 8,374 (3,292)

54,408 47,482 (6,926) 67,969 63,352 (4,617) 79,681 76,658 (3,023)

11 3 (8) 25 8 (17) 153 154 1(72.7%) (68.0%) 0.7%


LINENBR.




CASE NO.: U-13549-RWITNESS: V.E. BORRAEXHIBIT NO.: A-4 (VEB -4)PAGE NO.: 5 of 5


2003

OCTOBER NOVEMBER DECEMBER(A) (B) (C) (D) (E) (F) (G) (H) (I)


9,006 10,898 1,892 14,927 17,145 2,218 21,525 24,834 3,309380 1,072 692 501 (572) (1,073) 655 2,067 1,412

9,386 11,970 2,584 15,428 16,573 1,145 22,180 26,901 4,7213,099 1,627 (1,472) 5,318 1,567 (3,751) 7,962 3,341 (4,621)

12,485 13,597 1,112 20,746 18,140 (2,606) 30,142 30,242 100

13,259 19,087 5,828 10,346 11,898 1,552 11,450 14,644 3,194224 894 670 265 1,454 1,189 297 (778) (1,075)31 0 (31) 30 0 (30) 29 0 (29)

13,514 19,981 6,467 10,641 13,352 2,711 11,776 13,866 2,0904,289 2,034 (2,255) 4,295 1,699 (2,596) 4,363 1,942 (2,421)

17,803 22,015 4,212 14,936 15,051 115 16,139 15,808 (331)19,981 13,352 13,866

68,015 68,284 269 72,143 76,295 4,152 67,356 73,074 5,7184,128 8,011 3,883 (4,787) (3,221) 1,566 (10,404) (13,035) (2,631)

(4,097) (8,011) (3,914) 4,817 3,221 (1,596) 10,433 13,035 2,602

11,666 8,374 (3,292) 12,856 8,781 (4,075) 11,833 8,913 (2,920)1,190 407 (783) (1,023) 132 1,155 (3,599) (1,399) 2,200

79,681 76,658 (3,023) 84,999 85,076 77 79,189 81,987 2,7985,318 8,418 3,100 (5,810) (3,089) 2,721 (14,003) (14,434) (431)

0 0 0 0 0 0 0 (22) (22)72,143 76,295 4,152 67,356 73,074 5,718 56,952 60,017 3,08712,856 8,781 (4,075) 11,833 8,913 (2,920) 8,234 7,514 (720)

84,999 85,076 77 79,189 81,987 2,798 65,186 67,531 2,367

475 469 (6) 775 686 (89) 1147 1021 (126)(1.3%) (11.5%) (11.0%)


CASE NO.: U-13549-R WITNESS: V.E. BORRAEXHIBIT NO.: A-5 (VEB -5 )PAGE NO.: 1 of 1

Line Actual Peak Day Activity Plan Peak Day ActivityNbr. Column (a) Column (b)

1 DATE: 22-Jan-03 End of Month January

2 MEAN TEMPERATURE: 14° Fahrenheit -4° Fahrenheit

3 HEATING DEGREES: 51

4 TOTAL SENDOUT: 2.3 Bcf 2.8 Bcf

5 STORAGE Withdrawal: 1.5 Bcf 1.9 Bcf

6 Percent of sendout suppliedfrom storage 65% 68%

Field Withdrawals7 Taggart (198,882) (180,000)8 Belle River (925,012) (1,176,000)9 Columbus (77,635) (141,000)

10 West Columbus (311,086) (548,000)

11 Total Field Withdrawal (1,512,615) (2,045,000)

MICHIGAN CONSOLIDATED GAS COMPANY2003 PEAK DAY INFORMATION

CASE NO.: U-13549-RWITNESS: V.E. BORRAEXHIBIT NO.: A-6 (VEB - 6)PAGE NO.: 1 of 1

MICHCON GAS COMPANYGCR, GCC Total Storage Balance and 3rd Party Storage Balance1990-2001 Balances as of November 30

Volumes in Bcf

Column (A) Column (B) Column ('C) Column (D)

Line # YearMichCon & GCC Total 3rd Party Total

1 1991 75.8 38.6 114.42 1992 81.9 31.9 113.83 1993 81.0 31.4 112.44 1994 91.4 35.1 126.55 1995 82.3 33.7 116.06 1996 87.1 25.0 112.17 1997 77.9 33.0 110.98 1998 83.9 35.6 119.59 1999 98.3 20.4 118.7

10 2000 82.3 24.7 107.011 2001 65.3 57.6 122.9

Note: 3rd Party Customers include End User Transportation Exelon and Storage Service customers.

Michigan Consolidated Gas Company Case No.: U-13549-RSummer 2002 Spot Market Supply Witness: G.H. Chapel

Exhibit No.: A-___(GHC-1)Page No.: 1 of 1

Line July August September Total(Col. 1) (Col. 2) (Col. 3) (Col. 4) (Col. 5) (Col. 6)

1 Volume 1,375,601 2,436,864 2,290,044 6,102,5092 City-Gate Cost $4,766,629 $7,172,072 $7,518,830 $19,457,5313 Cost/Mcf $3.4651 $2.9432 $3.2833 $3.1884456 Volume 620,000 651,000 720,000 1,991,0007 Panhandle Less fuel (5.23 587,574 616,953 682,344 1,886,8718 Cost $1,825,900 $1,728,405 $2,105,250 $5,659,5559 Cost/Mcf $3.1075 $2.8015 $3.0853 $2.9994101112 Volume 1,963,175 3,053,817 2,972,388 7,989,38013 Total Cost $6,592,529 $8,900,477 $9,624,080 $25,117,08614 Cost/Mcf $3.3581 $2.9145 $3.2378 $3.1438

e48458

8

Michigan Consolidated Gas Company Case No.: U-13549-R2002 Enron Fixed Price Replacement Witness: G.H. Chapel

Exhibit No.: A-___(GHC-2)Page No.: 1 of 1

Line(Col. 1) (Col. 2) (Col. 3) (Col. 4) (Col. 5)

1 Enron Cancelled Jan-Mar CG 4,500,000 $5.8950 $26,527,5002 Replaced Apr-Oct Spot CG 4,500,000 $3.1438 14,147,14234 Cost Reduction $12,380,35856 Enron Booked Cost ($8,000,000)78 Net Cost Reduction $4,380,358

e48458

9

NYMEXLine Year Month Strip Basis Rate

(A) (B) (C) (D) (E)

1 2002 January $2.70 $0.14 $2.842 February $2.79 $0.14 $2.933 March $2.80 $0.14 $2.944 April $2.76 $0.06 $2.825 May $2.80 $0.06 $2.866 June $2.85 $0.06 $2.917 July $2.88 $0.06 $2.948 August $2.92 $0.06 $2.989 September $2.92 $0.06 $2.98

10 October $2.95 $0.06 $3.01

11 J-M Avg. $2.76 $0.14 $2.9012 A-O Avg. $2.87 $0.06 $2.93

/1 MichCon basis assumed to be the arithmetic average of themarket basis for Chicago and Dawn, Ont. for 11/30/01 asreported by Morgan Stanley's daily newsletter.

MichCon (City-Gate) /1

Michigan Consolidated Gas Company2003 GCR Reconciliation

NYMEX Strip and Basis Prices ($/Dth)as of November 30, 2001

e61968

Case No.: U-13549-R Witness: G. H. Chapel Exhibit No.: A- 10 (GHC-3) Page No.: 1 of 1

Case No. U-13549-R Witness: W. B. Kramer Exhibit No. A-11 (WBK-1) Page No. 1 of 2

Michigan Consolidated Gas Company

Summary of ANR’s Quarterly Dakota Cost Recovery Filings Pursuant to Order No. 636

Docket No. RP03-119 Date Filed November 27, 2002 Effective Date December 1, 2002 Period Costs Incurred August 1, 2002 through October 31, 2002 Recovery Period December 2002 through February 2003 Costs Allocated to Firm $2,093,515 (90% of total) Reservation Surcharge $0.151/Dth Calculation of Res. Surcharge $2,093,515 / 3 mo. / 4,629,017 Dth True Up Adjustment $(0.001)/Dth Net Dakota Surcharge $0.150/Dth

Docket No. RP03-288 Date Filed February 28, 2003 Effective Date March 1, 2003 Period Costs Incurred November 1, 2003 through January 31, 2003 Recovery Period March 2003 through May 2003 Costs Allocated to Firm $2,782,255 (90% of total) Reservation Surcharge $0.200 Calculation of Res. Surcharge $2,782,255 / 3 mo. / 4,629,017 Dth True Up Adjustment $0.012/Dth Net Dakota Surcharge $0.212/Dth Docket No. RP03-502 Date Filed May 30, 2003 Effective Date June 1, 2003 Period Costs Incurred February 1, 2003 through April 30, 2003 Recovery Period June 2003 through August 2003 Costs Allocated to Firm $2,005,268 (90% of total) Reservation Surcharge $0.161 Calculation of Res. Surcharge $2,005,268 / 3 mo. / 4,161,303 Dth True Up Adjustment $0.012/Dth Net Dakota Surcharge $0.173/Dth

Case No. U-13549-R Witness: W. B. Kramer Exhibit No. A-11 (WBK-1) Page No. 2 of 2


Summary of ANR’s Quarterly Dakota Cost Recovery Filings Pursuant to Order No. 636

Docket No. RP03-584 – Filing to Recover Buyout Costs Date Filed August 29, 2003 Effective Date September 1, 2003 Costs Incurred Buyout of Dakota Obligation Recovery Period September 2003 through August 2003 Costs Allocated to Firm $10,981,343 (90% of total) Reservation Surcharge $0.220 Calculation of Res. Surcharge $10,981,343 / 12 mo. / 4,161,303 Dth True Up Adjustment $0.012/Dth Net Dakota Surcharge $0.232/Dth

MICHIGAN CONSOLIDATED GAS COMPANY MPSC Case No.U-13549-R APPLICABLE RATES OF INTERSTATE Exhibit No. A-12 (WBK-2) PIPELINE TRANSPORTERS FOR 2003 Witness: W. B. Kramer

($/Dth) Page 1 of 2

LINE Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec(COL. 1) (COL. 2) (COL. 3) (COL. 4) (COL. 5) (COL. 6) (COL. 7) (COL. 8) (COL. 9) (COL. 10) (COL. 11) (COL. 12)

ANR Maximum Rate ETS Contracts - Expired 10/31/03

Southeast to ML-7, Contracts 4400 and 4500 (Includes Gathering Contract 51750).1 Total Reservation Rate 11.7580$ 11.7580$ 11.8200$ 11.8200$ 11.8200$ 11.7810$ 11.7810$ 11.7810$ 11.8400$ 11.8400$ 2 Total Usage Rate 0.0163$ 0.0163$ 0.0163$ 0.0163$ 0.0163$ 0.0163$ 0.0163$ 0.0159$ 0.0159$ 0.0159$

Southwest to ML-7, Contacts 107707, 4350, and 4450.3 Total Reservation Rate 10.0080$ 10.0080$ 10.0700$ 10.0700$ 10.0700$ 10.0310$ 10.0310$ 10.0310$ 10.0900$ 10.0900$ 4 Total Usage Rate 0.0181$ 0.0181$ 0.0181$ 0.0181$ 0.0181$ 0.0181$ 0.0181$ 0.0177$ 0.0177$ 0.0177$

Northern Segment, Contracts 4300 and 4550.5 Total Reservation Rate 5.0080$ 5.0080$ 5.0700$ 5.0700$ 5.0700$ 5.0310$ 5.0310$ 5.0310$ 5.0900$ 5.0900$ 6 Total Usage Rate 0.0096$ 0.0096$ 0.0096$ 0.0096$ 0.0096$ 0.0096$ 0.0096$ 0.0092$ 0.0092$ 0.0092$

Remaining ANR Contract

Discounted Southeast to ML-7 FTS-1 Contract 108405 (Includes Gathering Contract 108455).7 Total Reservation Rate 4.0360$ 4.0360$ 4.0360$ 9.9620$ 9.9620$ 9.9230$ 9.9230$ 9.9230$ 9.9820$ 9.9820$ 4.0360$ 4.0360$ 8 Total Usage Rate 0.0163$ 0.0163$ 0.0163$ 0.0163$ 0.0163$ 0.0163$ 0.0163$ 0.0159$ 0.0159$ 0.0159$ 0.0163$ 0.0163$

New ANR Contracts, Effective November 1, 2003

Discounted Southeast to ML-7 FTS-1 Contract 109608 (Includes Gathering Contract 109616).9 Total Reservation Rate 7.7806$ 7.7806$

10 Total Usage Rate 0.0163$ 0.0163$

Discounted Southwest to ML-7 ETS Contracts 108268 and 108304.11 Total Reservation Rate 5.9520$ 5.9520$ 12 Total Usage Rate 0.0181$ 0.0181$

Discounted Southwest to ML-7 FTS-1 Contract 109511.13 Total Reservation Rate 8.6383$ 8.6383$ 14 Total Usage Rate 0.0181$ 0.0181$

Maximum Rate Northern Segment ETS Contracts 108184 and 108185.15 5.0900$ 5.0900$ 16 0.0092$ 0.0092$

MICHIGAN CONSOLIDATED GAS COMPANY MPSC Case No.U-13549-R APPLICABLE RATES OF INTERSTATE Exhibit No. A-12 (WBK-2) PIPELINE TRANSPORTERS FOR 2003 Witness: W. B. Kramer

($/Dth) Page 2 of 2

LINE Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec(COL. 1) (COL. 2) (COL. 3) (COL. 4) (COL. 5) (COL. 6) (COL. 7) (COL. 8) (COL. 9) (COL. 10) (COL. 11) (COL. 12)

Viking Gas Transmission Contract

FT-A Maximum Rate Contract 7756.1 Total Reservation Rate 4.2761$ 4.2761$ 4.2761$ 4.2761$ 4.2761$ 4.2761$ 4.2761$ 4.2761$ 4.2761$ 4.2761$ 4.2761$ 4.2761$ 2 Total Usage Rate 0.0151$ 0.0151$ 0.0151$ 0.0151$ 0.0151$ 0.0151$ 0.0151$ 0.0151$ 0.0151$ 0.0151$ 0.0151$ 0.0151$

Great Lakes Gas Transmission Contract

Maximum Rate Contract FT015 Central Zone.3 Total Reservation Rate 5.8090$ 5.8090$ 5.8090$ 5.8090$ 5.8090$ 5.8090$ 5.8090$ 5.8090$ 5.8090$ 5.8090$ 5.8090$ 5.8090$ 4 Total Usage Rate 0.0123$ 0.0123$ 0.0123$ 0.0123$ 0.0123$ 0.0123$ 0.0123$ 0.0123$ 0.0123$ 0.0123$ 0.0123$ 0.0123$

Maximum Rate Contract FT015 Eastern Zone.5 Total Reservation Rate 10.3280$ 10.3280$ 10.3280$ 10.3280$ 10.3280$ 10.3280$ 10.3280$ 10.3280$ 10.3280$ 10.3280$ 10.3280$ 10.3280$ 6 Total Usage Rate 0.0169$ 0.0169$ 0.0169$ 0.0169$ 0.0169$ 0.0169$ 0.0169$ 0.0169$ 0.0169$ 0.0169$ 0.0169$ 0.0169$

Panhandle Eastern Pipe Line Contracts

Maximum Rate FT Contract 016329 Defiance to Chelsea (1 to 100 Miles).7 Total Reservation Rate 3.4400$ 3.4400$ 3.4400$ 3.4400$ 3.4300$ 3.4300$ 3.4300$ 3.4300$ 3.4300$ 3.4300$ 8 Total Usage Rate 0.0086$ 0.0086$ 0.0086$ 0.0086$ 0.0086$ 0.0086$ 0.0086$ 0.0086$ 0.0086$ 0.0086$

EFT Field Zone to Rouge Contract Released by CTC.9 Total Reservation Rate 6.6917$ 6.6917$ 6.6917$ 6.6917$ 6.6917$ 6.6917$ 6.6917$ 6.6917$ 6.6917$ 6.6917$ 6.6917$ 6.6917$

10 Total Usage Rate 0.0440$ 0.0440$ 0.0440$ 0.0440$ 0.0440$ 0.0440$ 0.0440$ 0.0440$ 0.0440$ 0.0440$ 0.0440$ 0.0440$

Discounted EFT Contract No. 17908 Field to MichCon Southern Station (801 to 900 Miles).11 Total Reservation Rate 7.7745$ 7.7745$ 12 Total Usage Rate 0.0444$ 0.0444$

Discounted EFT Contract No. 18251 Bourbon (Trunkline) to MichCon (350 Miles).13 Total Reservation Rate 2.6371$ 2.6371$ 14 Total Usage Rate 0.0124$ 0.0124$

Trunkline Gas Company Contract

Discounted FT Contract 17760 Field to Bourbon (Panhandle).15 Total Reservation Rate 4.0515$ 4.0515$ 16 Total Usage Rate 0.0151$ 0.0151$

Vector Pipeline Contract

Discounted FT Contract No. MCG-026.17 Total Reservation Rate 5.1708$ 5.1708$ 18 Total Usage Rate 0.0021$ 0.0021$

e48458

13


Line Execution Date Supplier LocationPrice

MethodContract

Price Total-03No. ($/Dth) (Dth)

(Col. 1) (Col. 2) (Col. 3) (Col. 4) (Col. 5) (Col. 6)1 10/22/2001 Morgan ANR SE Hurdle $3.525 3,650,000 2 10/25/2001 Duke MCCG Hurdle $3.835 3,650,000 3 10/26/2001 Duke MCCG Hurdle $3.755 3,650,000 4 10/29/2001 Reliant MCCG Hurdle $3.875 3,650,000 5 1/4/2002 Coral Emerson Hurdle $3.145 900,000 6 1/4/2002 Coral Emerson Hurdle $3.175 2,750,000 7 1/7/2002 BP Emerson Hurdle $3.195 3,650,000 8 1/11/2002 Conoco Emerson Hurdle $3.145 2,750,000 9 1/11/2002 Engage Emerson Hurdle $3.185 900,000 10 1/14/2002 Anadarko ANR SW Hurdle $2.880 3,650,000 11 3/12/2002 Reliant MCCG Hurdle $3.500 3,650,000 12 3/15/2002 AEP MCCG Hurdle $3.603 3,638,000 13 3/18/2002 Aquila MCCG Hurdle $3.585 3,650,000 14 3/19/2002 Engage Emerson Hurdle $3.800 900,000 15 3/19/2002 Conoco Emerson Hurdle $3.800 2,750,000 16 3/20/2002 CMSMST MCCG Hurdle $3.710 3,638,000 17 3/21/2002 Dynegy PEPL Hurdle $3.840 1,800,000 18 3/25/2002 Nexen Vector Hurdle $4.240 1,800,000 19 4/17/2002 Mirant Emerson Hurdle $3.705 2,140,000 20 4/18/2002 AEP MCCG Hurdle $4.210 630,000 21 4/18/2002 Aquila MCCG Hurdle $4.000 900,000 22 4/18/2002 Aquila PEPL Hurdle $3.700 2,750,000 23 4/18/2002 CMSMST MCCG Hurdle $4.245 900,000 24 4/19/2002 Morgan ANR SW Hurdle $3.650 3,650,000 25 4/23/2002 PanCan Vector Hurdle $3.920 3,650,000 26 4/24/2002 El Paso ANR SE Hurdle $3.708 3,650,000 27 4/25/2002 El Paso ANR SW Hurdle $3.605 3,650,000 28 5/3/2002 Conoco ANR SE Hurdle $3.885 3,650,000 29 5/7/2002 Reliant ANR SW Hurdle $3.860 3,650,000 30 5/8/2002 BP Emerson Hurdle $4.218 3,650,000 31 5/10/2002 Sempra MCCG Hurdle $4.285 3,648,000 32 5/14/2002 Cinergy MCCG Hurdle $4.345 3,648,000 33 6/17/2002 Sempra PEPL Hurdle $3.850 3,648,000 34 6/24/2002 Anadarko ANR SE Hurdle $4.008 3,650,000 35 8/22/2002 Duke MCCG Hurdle $4.108 3,650,000 36 8/4/2003 Anadarko ANR SW DCA $4.925 300,000 37 8/4/2003 Anadarko PEPL DCA $4.820 300,000 38 8/4/2003 Anadarko PEPL DCA $5.090 155,000 39 8/4/2003 Conoco ANR SE DCA $5.015 300,000 40 8/4/2003 Conoco ANR SE DCA $5.225 310,000 41 8/4/2003 Coral Emerson DCA $5.230 300,000 42 8/4/2003 Nexen PEPL DCA $4.980 300,000 43 8/4/2003 Nexen PEPL DCA $5.220 310,000 44 8/7/2003 Totalfina ANR SE DCA $5.280 300,000 45 8/14/2003 Oneok ANR SW DCA $4.940 300,000 46 8/29/2003 Totalfina TGC ELA DCA $4.975 300,000 47 9/2/2003 Totalfina TGC ELA DCA $5.125 310,000 48 Total $3.785 105,625,000

49 Subtotal Hurdle $3.741 102,140,000 50 Subtotal DCA $5.069 3,485,000 51 Total All $3.785 105,625,000

2003 Fixed Price Supply by Contract

Case No.: U-13549-RWitness: R. G. LawsheExhibit No.: A-14 (RGL-2)Page No.: 1 of 1

e48458

15

Michigan Consolidated Gas CompanyComparison of Fixed Price Gas Cost to Index

Case No.: U-13549-RWitness: R. G. Lawshe

Exhibit No.: A-16 (RGL-4)Page No.: 1 of1

Line No. Location Jan-03 Feb-03 Mar-03 Apr-03 May-03 Jun-03 Jul-03 Aug-03 Sep-03 Oct-03 Nov-03 Dec-03

Total / Vol Wt Avg

(Col. 1) (Col. 2) (Col. 3) (Col. 4) (Col. 5) (Col. 6) (Col. 7) (Col. 8) (Col. 9) (Col. 10) (Col. 11) (Col. 12) (Col. 13) (Col. 14)

Fixed Price Volume (MDth):1 ANR SE 1,240 1,120 1,240 1,200 1,240 1,200 1,240 1,240 1,200 1,240 1,800 1,550 15,510 2 ANR SW 1,240 1,120 1,240 1,200 1,240 1,200 1,240 1,240 1,200 1,240 1,800 1,240 15,200 3 Emerson 1,550 1,400 1,550 1,800 1,860 1,800 1,860 1,860 1,800 1,860 1,800 1,550 20,690 4 MCCG 3,441 3,108 3,441 3,540 3,658 3,540 3,658 3,658 3,540 3,658 1,800 1,860 38,902 5 PEPL 992 896 992 660 682 660 682 682 660 682 900 775 9,263 6 Vector 930 840 930 300 310 300 310 310 300 310 300 310 5,450 7 TGC ELA - - - - - - - - - - 300 310 610 8 Total 9,393 8,484 9,393 8,700 8,990 8,700 8,990 8,990 8,700 8,990 8,700 7,595 105,625

Fixed Price ($/Dth):9 ANR SE $3.78 $3.78 $3.78 $3.78 $3.78 $3.78 $3.78 $3.78 $3.78 $3.78 $4.24 $4.07 $3.86

10 ANR SW $3.50 $3.50 $3.50 $3.50 $3.50 $3.50 $3.50 $3.50 $3.50 $3.50 $3.98 $3.50 $3.5611 Emerson $3.51 $3.51 $3.51 $3.54 $3.54 $3.54 $3.54 $3.54 $3.54 $3.54 $3.79 $3.51 $3.5512 MCCG $3.98 $3.98 $3.98 $3.85 $3.85 $3.85 $3.85 $3.85 $3.85 $3.85 $3.78 $3.78 $3.8813 PEPL $3.84 $3.84 $3.84 $3.78 $3.78 $3.78 $3.78 $3.78 $3.78 $3.78 $4.50 $4.59 $3.9414 Vector $4.13 $4.13 $4.13 $3.92 $3.92 $3.92 $3.92 $3.92 $3.92 $3.92 $3.92 $3.92 $4.0315 TGC ELA - - - - - - - - - - $4.98 $5.13 $5.0516 Total $3.81 $3.81 $3.81 $3.73 $3.73 $3.73 $3.73 $3.73 $3.73 $3.73 $4.04 $3.88 $3.79

Index Price Comparison ($/Dth):17 ANR SE $4.90 $5.61 $9.11 $5.07 $5.07 $5.88 $5.23 $4.61 $4.87 $4.38 $4.41 $4.80 $5.2818 ANR SW $4.63 $5.13 $8.67 $4.80 $4.91 $5.59 $5.16 $4.57 $4.76 $4.31 $4.21 $4.68 $5.0919 Emerson $4.64 $5.41 $8.73 $5.01 $4.90 $5.68 $5.02 $4.42 $4.66 $4.16 $4.19 $4.59 $5.0720 MCCG $4.94 $5.65 $9.65 $5.37 $5.40 $6.17 $5.64 $4.84 $5.13 $4.72 $4.75 $5.03 $5.6621 PEPL $4.63 $5.13 $8.67 $4.80 $4.91 $5.59 $5.16 $4.57 $4.76 $4.31 $4.21 $4.68 $5.2022 Vector $4.98 $5.56 $9.25 $5.23 $5.21 $5.91 $5.48 $4.69 $5.02 $4.63 $4.66 $4.93 $5.8523 TGC ELA $4.78 $5.52 $9.04 $5.06 $5.05 $5.85 $5.18 $4.58 $4.84 $4.50 $4.40 $4.79 $4.6024 Total $4.82 $5.47 $9.15 $5.13 $5.14 $5.89 $5.35 $4.66 $4.91 $4.47 $4.38 $4.79 $5.37

Price Compare Variance ($/Dth):25 ANR SE ($1.12) ($1.83) ($5.33) ($1.29) ($1.29) ($2.10) ($1.45) ($0.83) ($1.09) ($0.60) ($0.17) ($0.73) ($1.42)26 ANR SW ($1.13) ($1.63) ($5.17) ($1.30) ($1.41) ($2.09) ($1.66) ($1.07) ($1.26) ($0.81) ($0.23) ($1.18) ($1.53)27 Emerson ($1.13) ($1.90) ($5.22) ($1.47) ($1.36) ($2.14) ($1.48) ($0.88) ($1.12) ($0.62) ($0.40) ($1.08) ($1.52)28 MCCG ($0.96) ($1.67) ($5.67) ($1.52) ($1.55) ($2.32) ($1.79) ($0.99) ($1.28) ($0.87) ($0.97) ($1.25) ($1.78)29 PEPL ($0.79) ($1.29) ($4.83) ($1.02) ($1.13) ($1.81) ($1.38) ($0.79) ($0.98) ($0.53) $0.29 ($0.09) ($1.26)30 Vector ($0.85) ($1.43) ($5.12) ($1.31) ($1.29) ($1.99) ($1.56) ($0.77) ($1.10) ($0.71) ($0.74) ($1.01) ($1.82)31 TGC ELA - - - - - - - - - - $0.57 $0.34 $0.4532 Total ($1.00) ($1.66) ($5.34) ($1.40) ($1.41) ($2.17) ($1.62) ($0.93) ($1.19) ($0.74) ($0.34) ($0.91) ($1.58)

Cost of Gas Compared to Index ($000):33 ANR SE ($1,387) ($2,048) ($6,608) ($1,547) ($1,598) ($2,519) ($1,796) ($1,028) ($1,307) ($742) ($312) ($1,132) ($22,023)34 ANR SW ($1,403) ($1,827) ($6,412) ($1,562) ($1,750) ($2,510) ($2,060) ($1,328) ($1,514) ($1,006) ($420) ($1,465) ($23,256)35 Emerson ($1,754) ($2,662) ($8,093) ($2,647) ($2,530) ($3,844) ($2,755) ($1,643) ($2,011) ($1,154) ($711) ($1,679) ($31,485)36 MCCG ($3,295) ($5,183) ($19,502) ($5,376) ($5,665) ($8,208) ($6,543) ($3,617) ($4,527) ($3,178) ($1,753) ($2,332) ($69,177)37 PEPL ($780) ($1,152) ($4,788) ($672) ($769) ($1,193) ($940) ($538) ($646) ($360) $261 ($73) ($11,650)38 Vector ($787) ($1,198) ($4,759) ($393) ($400) ($597) ($484) ($239) ($330) ($220) ($222) ($313) ($9,942)39 TGC ELA $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $173 $104 $27640 Total ($9,406) ($14,071) ($50,161) ($12,196) ($12,713) ($18,870) ($14,578) ($8,392) ($10,334) ($6,660) ($2,985) ($6,890) ($167,256)

41 Note: Emerson Monthly Index Price publication was discontinued effective Jun03.42 Note: The average Emerson Monthly Index Price for Jan03 through May03 was equal to NYMEX LTD less $0.27.43 Note: Index Comparison Price for Emerson is assumed equal to NYMEX LTD less $0.27 for Jun03 through Dec03.

Case No. : U-13549-RWitness: R. G. Lawshe

Exhibit No.: A-18 (RGL-6)Page No.: 1 of 1

Interstate Interstate Total Purchased InterstateSpot Purchases Term PurchasesVolume Gas Cost Volume Gas Cost Volume Gas Cost Cost per

Line Month (Dth) ($) (Dth) ($) (Dth) ($) Dth ($)(Col. 1) (Col. 2) (Col. 3) (Col. 4) (Col. 5) (Col. 6) (Col. 7)

1 January 697,934 $3,572,026 8,208,693 $34,569,164 8,906,627 $38,141,190 $4.282 February 0 0 7,804,452 35,388,494 7,804,452 $35,388,494 4.533 March 310,000 2,864,830 7,298,698 40,776,674 7,608,698 $43,641,504 5.744 April 989,979 5,053,708 6,359,855 26,707,471 7,349,834 $31,761,179 4.325 May 1,007,178 5,097,599 6,571,887 27,541,462 7,579,065 $32,639,061 4.316 June 825,000 4,836,375 6,507,372 29,511,832 7,332,372 $34,348,207 4.687 July 553,500 2,897,285 7,029,053 30,352,972 7,582,553 $33,250,257 4.398 August 398,522 1,840,729 7,192,000 29,341,267 7,590,522 $31,181,997 4.119 September 390,000 1,900,875 6,959,958 29,108,324 7,349,958 $31,009,199 4.22

10 October 386,200 1,716,732 7,192,000 28,541,313 7,578,200 $30,258,045 3.9911 November 1,245,000 5,278,515 7,050,860 29,667,917 8,295,860 $34,946,432 4.2112 December 0 0 9,290,700 40,526,339 9,290,700 $40,526,339 4.36

13 Total 6,803,313 $35,058,674 87,465,528 $382,033,228 94,268,841 $417,091,902 $4.42

14 YTD P to F adj (243,043) ($82,494) (243,043) ($82,494)

15 Total 6,803,313 $35,058,674 87,222,485 $381,950,733 94,025,798 $417,009,408 $4.44

Cost perMcf ($)

16 Cashout Vol. Mcf @ 14.65 0 (15,090) (15,090)17 Fuel Adjustment (276,109) (3,476,731) (3,752,840)18 Btu Adjustment (148,949) (1,858,952) (2,007,901)19 Total Mcf @ 14.73 6,378,255 81,871,794 88,250,04920 Total Mcf @ 14.65 6,413,335 82,322,089 88,735,424 $417,009,408 $4.70

2003

Interstate Purchases by Production MonthMichigan Consolidated Gas Company

(Total Purchased Cost Excluding Transportation and Cashouts)

Michigan Consolidated Gas CompanyAffiliate Purchase Summary

(2003)

Case No.: U-13549-RWitness: R.G.Lawshe

Exhibit No.: A-23 (RGL-11)Page No.: 1 of 1

Line Deal Term Term PurchaseNo. Affiliate Date Start End Dth/Day Point Justification

(Col.1) (Col.2) (Col.3) (Col.4) (Col.5) (Col.6) (Col.7)

1 CoEnergy 3/25/2003 4/1/2003 4/30/2003 10,000 MichCon CG CoEnergy Deal: $5.146 NYMEX plus $.222 Non-Affiliate Deal: $5.146 NYMEX plus $.23

1 CoEnergy 4/25/2003 5/1/2003 5/31/2003 10,000 MichCon CG CoEnergy Deal: $5.123 NYMEX plus $.2752 Non-Affiliate Deal: $5.123 NYMEX plus $.2753 Non-Affiliate Deal: $5.123 NYMEX plus $.275

4 CoEnergy 5/15/2003 6/1/2003 6/30/2003 10,000 MichCon CG CoEnergy Deal: $5.945 NYMEX plus $.2455 Non-Affiliate Deal: $5.945 NYMEX plus $.256 Non-Affiliate Deal: $5.945 NYMEX plus $.25

7 CoEnergy 6/18/2003 7/1/2003 7/31/2003 10,000 MichCon CG CoEnergy Deal: IFERC MichCon First of Month Index plus $.013758 Non-Affiliate Deal: IFERC MichCon First of Month Index plus $.01375

9 CoEnergy 7/18/2003 8/1/2003 10/31/2003 5,000 MichCon CG CoEnergy Deal: IFERC MichCon First of Month Index plus $.0110 Non-Affiliate Deal: IFERC MichCon First of Month Index plus $.0111 Non-Affiliate Deal: IFERC MichCon First of Month Index plus $.01



Line Description January February March April May June July August September October November December Year to Date(Col. 1) (Col. 2) (Col. 3) (Col. 4) (Col. 5) (Col. 6) (Col. 7) (Col. 8) (Col. 9) (Col. 10) (Col. 11) (Col. 12) (Col. 13)

Source of Gas

1 Purchased 13,297,215 14,830,244 14,630,739 17,664,713 18,271,925 15,313,097 17,812,198 18,980,611 16,582,407 19,724,621 13,159,072 13,613,634 193,880,476 2 Net (To) From Storage 19,766,274 14,131,623 5,794,249 (2,875,599) (5,983,879) (11,105,374) (14,378,551) (14,197,965) (11,992,349) (8,009,950) 3,220,823 13,034,890 (12,595,808) 3 Total Supply 33,063,489 28,961,867 20,424,988 14,789,114 12,288,046 4,207,723 3,433,647 4,782,646 4,590,058 11,714,671 16,379,895 26,648,524 181,284,668

Less Volumes For: Sales With No GCR Factor:

4 Company Use 272,035 220,040 190,125 104,438 118,776 118,227 197,325 158,416 147,461 113,781 96,880 146,321 1,883,825 5 Lost and Unaccounted For Gas 781,812 1,624,111 117,044 (544,116) (671,947) 1,166,778 (489,765) 468,982 412,089 958,126 (669,009) 1,920,397 5,074,502 6 Gas-in-Kind Provision (289,307) (263,500) (230,874) (165,248) (194,238) (247,520) (237,866) (214,508) (193,541) (255,724) (193,432) (251,793) (2,737,551) 7 Total GCR Supplies 32,298,949 27,381,216 20,348,693 15,394,040 13,035,455 3,170,238 3,963,953 4,369,756 4,224,049 10,898,488 17,145,456 24,833,599 177,063,892

GCR Sales 8 Rate Schedule Sales (Billed) 29,726,026 30,196,756 27,517,398 18,075,713 10,707,627 5,679,264 4,036,733 3,394,838 3,630,028 8,276,596 11,037,445 20,873,351 173,151,775 9 GCC Year 1 Settlement 0 0 0 0 4,425,047 0 0 425,642 0 0 0 0 4,850,689

10 Unbilled - Current Month 19,272,711 16,457,171 9,288,466 6,606,793 4,509,544 2,000,518 1,927,738 2,477,014 3,071,035 5,692,927 11,800,938 15,761,186 98,866,041 11 - Prior Month (16,699,788) (19,272,711) (16,457,171) (9,288,466) (6,606,793) (4,509,544) (2,000,518) (1,927,738) (2,477,014) (3,071,035) (5,692,927) (11,800,938) (99,804,643) 12 Total GCR Sales (Unbilled) 32,298,949 27,381,216 20,348,693 15,394,040 13,035,425 3,170,238 3,963,953 4,369,756 4,224,049 10,898,488 17,145,456 24,833,599 177,063,862

Michigan Consolidated Gas CompanyAnnual Reconciliation

2003

Case N

o. U-13549-R

Witness: J. C

. Schmidt

Exhibit N

o. A-24 (JC

S-1)

Page No. 1 of 2

All volumes Mcf @ 14.65 psia Dry unless otherwise noted.

Line Description January February March April May June July August September October November December Year to Date(Col. 1) (Col. 2) (Col. 3) (Col. 4) (Col. 5) (Col. 6) (Col. 7) (Col. 8) (Col. 9) (Col. 10) (Col. 11) (Col. 12) (Col. 13)

GCR Cost of Gas Sold 1 Purchased $61,467,241 $74,426,131 $92,482,730 $87,219,083 $87,999,795 $81,144,841 $88,889,321 $87,819,387 $76,903,774 $89,333,122 $60,974,482 $64,704,379 $953,364,2872 Net (To) From Storage 90,924,860 65,005,466 40,545,797 (14,234,215) (29,620,201) (54,971,601) (71,173,827) (70,279,927) (59,362,128) (39,649,253) 15,943,074 64,934,588 (61,937,367) 3 Total Cost of Gas Sold $152,392,101 $139,431,597 $133,028,527 $72,984,868 $58,379,594 $26,173,240 $17,715,493 $17,539,461 $17,541,647 $49,683,869 $76,917,556 $129,638,967 $891,426,921

Less: Sales with No GCR Factor4 Company Use $1,251,361 $1,012,184 $1,113,345 $516,968 $587,941 $585,224 $976,759 $784,159 $729,932 $563,216 $479,556 $662,688 $9,263,3335 Lost and Unaccounted For Gas 3,596,335 7,470,911 1,421,441 (2,693,374) (3,326,138) 5,775,551 (2,424,337) 2,321,461 2,039,841 4,742,724 (3,311,595) 9,340,029 24,952,8496 Gas-in-Kind Provision (1,330,812) (1,212,100) (1,336,309) (817,978) (961,478) (1,225,224) (1,177,437) (1,061,815) (958,028) (1,265,834) (957,488) (1,156,857) (13,461,360)7 SEC Revenue/Failure Fees - 10,382 186,393 243,514 - 6,103 3,802 4 2,702 16 2,354 7 455,275 8 GCR Cost of Gas Sold 148,875,217$ 132,150,220$ 131,643,657$ 75,735,738$ 62,079,269$ 21,031,587$ 20,336,706$ 15,495,651$ 15,727,200$ 45,643,747$ 80,704,730$ 120,793,101$ 870,216,824$

9 Average GCR Cost of Gas Sold $4.6093 $4.8263 $6.4694 $4.9198 $4.7623 $6.6341 $5.1304 $3.5461 $3.7233 $4.1881 $4.7071 $4.8641 $4.9147

Less:10 Prior Year GCR Over/(Under) Recovery($18,474,287) $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 ($18,474,287)11 90/10 Refunds - - - - - - - - - 645,462 977,203 1,029,402 2,652,067 12 Net Recoverable Costs 167,349,504$ 132,150,220$ 131,643,657$ 75,735,738$ 62,079,269$ 21,031,587$ 20,336,706$ 15,495,651$ 15,727,200$ 44,998,285$ 79,727,527$ 119,763,699$ 886,039,044$

GCR Revenues13 Maximum GCR Factor Permitted ($/Mcf) $4.1400 $4.5750 $4.5750 $4.5750 $4.5750 $4.5750 $4.9700 $5.7500 $5.7500 $5.7500 $5.7500 $5.500014 GCR Factor Billed ($/Mcf) $4.1400 $4.5750 $4.5750 $4.5750 $4.5750 $4.5750 $4.9700 $5.7500 $5.7500 $5.7500 $5.7500 $5.5000

15 Billed GCR Revenue $123,773,083 $137,205,842 $126,779,835 $82,971,692 $48,918,659 $26,295,656 $19,941,962 $19,119,427 $20,864,648 $47,280,094 $63,403,349 $114,624,080 $831,178,32616 GCC Year 1 Settlement 0 0 0 0 22,502,769 0 0 1,905,214 0 0 0 0 24,407,98417 Unbilled - Current Month 88,172,653 75,291,557 42,494,732 30,226,078 20,631,164 9,942,574 11,084,494 14,242,831 17,658,451 32,734,330 64,905,159 84,479,957 491,863,98018 - Prior Month (69,137,122) (88,172,653) (75,291,557) (42,494,732) (30,226,078) (20,631,164) (9,942,574) (11,084,494) (14,242,831) (17,658,451) (32,734,330) (64,905,159) (476,521,145) 19 Total GCR Revenue 142,808,613$ 124,324,746$ 93,983,010$ 70,703,038$ 61,826,514$ 15,607,067$ 21,083,881$ 24,182,978$ 24,280,269$ 62,355,973$ 95,574,178$ 134,198,878$ 870,929,145$

20 Over (Under) Recovery ($) (24,540,891)$ (7,825,474)$ (37,660,647)$ (5,032,700)$ (252,755)$ (5,424,520)$ 747,175$ 8,687,327$ 8,553,068$ 17,357,688$ 15,846,651$ 14,435,179$ (15,109,899)$

Annual Reconciliation2003


Case N

o. U-13549-R

Witness: J. C

. Schmidt

Exhibit N

o. A-24 (JC

S-1)

Page No. 2 of 2


Line Description January February March April May June July August September October November December Year to Date (Col. 1) (Col. 2) (Col. 3) (Col. 4) (Col. 5) (Col. 6) (Col. 7) (Col. 8) (Col. 9) (Col. 10) (Col. 11) (Col. 12) (Col. 13)

Source of Gas1 ANR Pipeline 0 (24,692) (33,762) 3,373 18,462 37,103 61,310 20,183 (30,147) (42,949) (82,331) 4,979 (68,471)2 Canadian Purchases - Great Lakes 899,199 833,157 855,760 913,781 907,407 879,322 914,220 920,977 886,625 918,538 894,354 936,384 10,759,7243 Spot/Term Purchases 13,930,062 14,225,871 13,495,267 16,595,672 15,643,758 14,624,954 15,705,276 17,164,871 16,207,255 18,164,308 11,024,194 13,571,658 180,353,1464 Intrastate 208,624 223,164 117,281 143,454 (90,263) 90,481 94,333 61,349 106,934 46,535 62,214 130,749 1,194,8555 Exchange Gas (1,740,670) (427,256) 196,193 8,433 1,120,428 (318,763) 615,747 813,231 (588,260) 638,087 1,260,641 (1,030,136) 547,6756 Other Purchased Gas - - - - 672,133 - 421,312 - - 102 - - 1,093,547 7 Total Purchased 13,297,215 14,830,244 14,630,739 17,664,713 18,271,925 15,313,097 17,812,198 18,980,611 16,582,407 19,724,621 13,159,072 13,613,634 193,880,476

Cost of Gas8 ANR Pipeline-Cost of Gas $2,605,798 $3,021,605 $2,429,060 $2,370,380 $3,528,336 $3,222,377 $3,343,165 $3,105,583 $2,888,052 $2,742,336 $2,104,476 $2,575,987 $33,937,1559 ANR Refunds 0 0 0 0 0 0 0 0 0 0 0 0 0

10 Canadian Purchases - Great Lakes 4,936,046 4,919,275 7,322,100 4,808,100 4,555,154 4,738,146 4,622,060 4,381,819 4,218,408 3,907,626 4,422,597 4,743,151 57,574,48311 Panhandle Eastern 0 0 0 0 0 0 0 0 0 0 0 0 012 Spot/Term Purchases 61,217,776 67,172,716 81,165,226 79,419,287 72,318,990 74,253,676 77,389,849 74,408,338 74,460,003 79,355,762 47,988,713 61,935,527 851,085,86313 Intrastate 742,816 1,277,912 973,777 646,626 (382,162) 508,643 485,977 213,960 (1,750,802) 168,364 218,523 563,606 3,667,24114 Other Purchased Gas Expenses 0 0 0 0 2,678,973 0 0 1,790,724 0 504 0 0 4,470,20115 Exchange Gas (8,035,195) (1,965,378) 592,567 (25,310) 5,300,504 (1,578,001) 3,048,269 3,918,964 (2,911,887) 3,158,531 6,240,173 (5,113,893) 2,629,344 16 Total Purchased Gas 61,467,241$ 74,426,131$ 92,482,730$ 87,219,083$ 87,999,795$ 81,144,841$ 88,889,321$ 87,819,387$ 76,903,774$ 89,333,122$ 60,974,482$ 64,704,379$ 953,364,287$

Sales by Revenue Class 17 Residential 239,056 191,935 163,544 129,606 92,356 45,534 62,732 51,975 60,673 107,575 139,927 187,243 1,472,15618 Residential Heating 23,912,618 20,737,510 14,985,021 11,003,436 6,577,031 2,440,829 2,790,041 2,668,684 3,090,776 8,335,174 13,000,397 18,537,530 128,079,04719 Commercial 433,768 238,601 286,336 213,038 130,696 130,890 116,291 178,312 57,300 175,239 194,500 295,663 2,450,63420 Commercial Heating 7,496,408 6,059,084 4,778,395 3,908,816 1,745,027 518,829 920,715 992,234 828,149 2,210,080 3,722,489 5,504,998 38,685,22421 Industrial 217,099 154,086 135,397 139,144 65,268 34,156 74,174 52,909 187,151 70,420 88,143 308,165 1,526,112 22 Subtotal 32,298,949 27,381,216 20,348,693 15,394,040 8,610,378 3,170,238 3,963,953 3,944,114 4,224,049 10,898,488 17,145,456 24,833,599 172,213,17323 Other - - - - 4,425,047 - - 425,642 - - - - 4,850,689 24 Total Sales (Unbilled) 32,298,949 27,381,216 20,348,693 15,394,040 13,035,425 3,170,238 3,963,953 4,369,756 4,224,049 10,898,488 17,145,456 24,833,599 177,063,862

Michigan Consolidated Gas CompanySupplemental Data

2003

Case N

o. U-13549-R

Witness: J. C

. Schmidt

Exhibit N

o. A-25 (JC

S-2)

Page No. 1 of 4



Sales by Rate Class 1 Rate 1 7,986,540 6,366,488 5,135,163 4,053,135 2,037,214 627,628 1,076,306 1,112,118 942,668 2,423,543 3,861,429 5,917,023 41,539,255 2 Rate 2 21,917,294 19,040,773 13,746,026 9,932,103 5,913,801 2,202,674 2,572,341 2,437,760 2,806,136 7,579,850 11,863,553 17,010,274 117,022,585 3 Rate 2A 1,042,907 867,625 672,347 666,868 428,721 180,865 191,543 193,701 235,906 462,182 668,042 867,372 6,478,078 4 Rate 3 330,582 296,835 210,372 151,653 94,630 30,208 25,440 24,407 31,760 117,885 177,695 249,677 1,741,144 5 Rate 3A 860,891 724,212 519,819 382,418 232,236 72,616 63,449 64,792 77,646 282,832 431,034 597,450 4,309,3946 Rate 6 45,795 5,714 3,929 8,567 5,474 7,005 31,030 107,695 118,565 (21,409) 20,997 77,288 410,651 7 Rate 10 114,940 79,570 61,037 199,296 (101,698) 49,242 3,844 3,642 11,368 53,605 122,707 114,515 712,066 8 Other - - - - 4,425,047 - - 425,642 - - - - 4,850,689 9 Total Sales (Unbilled) 32,298,949 27,381,216 20,348,693 15,394,040 13,035,425 3,170,238 3,963,953 4,369,756 4,224,049 10,898,488 17,145,456 24,833,599 177,063,862

Number of Customers10 Residential 23,379 23,354 23,593 23,717 23,657 23,671 23,336 23,357 23,215 23,379 23,167 23,19611 Residential Heating 978,329 981,574 1,002,528 1,016,900 1,020,154 1,022,238 1,013,270 1,015,718 1,015,288 978,329 1,018,442 1,021,57112 Commercial 3,973 3,973 4,075 4,236 4,282 4,314 3,903 3,882 3,846 3,973 3,879 3,88713 Commercial Heating 73,978 74,159 76,089 78,219 78,019 78,113 68,965 68,909 68,864 73,978 70,938 71,36214 Industrial 535 514 524 546 555 553 379 380 375 535 413 40315 Other - - - - - - - - - - - - 16 Total Customers 1,080,194 1,083,574 1,106,809 1,123,618 1,126,667 1,128,889 1,109,853 1,112,246 1,111,588 1,080,194 1,116,839 1,120,419

Total Revenue17 Gross Sales Billed $178,035,012 $191,345,262 $177,668,969 $119,519,564 $96,571,768 $44,074,853 $35,367,418 $34,827,572 $35,328,786 $69,819,100 $87,369,314 $155,411,507 $1,225,339,12518 Unbilled Adjustment 23,104,219 (17,220,650) (43,465,213) (16,362,142) (12,850,571) (14,560,221) 1,050,912 4,017,507 4,296,924 19,079,139 41,096,085 25,705,373 13,891,362 19 Sales Revenue (Unbilled) 201,139,231$ 174,124,612$ 134,203,756$ 103,157,422$ 83,721,197$ 29,514,632$ 36,418,330$ 38,845,079$ 39,625,710$ 88,898,239$ 128,465,399$ 181,116,880$ 1,239,230,487$

Less Revenue For 20 Sales With No GCR Factor: - - - - 22,502,769 - - 1,905,214 - - - - 24,407,984 21 Total Revenue 201,139,231$ 174,124,612$ 134,203,756$ 103,157,422$ 61,218,427$ 29,514,632$ 36,418,330$ 36,939,865$ 39,625,710$ 88,898,239$ 128,465,399$ 181,116,880$ 1,214,822,503$


2003

Case N

o. U-13549-R

Witness: J. C

. Schmidt

Exhibit N

o. A-25 (JC

S-2)

Page No. 2 of 4



Billed Sales by Rate Class 1 Rate 1 7,055,634 7,081,543 6,726,145 4,629,477 2,624,150 1,278,257 1,036,071 929,032 877,855 1,875,904 2,489,759 4,888,081 41,491,908 2 Rate 2 20,429,999 20,897,408 18,792,712 11,918,259 7,226,532 3,881,871 2,664,288 2,145,004 2,367,930 5,677,773 7,620,881 14,334,514 117,957,171 3 Rate 2A 988,073 976,207 899,893 711,349 484,624 286,771 196,093 166,130 193,456 370,799 446,115 765,972 6,485,481 4 Rate 3 311,161 322,702 288,410 182,707 113,577 57,516 31,109 22,700 26,177 82,965 113,456 211,375 1,763,855 5 Rate 3A 799,599 804,291 715,337 457,879 281,176 140,527 77,125 58,754 65,284 200,294 274,894 507,872 4,383,031 6 Rate 6 37,019 19,234 10,520 9,123 6,198 6,721 22,960 68,604 91,344 33,100 21,151 56,922 382,897 7 Rate 10 104,541 95,372 84,381 166,919 (28,630) 27,601 9,087 4,615 7,982 35,761 71,190 108,615 687,432 8 Other - - - - 4,425,047 - - 425,642 - - - - 4,850,689 9 Total Billed Sales 29,726,026 30,196,756 27,517,398 18,075,713 15,132,674 5,679,264 4,036,733 3,820,480 3,630,028 8,276,596 11,037,445 20,873,351 178,002,464

Change in Unbilled Volume10 Rate 1 930,906 (715,055) (1,590,982) (576,342) (586,936) (650,629) 40,235 183,086 64,813 547,639 1,371,670 1,028,94211 Rate 2 1,487,295 (1,856,635) (5,046,686) (1,986,156) (1,312,731) (1,679,197) (91,947) 292,756 438,206 1,902,077 4,242,672 2,675,76012 Rate 2A 54,834 (108,582) (227,546) (44,481) (55,903) (105,906) (4,550) 27,571 42,450 91,383 221,927 101,40013 Rate 3 19,421 (25,867) (78,038) (31,054) (18,947) (27,308) (5,669) 1,707 5,583 34,920 64,239 38,30214 Rate 3A 61,292 (80,079) (195,518) (75,461) (48,940) (67,911) (13,676) 6,038 12,362 82,538 156,140 89,57815 Rate 6 8,776 (13,520) (6,591) (556) (724) 284 8,070 39,091 27,221 (54,509) (154) 20,36616 Rate 10 10,399 (15,802) (23,344) 32,377 (73,068) 21,641 (5,243) (973) 3,386 17,844 51,517 5,90017 Other - - - - - - - - - - - - 18 Total Unbilled Volume Balance 2,572,923$ (2,815,540)$ (7,168,705)$ (2,681,673)$ (2,097,249)$ (2,509,026)$ (72,780)$ 549,276$ 594,021$ 2,621,892$ 6,108,011$ 3,960,248$


2003

Case N

o. U-13549-R

Witness: J. C

. Schmidt

Exhibit N

o. A-25 (JC

S-2)

Page No. 3 of 4



Billed GCR Revenues by Rate Class 1 Rate 1 $29,468,632 $32,202,465 $31,452,573 $21,515,737 $11,985,632 $6,044,462 $5,122,793 $5,168,672 $5,169,271 $10,687,823 $14,335,450 $26,590,772 $199,744,281 2 Rate 2 84,985,226 94,917,022 86,154,923 54,469,908 33,016,721 17,862,189 13,173,326 12,161,412 13,504,553 32,458,484 43,671,846 78,935,617 565,311,227 3 Rate 2A 4,110,447 4,432,679 4,127,580 3,253,153 2,213,091 1,317,543 952,525 952,867 1,088,203 2,110,584 2,637,143 4,223,733 31,419,549 4 Rate 3 1,293,880 1,469,458 1,324,127 835,848 519,227 265,038 154,890 131,116 151,328 476,722 652,235 1,165,184 8,439,053 5 Rate 3A 3,325,754 3,662,825 3,283,910 2,094,188 1,285,787 648,587 384,182 339,464 380,126 1,152,176 1,581,867 2,801,453 20,940,319 6 Rate 6 153,550 87,964 49,711 41,740 28,358 31,269 108,941 337,697 525,224 190,327 121,622 308,508 1,984,912 7 Rate 10 435,594 433,428 387,010 761,118 (130,157) 126,569 45,305 28,200 45,943 203,978 403,185 598,813 3,338,986 8 Total Billed GCR Revenue 123,773,083$ 137,205,842$ 126,779,835$ 82,971,692$ 48,918,659$ 26,295,656$ 19,941,962$ 19,119,427$ 20,864,648$ 47,280,094$ 63,403,349$ 114,624,080$ 831,178,326$

Unbilled GCR Revenues by Rate Class 9 Rate 1 $5,843,851 ($3,271,378) ($7,278,741) ($2,636,765) ($2,685,233) ($2,797,085) $585,893 $1,052,745 $372,674 $3,148,925 $7,221,606 $5,142,452 $4,698,944

10 Rate 2 11,919,272 (8,494,105) (23,088,589) (9,086,663) (6,005,745) (7,143,437) 535,440 1,683,346 2,519,685 10,936,943 22,358,354 13,201,347 9,335,848 11 Rate 2A 505,679 (496,763) (1,041,023) (203,500) (255,756) (445,734) 50,429 158,534 244,087 525,452 1,156,837 476,727 674,969 12 Rate 3 168,159 (118,341) (357,025) (142,072) (86,682) (116,827) (16,587) 9,815 32,103 200,790 339,048 188,316 100,697 13 Rate 3A 479,260 (366,361) (894,495) (345,234) (223,901) (290,742) (39,242) 34,719 71,081 474,594 824,328 438,990 162,997 14 Rate 6 46,774 (61,856) (30,153) (2,544) (3,312) 2,443 48,662 224,772 156,522 (313,428) (6,538) 105,994 167,336 15 Rate 10 72,536 (72,294) (106,799) 148,125 (334,286) 102,793 (22,673) (5,595) 19,470 102,603 277,194 20,968 202,042 16 Total GCR Revenue 19,035,531$ (12,881,098)$ (32,796,825)$ (12,268,653)$ (9,594,915)$ (10,688,589)$ 1,141,922$ 3,158,336$ 3,415,622$ 15,075,879$ 32,170,829$ 19,574,794$ 15,342,833$

Revenues by Rate Class (Unbilled Basis)17 Rate 1 $35,312,483 $28,931,087 $24,173,832 $18,878,972 $9,300,399 $3,247,377 $5,708,686 $6,221,417 $5,541,945 $13,836,748 $21,557,056 $31,733,224 $204,443,22518 Rate 2 96,904,498 86,422,917 63,066,334 45,383,245 27,010,976 10,718,752 13,708,766 13,844,758 16,024,238 43,395,427 66,030,200 92,136,964 574,647,075 19 Rate 2A 4,616,126 3,935,916 3,086,557 3,049,653 1,957,335 871,809 1,002,954 1,111,401 1,332,290 2,636,036 3,793,980 4,700,460 32,094,518 20 Rate 3 1,462,039 1,351,117 967,102 693,776 432,545 148,211 138,303 140,931 183,431 677,512 991,283 1,353,500 8,539,750 21 Rate 3A 3,805,014 3,296,464 2,389,415 1,748,954 1,061,886 357,845 344,940 374,183 451,207 1,626,770 2,406,195 3,240,443 21,103,316 22 Rate 6 200,324 26,108 19,558 39,196 25,046 33,712 157,603 562,469 681,746 (123,101) 115,084 414,502 2,152,248 23 Rate 10 508,130 361,134 280,211 909,243 (464,443) 229,362 22,632 22,605 65,413 306,581 680,379 619,781 3,541,028 24 Total GCR Revenue 142,808,614$ 124,324,744$ 93,983,010$ 70,703,039$ 39,323,744$ 15,607,067$ 21,083,884$ 22,277,763$ 24,280,270$ 62,355,973$ 95,574,178$ 134,198,874$ 846,521,159$

Supplemental Data2003


Case N

o. U-13549-R

Witness: J. C

. Schmidt

Exhibit N

o. A-25 (JC

S-2)

Page No. 4 of 4


Line Month

Contract Storage Revenue

Excess Storage Fees

Total Monthly Revenue

Cumulative Revenue

Revenue in Excess of Limit (1)

90:10 Refund Liability

(Col 1) (Col 2) (Col 3) (Col 4) (Col 5) (Col 6)Col 1 + Col 2 Col 5 * 90%

1 January 956,623$ 27,744$ 984,367$ 984,367$ -$ -$ 2 February 804,455 4,044 808,500 1,792,867 - - 3 March 784,949 (3,390) 781,558 2,574,425 - - 4 April 764,966 20,853 785,819 3,360,243 - - 5 May 735,255 13,099 748,355 4,108,598 - - 6 June 687,395 15,470 702,865 4,811,463 - - 7 July 959,358 41,755 1,001,112 5,812,575 - - 8 August 1,022,843 51,504 1,074,347 6,886,922 - - 9 September 1,012,541 65,968 1,078,509 7,965,431 - - 10 October 1,031,093 72,655 1,103,748 9,069,180 (717,180) (645,462) 11 November 1,065,626 20,155 1,085,781 10,154,961 (1,085,781) (977,203) 12 December 1,114,693 29,088 1,143,780 11,298,741 (1,143,780) (1,029,402)

13 Total 10,939,796$ 358,945$ 11,298,741$ (2,946,741)$ (2,652,067)$

(1) Annual Limit is $8,352,000, per Case No. U-10150

MICHIGAN CONSOLIDATED GAS COMPANY2003 90:10 REFUND LIABILITY

Case No. U-13549-R Witness: J. C. Schmidt Exhibit No. A-26 (JCS-3) Page No. 1 of 1

Beginning Balance Current Month Current Month InterestOver/(Under) Over/(Under) Current Month Base For Interest (Revenue)/

Line Month Recovery Recovery Average Interest Accrual Rate ExpenseCol. 1 Col. 2 Col. 3 Col. 4 Col. 5 Col. 6

(Col. 2 * 50%) (Col. 1 + Col. 3) (Col. 4 * Col. 5 * days in month / 365)

1 1/1/02 Balance (18,474,287)$ 2 January (18,474,287)$ (6,066,604) (3,033,302)$ (21,507,589)$ 1.360% (24,843)$ 3 February (24,540,891) (7,825,474) (3,912,737) (28,453,628) 1.340% (29,249) 4 March (32,366,365) (37,660,647) (18,830,324) (51,196,689) 1.180% (51,309) 5 April (70,027,012) (5,032,700) (2,516,350) (72,543,362) 1.100% (65,587) 6 May (75,059,712) (252,755) (126,378) (75,186,090) 1.120% (71,519) 7 June (75,312,467) (5,424,520) (2,712,260) (78,024,727) 1.110% (71,184) 8 July (80,736,987) 747,175 373,588 (80,363,400) 0.890% (60,746) 9 August (79,989,812) 8,687,327 4,343,664 (75,646,149) 1.070% (68,745)

10 September (71,302,485) 8,553,068 4,276,534 (67,025,951) 1.070% (58,946) 11 October (62,749,417) 17,357,688 8,678,844 (54,070,573) 1.080% (49,597) 12 November (45,391,729) 15,846,651 7,923,326 (37,468,404) 1.080% (33,260) 13 December (29,545,078) 14,435,179 7,217,590 (22,327,489) 1.080% (20,480)

14 TOTAL (15,109,899)$ (605,465)$

15 TOTAL UNDERRECOVERY PLUS INTEREST (15,715,364)$

Note: If the beginning balance for any month plus the current month average balance is overcollected, the interest rate utilized in Column 5 is the allowed rate of return of 11.5%.If the beginning balance plus the current month average balance is undercollected, the interest rate is the average short term borrowing rate for the current month.

MICHIGAN CONSOLIDATED GAS COMPANYGCR INTEREST CALCULATION

2003

Case No.: U-13549-RWitness: J. C. SchmidtExhibit No.: A-27 (JCS-4)Page No.: 1 of 1

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CASE NO.: U-13549-R WITNESS: D.M. STANCZAK EXHIBIT: A-32 (DMS-1) PAGE NO.: 1 OF 2

e60770

CASE NO.: U-13549-R WITNESS: D.M. STANCZAK EXHIBIT: A-32 (DMS-1) PAGE NO.: 2 OF 2

MichCon Other EnronContract Claims

Line Termination AgainstNo. M to M Percent DTE Percent Total

(Col. 1) (Col. 2) (Col. 3) (Col. 4) (Col. 5)

1 Initial Enron Claim Against DTE (1) 16$ 57% 12$ 43% 28$

2 Pro Rata Allocation of Settlement 10.5$ 57% 7.8$ 43% 18.3$

3 Initial Enron Claim Against DTE (1) 16$ 12$ 28$

4 Less Clinton Settlement (1) (2)$ (2)$

5 Net Claim W/O Clinton Settlement 16$ 62% 10$ 38% 26$

6 Pro Rata Allocation of Settlement 10.0$ 62% 6.3$ 38% 16.3$

7 Actual Settlement Amount as Booked 8.0$ 44% 10.3$ 56% 18.3$

(1) Sources: Exhibit A-___(DMS-1) - July 10, 2003 Hogan & Hartson Letter &Exhibit I-___(REM-4) - March 12, 2003 E-mail from Craig Ulman to Patrick Carey

Description

MICHIGAN CONSOLIDATED GAS COMPANYPRO RATA ALLOCATION OF ENRON SETTLEMENT

($-MILLIONS)

e61968

Case No.: U-13549-R Witness: D. M. Stanczak Exhibit No.: A-33 (DMS-2) Page No.: 1 of 1

case no.: u-13549-r witness: v.e. borra exhibit no.: a- 1

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