GAS ADJUSTMENTS EFFECTIVE JULY 1, 1996
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CLEARWATER GAS SYSTEM
Interoffice Co"espondence Sheet
TO: Betty Deptula, City Manager
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FROM: Chuck Warrington, Gas System Managing Director ,~rr
COPIES: Kathy Rice, Deputy City Manager; Margie Simmons, Finance Director;
CGS Management Team; John Scott, Asst. Director Finance/UCS;
Tom Madley, Senior Accountant; Karen Miles, Accounting Manager
SUBJECT: GAS ADJUSTMENTS EFFECTIVE JULY 1, 1996
DATE: June 15, 1996
We have recalculated our Purchased Gas Adjustment (PGA), Energy Conservation
Adjustment (ECA), and Environmental Imposition Adjustment (EIA) costs for the
remainder of this year based on our mid-year budget adjustments and current market
conditions/forecasts and recommend your approval of the following rates to become
effective July 1, 1996:
Natural Gas Firm Standard Rate Schedule PGA ....... $0.390 per therm (up 3(:)
Natural Gas Interruptible and Contract
(Non-Standard) Rate Schedule PGA ............. $0.273 per therm (up 3(:)
Propane (LP) Gas Rate Schedule PGA .................... $0.540 per gallon (no change)
= $0.590 per therm equivalent
Energy Conservation Adjustment (ECA) ............... $0.070 per therm (up 4(:)
= $0.064 per gallon of LP
(up 3.7(:)
Environmental Imposition Adjustment (EIA) ......... $0.010 per therm (up 0.5(:)
= $0.009 per Gallon of LP
(up 0.4(:)
Weather Normalization Adjustment (WNA) .......... Not Applicable at this time
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Betty Deptula, City Manager
Page 2
June 15, 1996
We have reassessed our Rate Adjustment Clauses based on our current status as of
the end of April and forecasted for the balance of the fiscal year based on current
market conditions. As shown on Attachment #1, our current Rate Adjustment
Clause balance as of the end of April is $430,366 and our projections for fiscal year
end is an underrecovery of $357,966 without corrections to our Rate Adjustment
Clauses. As you know, our rates require us to notify you if our actuals or projections
exceed $100,000 for PGA, ECA or EIA, which is now the case. Based on our
projections, we are recommending a three (3) month correction in our recovery
factors which we estimate would bring us essentially current by fiscal year end for all
but the EIA (and that factor is designed to be recovered over a 3 year period).
Attachment #2 shows our projections of the impact of these corrected Rate
Adjustment Clauses which we forecast will reduce our underrecovery by $226,405
to $131,561 by fiscal year end.
Betty, the gas commodity markets have remained much higher than we last
forecasted in my March 19th memo to you. The colder than normal winter,
particularly the Northeastern U.S., has resulted in the natural gas storage fields and
propane (LP) storage tanks nationally being depleted considerably below normal
levels. This has caused an increase in the world-wide gas demand, resulting in higher
prices for both natural and propane (LP) gas as this storage is replenished. Current
gas price forecasts do not project any real relief in this trend until next summer.
Therefore, we also expect FY 96/97 fuel pricing to exceed our previous budget
projections which will require our PGA levels to be higher than we originally
forecasted for FY 96/97. Additionally, we have adjusted the recommended ECA in
line with our recommended mid-year budget adjustments.
I recommend that we make this mid-cycle correction at this time for four (4) reasons.
First, I believe that it is good policy to recover these Rate Adjustment Clause dollars
in the fiscal year that they are incurred. This keeps our financials accurate in that
they would otherwise be distorted with these unbillable amounts. Second, I would
recommend that we catch up these balances before the new gas rates go into effect
on October 1 st. Otherwise, this would necessitate even higher recovery rates for
these Rate Adjustment Clauses which will make gas rates even higher in the Fall.
Third, this is the lowest usage period and an increase in the per therm rates will least
affect our customers bills in this period. Finally, this will lessen the rate shock of the
new rates. As you will note, Attachment #3 shows that the resulting summer
Residential natural gas rate would be 95C/therm. Attachment #8 shows that the
new residential rates effective October 1996 (with our preliminary projections for the
Rate Adjustment Clauses based on Attachments #6 & #7) would be 95C/therm.
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Betty Deptula, City Manager
Page 3
June 15, 1996
Therefore, our residential customers would see only the impact of the $1 .00 increase
in their Customer Charge in October, as the therm rate increase of 5C is projected to
be offset by a corresponding decrease in the Rate Adjustment Clauses of 5C (4C in
ECA and 1 C in PGA).
The following attachments document these recommended rates:
Attachment #1:
Attachment #2:
Attachment #3:
Attachment #4:
Attachment #5:
Attachment #6:
Attachment #7:
Is our Summary of Rate Adjustment Clause Calculations showing
our projections of FY 95/96 year end results without the
recommended July 1st mid-cycle corrections.
Is our Summary of Rate Adjustment Clause Calculations showing
our projections of FY 95/96 year end results with our
recommended July 1st mid-cycle corrections.
Shows the resulting Natural Gas Rate Billing Factors proposed to
become effective for 07/01/96 - 9/30/96 based on the
recommended adjustments to PGA, ECA, and EIA.
Shows the resulting Propane (LP) Gas Rate Billing Factors
proposed to become effective for 07/01/96 - 9/30/96 based on
the recommended adjustments to PGA, ECA, and EIA.
Shows the projected comparison of our residential rates with
Peoples Gas System (PGS) based on our recommended July 1st
corrections in our Rate Adjustment Clauses verses PGS's current
rates. You will note that this will makes our residential rate for
25 therms of monthly usage $1.20 higher than PGS; however,
you should note that we have been as much as $1.63 lower than
PGS during the winter months when they had held their PGA at a
much higher level than ours.
Shows our preliminary calculation of PGA for both natural and
propane (LP) gas for FY 96/97. You will note that these
projections reflect a 4C higher natural gas PGA for October than
we had projected in the Rate Study as a result of the current
market conditions.
Shows our preliminary calculations for ECA and EIA based our
proposed FY 96/97 budget.
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Betty Deptula, City Manager
Page 4
June 15, 1996
Attachment #8:
Shows our preliminary projection of the Natural Gas Rate Billing
Factors proposed to become effective on October 1 st based on
the forecasted PGA, ECA, and EIA.
Attachment #9:
Shows our preliminary projection of the Propane (LP) Gas Rate
Billing Factors proposed to become effective on October 1 st
based on the forecasted PGA, ECA, and EIA.
It is our plan to use the above proposed adjustments for billings through September
30, 1996, unless there is a further significant change in our forecasts or we project
an over/under recovery in excess of the thresholds as prescribed in our rate
ordinance. We will continue to track these balances monthly. We will monitor these
monthly and let you know if any of these get significantly out of balance. We will
also continue to provide you with a summary of our adjustment status as a part of
the monthly financial statements.
Finally, I would like to make a formal recommendation for your approval regarding the
Weather Normalization Adjustment (WNA) Clause. I would ask for your approval that
we not invoke this Clause for this year. Even though the winter Heating Degree Days
exceeded the ten (10) year historical average by 70% (817 vs. 481), the earnings of
the Gas System were not enhanced above plan based on the problems that we
encountered with the Phase I Rate implementation. The WNA rider specifically
states, "The implementation of the WNA will be at the sole discretion of the City
Manager only if the heating degree day data for the winter season exceeds at least a
10% variation from the ten (10) year historical average and the City Manager
determines that this has created a material impact on the earnings of the Clearwater
Gas System for the year warranting the WNA implementation. n While the first
condition was met, I would maintain that the second was not. We estimate that the
added heating degree days this year resulted in approximately $300,000 in improved
earnings; however, the rate problems eroded our earnings by $1.3 Million.
Betty, I would appreciate your approval of these new adjustment clause rates so that
I may get them to UCS for implementation on July 1, 1996. If you have any
questions on this, please call me.
CSW /csw
Attachments
Approved:
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Bet~ep la, City Manager
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fCSW:6115/96 II Ij I ATTACHMENT #1
CLEARWATER GAS SYSTEM Page 1 of 2
SUMMARY OF RATE ADJUSTMENT CLAUSE COLLECTIONS
(At Currently Effective Rates)
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NATURAL GAS PURCHASED GAS ADJUSTMENT (PGA-NG)
Monthly Cummulatlve
Budget Reservation Commodity Cost Center Total NG Fuel Total NG PGA Overage YTD Overage PGA
Month Charges Charges Expenses Expenses Billed (Shortage) (Shortage) Rate
Prior Year $ - $ - $ - $ - $ - $ - $ -
Oct-95 $ 123,043.58 $ 201,837,74 $ 1,649.40 $ 326,530.72 $ 292,679.84 $ (33,850.88) $ (33,850.88) 0.32/0.234
Nov-95 $ 169,542,26 $ 229,280.63 $ 953,99 $ 399,776.88 $ 328,780.15 $ (70,996.73) $ (104,847,61) 0.32/0,234
Dec-95 $ 178,384.56 $ 361,079.89 $ 672.68 $ 540,137.13 $ 466,281.94 $ (73,855.19) $ (178,702.80) 0.32/0.234
Jan-96 $ 174,798.92 $ 518,487,54 $ 713,36 $ 693,999.82 $ 705,130,51 $ 11,130.69 $ (167,572.11) 0.36/0.274
Feb-96 $ 160,615,00 $ 591,968,27 $ 10,804.17 $ 763,387.44 $ 731,966.41 $ (31,421,03) $ (198,993.14) 0.36/0.274
Mar -96 $ 169,019.00 $ 443,010.57 $ 8,864,28 $ 620,893.85 $ 623,157.53 $ 2,263.68 $ (196,729.46) 0.36/0.274
Apr-96 $ 163,759,00 $ 413,027.00 $ 4,316.94 $ 581,102,94 $ 586,757.36 $ 5,654.42 $ (191,075,04) 0.36/0.243
May-96 $ 80,000.00 $ 323,400.00 $ 6,000.00 $ 409,400.00 $ 441,270.00 $ 31,870.00 $ (159,205.04) 0.36/0.243
Jun-96 $ 80,000.00 $ 296,450.00 $ 6,000.00 $ 382,450.00 $ 402,840,00 $ 20,390,00 $ (138,815.04) 0.36/0.243
Jul-96 $ 80,000.00 $ 284,200.00 $ 6,000.00 $ 370,200,00 $ 386,010.00 $ 15,810.00 $ (123,005.04) 0.36/0,243
Aug-96 $ 80,000.00 $ 269,500.00 $ 6,000.00 $ 355,500.00 $ 364,410.00 $ 8,910.00 $ (114,095.04) 0.36/0.243
Sep-96 $ 80,000,00 $ 276,850.00 $ 6,000.00 $ 362,850,00 $ 375,210.00 $ 12,360.00 $ (101,735.04) 0,36/0.243
Total YTD $1,539,162.32 $ 4,209,091.64 $ 57,974.82 $ 5,806,228.78 $ 5,704,493.74 $ (101,735.04)
PROPANE (LP) GAS PURCHASED GAS ADJUSTMENT (PGA-LP)
Monthly Cummulatlve
Budget Gallons Monthly Commodity Total LP Fuel Total LP PGA Overage YTD Overage PGA
Month Sold WACOG Charges Expenses allied (Shortage) (Shortage) Rate
Prior Year 0 $ - $ - $ - $ - $ - $ -
Oct-95 9,884.67 $ 0.45915 $ 4,538.55 $ 4,538.55 $ 4,456.74 $ (81.81) $ (81.81 ) 0.48/0.525
Nov-95 10,048.28 $ 0.45848 $ 4,606.94 $ 4,606.94 $ 5,533.32 $ 926.38 $ 844.58 0.48/0.525
Dec-95 14,736.72 $ 0.45708 $ 6,735.86 $ 6,735.86 $ 8,685.86 $ 1,950.00 $ 2,794.58 0.48/0.525
Jan-96 20,710.64 $ 0.46244 $ 9,577.43 $ 9,577.43 $ 7,413,29 $ (2,164.14) $ 630.44 0.48/0.525
Feb-96 19,241.97 $ 0.49890 $ 9,599.82 $ 9,599.82 $ 9,219.25 $ (380.57) $ 249.87 0.48/0,525
Mar-96 18,924.00 $ 0.54076 $ 10,233.34 $ 10,233.34 $ 9,083.05 $ (1,150.29) $ (900.42) 0.48/0.525
Apr-96 20,069.60 $ 0.55708 $ 11,180.37 $ 11,180.37 $ 11,164.21 $ (16.16) $ (916.58) 0.54/0,59
May-96 16,000.00 $ 0.53264 $ 8,522.24 $ 8,522.24 $ 8,640.00 $ 117.76 $ (798,82) 0,54/0.59
Jun-96 16,000.00 $ 0.53264 $ 8,522.24 $ 8,522.24 $ 8,640.00 $ 117.76 $ (681.06) 0.54/0.59
Jul-96 16,000,00 $ 0.52500 $ 8,400.00 $ 8,400.00 $ 8,640.00 $ 240.00 $ (441.06) 0.54/0,59
Aug-96 16,000.00 $ 0.52000 $ 8,320.00 $ 8,320.00 $ 8,640.00 $ 320.00 $ (121.06) 0.54/0.59
Sep-96 16,000.00 $ 0.51500 $ . 8,240.00 $ 8,240.00 $ 8,640.00 $ 400.00 $ 278.94 0,54/0.59
Total YTD 193,615.88 $ 0.50862 $ 98,476.78 $ 98,476.78 $ 98,755.72 $ 278.94
ENERGY CONSERVATION ADJUSTMENT tECA)
Monthly Cummulative
Budget Cost Center Total ECA Total ECA Overage YTD Overage ECA
Month Expenses Notes/Exceptional Items Expenses allied (Shortage) (Shortage) Rate
Prior Year $ 99,542.54 April 1, 1995 - Sept. 30, 1995 $ 99,542.54 $ - $ (99,542.54) $ (99,542.54)
Oct-95 $ 15,995.01 I $ 15,995.01 $ 17,231.81 $ 1,236.80 $ (98,305.74) 0,03
Nov-95 $ 26,460.44 I $ 26,460.44 $ 19,533.89 $ (6,926.55) $ (105,232.29) 0.03
Dec-95 $ 57,977.65 $45,000 for Morton Plant NC $ 57,977.65 $ 29,093.63 $ (28,884.02) $ (134,116,31) 0.03
Jan-96 $ 38,523,60 $ 38,523.60 $ 39,599.40 $ 1,075.80 $ (133,040,51) 0.03
Feb-96 $ 26,324.00 $ 26,324.00 $ 39,803.89 $ 13,479.89 $ (119,560,62) 0.03
Mar-96 $ 50,867,20 Heavy Allow month $ 50,867.20 $ 34,256.58 $ (16.610.62) $(136,171,24) 0.03
Apr-96 $ 34,725.65 $ 34,725,65 $ 42,412.02 $ 7,686.37 $ (128,484.87) 0.03
May-96 $ 26,000,00 $ 26,000.00 $ 32,130,00 $ 6,130.00 $ (122,354.87) 0.03
Jun-96 $ 26,000.00 $ 26,000.00 $ 29,490.00 $ 3,490.00 $ (118,864,87) 0.03
Jul-96 $ 25,000,00 $ 25,000,00 i $ 28,770.00 $ 3,770,00 $ (115,094,87) 0.03
Aug-96 $ 25,000.00 $ 25,000.00 I $ 26,850,00 $ 1,850.00 $ (113,244.87) 0.03
Sep-96 $ 25,000.00 $ 25,000.00 $ 27,570,00 $ 2,570.00 $ (110,674.87) 0,03
Total YTD $ 477,416,09 $ 477,416.09 $ 366,741,22 $ (110,674.87)
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ENVIRONMENTAL IMPOSITION ADJUSTMENT (EIA)
Monthly Cummulative
Budget Cost Center Total EIA Total EIA Overage YTD Overage EIA
Month Expenses Notes/Exceptional Items Expenses Billed (Shortage) (Shortage) Rate
Prior Year $ 121,435.63 Feb, 1, 1993 - Sept. 30, 1995 $ 121,435.63 $ - $ (121,435.63) $ (121,435.63)
Oct-95 $ 7,321,79 $ 7,321.79 $ 3,750,16 $ (3,571,63) $ (125,007.26) 0.005
Nov-95 $ 2,518.20 $ 2,518.20 $ 4,250.51 $ 1,732.31 $ (123,274.95) 0.005
Oec-95 $ 2,057,59 $ 2,057.59 $ 6,330.53 $ 4,272.94 $ (119,002.01) 0.005
Jan-96 $ 2,445.12 $ 2,445.12 $ 8,617.04 $ 6,171.92 $ (112,830.09) 0.005
Feb-96 $ 16,512,52 $ 16,512.52 $ 8,660.91 $ (7,851.61 ) $ (120,681.70) 0.005
Mar-96 $ - $ - $ 7,454.43 $ 7,454.43 $ (113,227.27) 0.005
Apr-96 $ 3,741.40 $ 3,741.40 $ 7,079,03 $ 3,337,63 $ (109,889.64) 0.005
May-96 $ 44,000.00 Berry Site Remediation (net cost) $ 44,000.00 $ 5,355.00 $ (38,645.00) $ (148,534.64) 0.005
Jun-96 $ 4,000,00 $ 4,000,00 $ 4,915.00 $ 915.00 $ (147,619.64) 0,005
Jul-96 $ 4,000.00 $ 4,000.00 $ 4,715.00 $ 715,00 $ (146,904,64) 0.005
Aug-96 $ 4,000,00 $ 4,000,00 $ 4,475.00 $ 475.00 $ (146,429.64) 0.005
Sep-96 $ 4,000.00 $ 4,000.00 $ 4,595,00 $ 595.00 $ (145,834.64) 0.005
Total YTO $ 216,032.25 $ 216,032.25 $ 70,197.61 $ (145,834,64)
TOTAL ALL COST RECOVERY ADJUSTMENT CLAUSES {Both PGAs + ECA + EIA)
Monthly Cummulative
Budget Total All Total Recovery Overage YTD Overage
Month Expenses Billed (Shortage) (Shortage)
Prior Year $ 220,978,17 $ - $ (220,978.17) $ (220,978.17)
Oct-95 $ 354,386.07 $ 318,118.55 $ (36,267.52) $ (257,245,69)
Nov-95 $ 433,362.46 $ 358,097.87 $ (75,264.59) $ (332,510.27)
Oec-95 $ 606,908.23 $ 510,391.96 $ (96,516,27) $ (429,026.54)
Jan-96 $ 744,545.97 $ 760,760.24 $ 16,214.27 $ (412,812.27)
Feb-96 $ 815,823.78 $ 789,650.46 $ (26,173.32) $ (438,985,59)
Mar-96 $ 681,994.39 $ 673,951.59 $ (8,042.80) $ (447,028.39)
Apr-96 $ 630,750.36 $ 647,412,62 $ 16,662.26 $ (430,366.13)
May-96 $ 487,922.24 $ 487,395.00 $ (527.24) $ (430,893.37)
Jun-96 $ 420,972.24 $ 445,885.00 $ 24,912.76 $ (405,980.61)
Jul-96 $ 407,600.00 $ 428,135.00 $ 20,535.00 $ (385,445.61)
Aug-96 $ 392,820.00 $ 404,375.00 $ 11,555.00 $ (373,890.61)
Sep-96 $ 400,090.00 $ 416,015.00 $ 15,925.00 $ (357,965.61)
Total YTO $ 6,598,153.90 $ 6,240,188,29 $ (357,965.61)
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CSW:6115/96 I . I I I ATTACHMENT #2
CLEARWATER GAS SYSTEM Page 1 of 2
SUMMARY OF RATE ADJUSTMENT CLAUSE COLLECTIONS
(At Proposed 07/01/98 Rates)
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NATURAL GAS PURCHASED GAS ADJUSTMENT (PGA-NG)
Monthly Cummulatfve
Budget Reservation Commodity Cost Center Total NG Fuel Total NG PGA Overage YTD Overage PGA
Month Charge. Charge. Expenses Expenses Billed (Shortage) (Shortage) Rate
Prior Year $ - $ - $ - $ - $ - $ - $ -
Oct-95 $ 123,043,58 $ 201,837.74 $ 1,649.40 $ 326,530.72 $ 292,679,84 $ (33,850.88) $ (33,850,88) 0.32/0.234
Nov-95 $ 169,542.26 $ 229,280.63 $ 953.99 $ 399,776.88 $ 328,780.15 $ (70,996.73) $ (104,847.61) 0.32/0,234
Dec-95 $ 178,384.56 $ 361,079.89 $ 672.68 $ 540,137.13 $ 466,281.94 $ (73,855.19) $ (178,702.80) 0.32/0.234
Jan-96 $ 174,798.92 $ 518,487.54 $ 713.36 $ 693,999.82 $ 705,130.51 $ 11,130.69 $ (167,572.11) 0.36/0.274
Feb-96 $ 160,615.00 $ 591,968.27 $ 10,804.17 $ 763,387.44 $ 731,966.41 $ (31,421.03) $ (198,993.14) 0.36/0,274
Mar-96 $ 169,019.00 $ 443,010.57 $ 8,864.28 $ 620,893.85 $ 623,157.53 $ 2,263.68 $ (196,729.46) 0,36/0.274
Apr-96 $ 163,759.00 $ 413,027.00 $ 4,316.94 $ 581,102.94 $ 586,757.36 $ 5,654.42 $ (191,075.04) 0,36/0.243
May-96 $ 80,000.00 $ 323,400.00 $ 6,000.00 $ 409,400.00 $ 441,270.00 $ 31,870.00 $ (159,205,04) 0.36/0,243
Jun-96 $ 80,000.00 $ 296,450,00 $ 6,000.00 $ 382,450.00 $ 402,840.00 $ 20,390.00 $ (138,815.04) 0,36/0.243
Jul-96 $ 80,000.00 $ 284,200.00 $ 6,000.00 $ 370,200.00 $ 420,810,00 $ 50,610.00 $ (88,205.04) 0.39/0.273
Aug-96 $ 80,000.00 $ 269,500.00 $ 6,000.00 $ 355,500.00 $ 397,410.00 $ 41,910.00 $ (46,295.04) 0.39/0.273
Sep-96 $ 80,000,00 $ 276,850.00 $ 6,000.00 $ 362,850.00 $ 409,110.00 $ 46,260.00 $ (35,04) 0,39/0,273
Total YTD $1,539,162.32 $ 4,209,091.64 $ 57,974.82 $ 5,806,228.78 $ 5,806,193.74 $ (35.04)
PROPANE ILP) GAS PURCHASED GAS ADJUSTMENT (PGA-LP)
Monthly Cummulative
Budget Gallons Monthly Commodity Total LP Fuel Total LP PGA Overage YTD Overage PGA
Month Sold WACOG Charges Expenses Billed (Shortage) (Shortage) Rate
Prior Year 0 $ - $ - $ - $ - $ - $ -
Oct-95 9,884.67 $ 0.45915 $ 4,538.55 $ 4,538.55 $ 4,456.74 $ (81.81 ) $ (81.81 ) 0.48/0.525
Nov-95 10,048.28 $ 0.45848 $ 4,606.94 $ 4,606.94 $ 5,533.32 $ 926.38 $ 844.58 0.48/0.525
Dec-95 14,736.72 $ 0.45708 $ 6,735.86 $ 6,735.86 $ 8,685.86 $ 1,950.00 $ 2,794.58 0.48/0.525
Jan-96 20,710.64 $ 0.46244 $ 9,577.43 $ 9,577.43 $ 7,413.29 $ (2,164.14) $ 630.44 0.48/0.525
Feb-96 19,241.97 $ 0.49890 $ 9,599.82 $ 9,599.82 $ 9,219.25 $ (380.57) $ 249.87 0.48/0.525
Mar-96 18,924.00 $ 0.54076 $ 10,233.34 $ 10,233.34 $ 9,083,05 $ (1,150.29) $ (900.42) 0.48/0.525
Apr-96 20,069,60 $ 0.55708 $ 11,180.37 $ 11,180.37 $ 11,164,21 $ (16.16) $ (916.58) 0.54/0.59
May-96 16,000.00 $ 0.53264 $ 8,522.24 $ 8,522.24 $ 8,640.00 $ 117.76 $ (798.82) 0.54/0.59
Jun-96 16,000.00 $ 0.53264 $ 8,522.24 $ 8,522.24 $ 8,640.00 $ 117.76 $ (681.06) 0.54/0.59
Jul-96 16,000.00 $ 0.52500 $ 8,400.00 $ 8,400.00 $ 8,640.00 $ 240.00 $ (441.06) 0.54/0.59
Aug-96 16,000.00 $ 0.52000 $ 8,320.00 $ 8,320.00 $ 8,640.00 $ 320.00 $ (121.06) 0,54/0.59
Sep-96 16,000.00 $ 0.51500 $ 8,240.00 $ 8,240.00 $ 8,640.00 $ 400.00 $ 278.94 0.54/0.59
Total YTD 193,615.88 $ 0.50862 $ 98,476.78 $ 98,476.78 $ 98,755.72 $ 278.94
ENERGY CONSERVATION ADJUSTMENT IECA)
I Monthly Cummulative
Budget Cost Center Total ECA Total ECA Overage YTD Overage ECA
Month Expenses Notes/Exceptional Items Expenses Billed (Shortage) (Shortage) Rate
Prior Year $ 99,542.54 April 1, 1995 - Sept. 30, 1995 $ 99,542.54 $ - $ (99,542.54) $ (99,542.54)
Oct-95 $ 15,995.01 I $ 15,995.01 $ 17,231.81 $ 1,236,80 $ (98,305,74) 0.03
Nov-95 $ 26,460.44 $ 26,460.44 $ 19,533.89 $ (6,926.55) $ (105,232.29) 0.03
Dec-95 $ 57,977.65 $45,000 for Morton Plant Ale $ 57,977.65 $ 29,093,63 $ (28,884.02) $ (134,116,31) 0.03
Jan-96 $ 38,523.60 $ 38,523.60 $ 39,599.40 $ 1,075.80 $ (133,040.51) 0,03
Feb-96 $ 26,324.00 $ 26,324.00 $ 39,803,89 $ 13,479.89 $ (119,560.62) 0.03
Mar-96 $ 50,867.20 Heavy Allow month $ 50,867.20 $ 34,256.58 $ (16,610.62) $(136,171.24) 0.03
Apr-96 $ 34,725.65 $ 34,725.65 $ 42,412,02 $ 7,686.37 $ (128,484.87) 0,03
May-96 $ 26,000.00 $ 26,000,00 $ 32,130,00 $ 6,130.00 $ (122,354,87) 0.03
Jun-96 $ 26,000,00 $ 26,000.00 $ 29,490.00 $ 3,490.00 $ (118,864.87) 0.03
Jul-96 $ 25,000.00 $ 25,000.00 $ 67,130,00 $ 42,130.00 $ (76,734,87) 0.07
Aug-96 $ 25,000,00 $ 25,000.00 $ 62,650.00 $ 37,650,00 $ (39,084,87) 0,07
Sep-96 $ 25,000.00 $ 25,000.00 $ 64,330.00 $ 39,330,00 $ 245.13 0.07
Total YTD $ 477,416,09 $ 477,416.09 $ 477,661.22 $ 245.13
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I '- I ATTACHMENT #2
I Paoe 2 of 2
ENVIRONMENTAL IMPOSITION ADJUSTMENT (EIA) I
1 Monthly CummulatJve
Budget Cost Center I Total EIA Total EIA Overage YTD Overage EIA
Month Expenses Notes/ExceptJonalltems Expenses Billed (Shortage) (Shortage) Rate
Prior Year $ 121,435,63 Feb, 1, 1993 - Sept. 30,1995 $ 121,435.63 $ - $ (121,435,63) $ (121,435.63)
Oct-95 $ 7,321.79 $ 7,321.79 $ 3,750.16 $ (3,571.63) $ (125,007.26) 0.005
Nov-95 $ 2,518.20 $ 2,518.20 $ 4,250.51 $ 1,732.31 $ (123,274.95) 0.005
Dec-95 $ 2,057.59 i$ 2,057,59 $ 6,330.53 $ 4,272.94 $ (119,002.01) 0.005
Jan-96 $ 2,445.12 1$ 2,445.12 $ 8,617.04 $ 6,171.92 $ (112,830.09) 0.005
Feb-96 $ 16,512.52 1$ 16,512.52 $ 8,660.91 $ (7,851.61 ) $ (120,681.70) 0.005
Mar-96 $ - !$ - $ 7,454.43 $ 7,454.43 $ (113,227.27) 0.005
Apr-96 $ 3,741.40 ,$ 3,741.40 $ 7,079.03 $ 3,337.63 $ (109,889.64) 0,005
May-96 $ 44,000.00 Berry Site Remediation (net cost) i $ 44,000.00 $ 5,355.00 $ (38,645.00) $ (148,534.64) 0,005
Jun-96 $ 4,000.00 $ 4,000.00 $ 4,915.00 $ 915.00 $ (147,619.64) 0.005
Jul-96 $ 4,000.00 $ 4,000.00 $ 9,430.00 $ 5,430.00 $ (142,189.64) 0.01
Aug-96 $ 4,000.00 1$ 4,000.00 $ 8,950.00 $ 4,950.00 $ (137,239.64) 0,01
Sep-96 $ 4,000.00 $ 4,000.00 $ 9,190,00 $ 5,190.00 $ (132,049.64) 0.01
Total YTD $ 216,032.25 $ 216,032.25 $ 83,982.61 $ (132,049,64)
TOTAL ALL COST RECOVERY ADJUSTMENT CLAUSES (Both PGAs + ECA + EIA)
I Monthly Cummulative
Budget ! Total All Total Recovery Overage YTD Overage
Month ; Expenses Billed (Shortage) (Shortage)
Prior Year 1$ 220,978.17 $ - $ (220,978.17) $ (220,978.17)
Oct-95 $ 354,386.07 $ 318,118.55 $ (36,267.52) $ (257,245.69)
Nov-95 $ 433,362.46 $ 358,097,87 $ (75,264.59) $ (332,510.27)
Dec-95 $ 606,908.23 $ 510,391.96 $ (96,516.27) $ (429,026.54)
Jan-96 $ 744,545.97 $ 760,760.24 $ 16,214.27 $ (412,812.27)
Feb-96 $ 815,823.78 $ 789,650.46 $ (26,173.32) $ (438,985.59)
Mar-96 $ 681,994.39 $ 673,951.59 $ (8,042.80) $ (447,028.39)
Apr-96 $ 630,750.36 $ 647,412.62 $ 16,662.26 $ (430,366.13)
May-96 $ 487,922.24 $ 487,395.00 $ (527.24) $ (430,893.37)
Jun-96 $ 420,972.24 $ 445,885.00 $ 24,912.76 $ (405,980.61)
Jul-96 $ 407,600.00 $ 506,010,00 $ 98,410.00 $ (307,570.61)
Aug-96 $ 392,820.00 $ 477,650.00 $ 84,830.00 $ (222,740.61)
Sep-96 $ 400,090.00 $ 491,270.00 $ 91,180.00 $(131,560.61)
Total YTD $ 6,598,153.90 $ 6,466,593.29 $ (131,560.61)
Page 2
U :chuck/windowslmsoffice\excel\gasrates\adjcalc2
CSW:06/15/96 CLEARWATER GAS SYSTEM ATTACHMENT '3
NATURAL GAS RATE BIWNG FACTORS
FOR THE PERIOD OF 07/01/96 - 09/30/96
Interr . ContnICI
Firm Natural Gas Rate Schedules Mi.BalI. miBIIlI
---BL J.G.L ~ ---LGL --BAk... ....GAC.-. ....LAC.... --.SL SL w/M& ~ ...N.S.S.- ---.1S.- ~
Bmjgb1
Applicable Annual Therm Range NA (1 - 0- 18,000- 100,000 NA (1 - NA (0- NA (150 NA NA NA NA 100,000 NA ,--
or Other Rate Determinant 3 Units) 17,999 99,999 & up 3 Units) 149 tons) ons & +) & up
Monthly Customer Charge $5.00 $15.00 $20.00 $50.00 $5.00 if $15.00 if $15.00 if $15.00 $15.00 $5 Resl.l $25.00 $100.00 By
not prey. not prey. not prey. $15 GS if Contract
Non-Fuel Energy CharoelTherm billed billed billed not prey.
billed
Non-Fuel Energy Charge $0.480 $0.430 $0.380 $0.330 $0.200 $0.150 $0.100 $0.200 $0.300 $0.100 $0.430 $0.260 By
Contract
Energy Conservation Adj. IECA) 0.070 0.070 0.070 0.070 0.070 0.070 0.070 0.070 0.070 0.070 0.070 NA NA
Environmental Imposition Adj. (EIA) 0.010 0.010 0.010 0.010 0.010 0.Q10 0.010 0.010 0.010 0.010 0.010 NA NA
Weather Normalization Adj. (WNA) Q.QQQ Q.QQQ Q.QQQ Q.QQQ Q.QQQ Q.QQQ Q.QQQ Q.QQQ Q.QQQ Q.QQQ Q.QQQ -HA -...&
Total Non-Fuel Energy Charge $0.560 $0.510 $0.460 $0.410 $0.280 $0.230 $0.180 $0.280 $0.380 $0.180 $0.510 $0.260 By
Contract
Purchased Gas Adjustment (PGAI ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Q...2.1.3. Q...2.1.3.
Total Energy ChargelTherm $0.950 $0.900 $0.850 $0.800 $0.670 $0.620 $0.570 $0.670 $0.770 $0.570 $0.900 $0.533 $0.273
+ Non-FueI
Minimum Monthly Bill $5.00 $15.00 $20.00 $50.00 $5.00 @ 15.oo@ 15.oo@ $15.00 $15.00 $ 5 ResU $25.00 $100.00 Customer -
premise premise premise + FAC + FAC $15 GS @ + FAC + Non-Fuel Charge +
premise Therm Rate for Non-Fuel Therm
+ FAC 250 therms X Rate for Contract
Utilitv Tax Note: # Days in Mo. # of Therms
Fuel Rate per Therm 10/01/73 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.055 $0.069
Non-Utility Taxable Fuel/Therm $0.321 $0.321 $0.321 $0.321 $0.321 $0.321 $0.321 $0.321 $0.321 $0.321 $0.321 $0.218 $0.204
BTU FACTOR = THERMS/100 CUBIC FEET ICCFI
.1.01a5 .1.1LH 1ZlS..li ~ QZLa.lI. Q.3lU ~ .ll.5Lti lW.ali .Q.Z.lU ~ ~
Firm Service Rates 1.063 1.067 1.065 1.067 1.072 1.071 1.070 1.068 1.070 1.069
IntFl""ptibllJ SA,vi"A RAtl)~ 1.043 1.046 1.044 1.046 1.061 1.060 1.049 1.047 1.049 1.048
CSW:06/15/96 ATTACHMENT #4
CLEARWATER GAS SYSTEM
BTU Factor: 2..1JA Gallons/l00 cubic feet (CCF) PROPANE (LP) RATE BILLING FACTORS
BTU Factor: ~ Therms/l00 cubic feet (CCF) FOR THE PERIOD OF 07/01/96 - 09/30/96
Therm Factor: Mli Therms/Gallon
Contract LP Svc. ,--
RLP GLP LLP LPV LPS CLP
Appl. Annual Gallon (Therm) Range NA o - 2,499 Gallons 2,500 Gallons & Up NA NA NA
or Other Rate Determinant (1 - 3 Units) (0-2,287 Therms) (2,288 Therms & Up)
Monthly Customer Charge $5.00 $15.00 $20.00 $5.00 Res/. or $25.00 Set By Contract
$15.00 GS if not
Non-Fuel Eneray CharQe: prevo billed @
premise
Non-Fuel Energy Charge /Gallon $0.650 $0.350 $0.290 $0.100 $0.350 By Contract
(NFE) /Therm $0.710 $0.383 $0.317 $0.109 $0.383 By Contr.
Energy Conservation Adj. /Gallon 0.064 0.064 0.064 0.064 0.064 NA
(ECA) /Therm 0.070 0.070 0.070 0.070 0.070 NA
Environm'l Imposition Adj. /Gallon 0.009 0.009 0.009 0.009 0.009 NA
(EIA) /Therm 0.010 0.010 0.010 0.010 0.010 NA
Weather Normalization Adj./Gallon Q.QQQ Q.QQQ Q.QQQ MOO MOO ---HA
(WNA) /Therm .Q.QQQ .Q.QQQ .Q.QQQ .Q.QQQ .Q.QQQ Nod
Total Non-Fuel Charge/Gallon $0.723 $0.423 $0.363 $0.173 $0.423 By Contract
ITherm $0.790 $0.463 $0.397 $0.189 $0.463 By Cntr.
Purchased Gas Adjustment/Gallon .M!Q .Q.HQ .M!Q .Q.HQ .M!Q .Q.HQ
(PGA) /Therm M9..Q M9..Q M9..Q M9..Q M9..Q ~
Total Energy Charges /Gallon $1.263 $0.963 $0.903 $0.713 $0.963 $0.540
/Therm $1.380 $1 .053 $0.987 $0.779 $1.053 + NF $0.590
+ NF
Minimum Monthly Bill $5.00 $15.00 $20.00 Any Applicable $25.00 Customer Charge +
Customer Charge Non-Fuel Energy Chg
+ Any Applicable for the Contracted
Note: Utiliy Tax is billed on total LP bill. Facility Charges # of Gallons/Mo.
I
I
TYPICAL RESIDENTIAL CUSTOMER
NATURAL GAS BILL
Based on an average monthly consumption of 25 therms projected as of 7/96
Clearwater Gas System (CGS)
Customer Charge
Therm Rate: 25 therms x 95.0C/therm
Peoples Gas System (pGS)
Customer Charge
Therm Rate: 25 therms x 82. 184C/therm
Difference in Typical Residential Billing
Clearwater Gas System
Peoples Gas System
Plus:
Gross Receipts Tax Increase
Utility Tax = typically about
Franchise Fees = typically about
Total TaxeslImpositions = about
Monthly CGS Bill
Monthly PGS Bill
CGS is higher by
% CGS Difference
2.564%
7.5%
~
15%
ATTACHMENT #5
$ 5.00
~
$ 28.75
$ 7.00
20.55
$27.55
$28.75
.l:L52
$1.20
+4.4%
CSW:6/15/96
CSW:06/15/96
I
I
ATTACHMENT #8
PRELIMINARY PURCHASED GAS ADJUSTMENT (PGA) CALCULATIONS
FOR THE BILLING PERIOD OF 10101/98.03/31/97
I. Preliminary Calculation of the Differential between the Natural Gas Firm Standard Rate Schedule PGA and the Natural
Gas Interruptible & Contract (Non-Standard) Rate Schedule PGA for the semi-annual period of 10/1/96 - 3/31/97
A. Reservation Charges for the Most Recent 12 Months Computed by UCS
3/95 - 9/95
10/95 - 2/96
Total
$674,237
$810.362
$1.484,599
B. Standard Rate Schedule Therm Usage for the Most Recent 12 Months Computed by UCS
2/95 - 1/96 Total Therm Usage
2/95 - 1/96 Non-Standard Usage
2/95 - 1/96 Standard Usage
16,030,288
(3.298.9351
12,731,353
100.0%
20.6%
79.4%
C. Preliminary Estimate of Differential Applicable for Interruptible & Contract Rate Schedules for 10/1196 -3/31197
A
C
$1.484.599
12,731,353
$0.117
II. Preliminary Calculation of the Required Natural Gas PGA WACOG for FY 96/97
Therm Sales Projection for 10/1/96 - 9/30/97 =
18,630,000
Budgeted NG Reservation Cost 10/1/96 - 9/30/97 =
Estimated NG Commodity Cost 10/1/96 - 9/30/97 =
Budgeted Other Supply Related Expenses =
Estimated 50% of Terry Neenan's Salary =
Total Annualized Recovery Needed for FY 96/97 =
$ 1,643,730.00
4,510,000.00 @ FY96/97 E/A cost of $0.242/therm
133,110.00
27.000.00
$ 6,313,840.00
Required Average Cost/therm to Recover =
$
0.339
78.0% Standard =
~ Non-Standard =
100.0%
14,531.400 Therms @
4.098.600 Therms @
18,630,000 Therms
$
$
WACOG
0.365
0.248
Recovery
$ 5,303,961
.L 1.018.053
$ 6,322,014
III. Preliminary Natural Gas PGA Estimate for 1011/96 - 3/31/97
A. Provide a $0.03 differential between winter & summer WACOG; therefore increase the above calculation
by $0.015 for the winter period.
B. Projected Required Standard Rate Schedule Winter PGA
$0.380
C. Less Projected Differential
($0.1171
D. Projected Required Non-Standard Rate Schedule Winter PGA
$0.263
III. Preliminary Propane (LP) Gas PGA Estimate for 10/1/96 - 3/31/97
A. Budget for LP Supply Cost for FY 96/97 =
$
120,000
B. Estimated LP Gallons to be Sold in FY 96/97 =
240.000
C. Projected Annualized LP WACOG for FY 96/97 =
$
0.500
D. Estimated Winter/Summer Differential in Required WACOG =
+ 1- $
0.020
E. Projected Required LP PGA for 10/1196 - 3/31197 =
$
0.520
i
I
CSW:06/15/96
ATTACHMENT #7
PRELIMINARY ENERGY CONSERVATION ADJUSTMENT (ECA) &
ENVIRONMENTAL IMPOSITION ADJUSTMENT (EIA) CALCULATIONS
FOR THE BILLING PERIOD OF 10/01/96 - 03/31/97
I. Calculation of the Energy Conservation Adjustment (ECA) Required for FY 96/97
Budgeted ECA Requirements for FY 96/97
$ 400,000
Projected Therm Sales for FY96/97 Applicable to ECA Recovery
(Natural Gas = 14,531,400 and LP = 219,600)
14,751,000
Computed ECA Recovery Factor Necessary
$
0.0271
Round to
$
0.030
II. Calculation of the Environmental Imposition Adjustment (ErA) Required for FY 96/97
Budgeted EIA Requirements for FY 96/97 $ 100,000
Projected FY 95/97 Underrecovery Balance 132,050
Total Projected EIA Recovery Requirements thru FY 96/97 $ 232,050
Projected Therm Sales for FY 96/97 Applicable to EIA 14,751,000
Times 3 Years Recovery Period K..3
Projected Therms for Recovery Timetable 44,253,000
Computed EIA Recovery Factor Necessary for FY 96/97 $ 0.00524
Round to Projected Current Recovery Level of $ 0.010
u:/chuck\excel\gasrates\eca_2h96.xls
CSW:06/15/96
ATTACHMENT #9
BTU Factor:
aTU Factor:
Therm Factor:
Gallons/1oo cubic feet (CCF)
Therms/1 00 cubic feet (CCF)
Therms/Gallon
CLEARWATER GAS SYSTEM
PROPANE (lP) RATE BilLING FACTORS
PRELIMINARY ESTIMATES FOR 10/01196 - 03/31/97 BASED ON NEW GAS RATES
2.1H
.2....4.8.3.
Q.Bli
....
RLP MLP GLP LLP LPV
Appl. Annual Gallon (Therm) Range NA NA o - 2.499 Gallons 2,500 Gallons & Up NA
or Other Rate Determinant (1 - 3 Units) (4 + Units) (0-2,287 Therms) (2,288 Therms & Up)
Monthly Customer Charge $6.00 $15.00 $15.00 $20.00 $6.00 Resl. or
$15.00 GS if not
Non-Fuel Enerov CharQe: prey. billed @
premise
Non-Fuel Energy Charge IGallon $0.700 $0.700 $0.390 $0.320 $0.100
ITherm $0.765 $0.765 $0.426 $0.350 $0.109
Energy Conservation Adj. IGallon 0.027 0.027 0.027 0.027 0.027
(ECA) ITherm 0.030 0.030 0.030 0.030 0.030
EnYironm'llmposition Adj. IGallon 0.009 0.009 0.009 0.009 0.009
(EIA) ITherm 0.010 0.010 0.010 0.010 0.010
Weather Normalization Adj./Gallon .Q..QQQ .Q..QQQ .Q..QQQ MOO MOO
(WNA) ITherm MOO Q.QQQ MOO MOO MOO
~otal Non-Fuel Charge/Gallon $0.736 $0.736 $0.426 $0.356 $0.136
fTherm $0.805 $0.805 $0.466 $0.390 $0.149
Purchased Gas AdjustmentlGallon Q&ZQ Q&ZQ Q&ZQ Q&ZQ Q&ZQ
(PGA) fTherm Q..5.2a Q..5.2a Q..5.2a Q..5.2a Q..5.2a
Total Energy Charges IGallon $1.256 $1 .256 $0.946 $0.876 $0.656
fTherm $1.373 $1.373 $1.034 $0.958 $0.717
Minimum Monthly Bill $6.00 $15.00 $15.00 $20.00 Any Applicable
Customer Charge
+ Any Applicable
Note: Utiliy Tax is billed on total LP bill. Facility Charges
LPS
Contract LP SYc.
CLP
NA
NA
$25.00
Set By Contract
$0.390 By Contract
$0.426 By Contr.
0.027 NA
0.030 NA
0.009 NA
0.010 NA
MOO ---.MA
MOO ---.MA
$0.426 By Contract
$0.466 By Cntr.
Q&ZQ Q&ZQ
Q..5.2a Q..5.2a
$0.946 $0.520
$1.034 + NF $0.568
+ NF
$25.00 Customer Charge +
Non-Fuel Energy Chg
for the Contracted
# of Gallons/Mo.
CSW:06/15/96 CLEARWATER GAS SYSTEM ATTACHMENT #8
NATURAL GAS RATE BILLING FACTORS
PRELIMINARY ESTIMATES FOR 10/01/98.03/31/97 BASED ON NEW GAS RATES WHICH BECOME EFFECTNE 10/01/98
Inte". Contract
Arm Naturel Ga. Rata Schedule. ~ ~
----8S.... ....sML ....MML ....I.ML ....s.G.S.... ~ ....L.liL ....BAk... ~ ..1Ak... -A... SL w/M& ...moc.. ~ ---1L.. ~
~ RIIilIIll
Applicable Annual Therm Range NA (1- NA (4 + NA (4 + NA (4 + O. 18,000- 100,000 NA(I. NAIO. NA (150 NA NA NA NA 100,000 NA
Of Other Rate DeterminalJt 3 Unitsl Unitsl Units) Unitsl 17,999 99.999 &up 3 Units) 149 tons) tons & +1 & up
Monthly Customer Charge $6.00 $15.00 $20.00 $50.00 $15.00 $20.00 $50.00 $6.00 if $15.00 if $15.00 if $15.00 $15.00 $6 Res!./ $25.00 $100.00 By
not p,ey. not prey. not prey. $15 GS if Contract
Non-Fuel er-av CharoeIThenn billed billed billed not prev.
billed
Non-Fuel Energy Charge $0.530 $0.530 $0.530 $0.530 $0.470 $0.410 $0.350 $0.200 $0.150 $0.100 $0.200 $0.300 $0.100 $0.470 $0.280 By
Cont,act
Energy Conservation Adj. (ECAI 0.030 0.030 0.030 0.030 0.030 0.030 0.030 0.030 0.030 0.030 0.030 0.030 0.030 0.030 NA NA
Environmental Imposition Adj. (EIA) 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 NA NA
Weather Normalization Adj. (WNA) QJlQQ Q..QQg QJlQQ Q..QQg QJlQQ QJlQQ QJlQQ QJlQQ QJlQQ QJlQQ QJlQQ QJlQQ QJlQQ QJlQQ ~ ~
Total Non-Fuel Energy Charge $0.570 $0.570 $0.570 $0.570 $0.510 $0.450 $0.390 $0.240 $0.190 $0.140 $0.240 $0.340 $0.140 $0.510 $0.280 By
Contract
I'IJrchased Gas Adjustment (PGA) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Q.2.6J Q.2.6J
Total Energy Charge/Therm $0.960 $0.950 $0.950 $0.950 $0.890 $0.830 $0.770 $0.820 $0.570 $0.520 $0.820 $0.720 $0.520 $0.890 $0.543 $0.283
+ Non-Fuel
Minimum Monthly llin $6.00 $15.00 $20.00 $50.00 $15.00 $20.00 $50.00 $6.00 @ $15.00 @ $15.00@ $15.00 $15.00 $6 Resl.! $25.00 $100.00 Custome,
premise premise premise + FAC + FAC $15 GS @ + FAC + Non.Fuel Cha'ge +
~ premise The,m Rate fa, Non-Fuel Therm
+ FAC 250 tt.e,ms X Rate fo, Cont,act
u.tY T.. Not.. # Days ilJ Mo. # of Therms
Fuel Rate per The,m 1 a/a 1/73 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.069 $0.055 $0.069
Non-Utility Taxable FuellTherm $0.311 $0.311 $0.311 $0.311 $0.311 $0.311 $0.311 $0.311 $0.311 $0.311 $0.311 $0.311 $0.311 $0.311 $0.208 $0.194
BTU FACTOR - THERMS/l00 CUBIC FEET ICCFI
1O.ll!l 1.1llUl .1.Zlti 21LU 2ZlU Q31ll .IMLB.Z ll.5lU Q6lll1 fll.1ll Q6lll1 MlU
Fi'm Service Rates
Interruptible Service Rates