Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
GAS ADJUSTMENTS EFFECTIVE OCTOBER 1, 1996
I I y~ CLEARWATER GAS SYSTEM Interoffice Correspondence Sheet TO: Betty Deptula, City Manager ;; FROM: Chuck Warrington, Gas System Managing Director 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 OCTOBER 1, 1996 DATE: August 21, 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 for the remainder of this year as well as FY 96/97 and recommend your approval of the following rates to become effective on October 1, 1996: Natural Gas Firm Standard Rate Schedule PGA ....... $0.380 per therm (down 1 (:) Natural Gas Interruptible and Contract (Non-Standard) Rate Schedule PGA ............. $0.267 per therm (down 0.6(:) Propane (LP) Gas Rate Schedule PGA .................... $0.530 per gallon (down 1 (:) = $0.579 per therm equivalent Energy Conservation Adjustment (ECA) ............... $0.040 per therm (down 3(:) = $0.037 per gallon of LP (down 2.7(:) Environmental Imposition Adjustment (EIA) ......... $0.010 per therm (no change) = $0.009 per Gallon of LP (no change) Weather Normalization Adjustment (WNA) .......... Not Applicable at this time . .-, I, '.. ~ / ,)...,' .0:" .; .... ',._ I"" f~. .. , .-, , / ~ () , I I I Betty Deptula, City Manager Page 2 August 21, 1996 We have reassessed our Rate Adjustment Clauses based on our current status as of the end of July 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 July is ($435,184.63) and our projections for fiscal year end is an underrecovery of ($324,307.87). Implementation of the above adjustment clauses are projected to bring this into balance for PGA and ECA by fiscal year end FY 96/97 and to reduce our deficit in EIA to a projected ($70,500) by fiscal year end FY 96/97. Please note that the EIA factor is designed to be recovered over a 2 - 5 year period. Betty, the gas commodity markets have remained much higher than we had hoped they would be. 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 Spring. Even with these conditions, we are able to reduce the impact of our Phase II Gas Rate Increase to 4.3% (or $1.25/month) for our typical residential customer due to the reduction of the adjustment clause levels for PGA and ECA below our current levels which became effective July 1, 1996. Attachment #4 shows that our proposed typical residential bill for 25 therms of consumption will be $30.00. Our residential customers would see the impact of the $1.00 increase in their Monthly Customer Charge, but the therm rate increase of 5C will be offset by a decrease in the Rate Adjustment Clauses of 4C (3C in ECA and 1 C in PGA). The following attachments document these recommended rates: Attachment #1: Is our Summary of Rate Adjustment Clause Calculations showing our projections of FY 95/96 year end results. Attachment #2: Shows our calculation of the required PGA billing factors for both natural and propane (LP) gas for FY 96/97. Attachment #3: Shows our calculations of the required ECA and EIA billing factors for both natural and propane (LP) gas for FY 96/97. I I Betty Deptula, City Manager Page 3 August 21, 1996 Attachment #4: Shows the calculation of the proposed typical residential bill as of 10/01/96 for 25 therms of monthly consumption. Attachment #5: Shows the resulting Natural Gas Rate Billing Factors proposed to become effective for 10/01/96 - 3/31/97 based on our Phase II Gas Rates and the recommended adjustments to PGA, ECA, and EIA. Attachment #6: Shows the resulting Propane (LP) Gas Rate Billing Factors proposed to become effective for 1 % 1/96 - 3/31/97 based on our Phase II Gas Rates and the recommended adjustments to PGA, ECA, and EIA. It is our plan to use the above proposed adjustments for billings through March 31, 1 997, unless there is a 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, make monthly projections of these factors based on market conditions, 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 our monthly indicators. Betty, I would appreciate your approval of these new adjustment clause rates so that we can finalize our bill inserts and training materials to implement our Phase II Gas Rates on October 1, 1 996. If you have any questions on this, please call me. CSW /cw Attachments '/~ - Approved: '.::r BeWDe Cia, -City Manager . CSW:8/20/~6 II I I ATTACHMENT #1 CLEARWATER GAS SYSTEM . Page 1 of 2 SUMMARY OF RATE ADJUSTMENT CLAUSE COLLECTIONS (Based on Eatlmates for August & September, 1996) I . NA ruRAL GAS PURCHASED GAS ADJUSTMENT fPGA-NG) Monthly Cummulative 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 $ 77,511.00 $ 371,578.00 $ 8,908.46 $ 457,997.46 $ 501,336.16 $ 43,338.70 $ (147,736.34) 0.36/0.243 Jun-96 $ 87,625.39 $ 316,179.68 $ 12,571.89 $ 416,376.96 $ 417,397.19 $ 1,020.23 $(146,716.11) 0.36/0.243 Jul-96 $ 86,438.92 $ 278,713.18 $ 4,806.08 $ 369,958.18 $ 363,359.74 $ (6,598.44) $ (153,314.55) 0.39/0.273 Aug-96 $ 87,250.00 $ 286,000.00 $ 10,000.00 $ 383,250.00 $ 395,070.00 $ 11,820.00 $ (141,494.55) 0.39/0.273 Sep-96 $ 84,200.00 $ 293,800.00 $ 10,000.00 $ 388,000.00 $ 406,770.00 $ 18,770.00 $ (122,724.55) 0.39/0.273 Total YTD $1,562,187.63 $ 4,304,962.50 $ 74,261.25 $ 5,941,411.38 $ 5,818,686.83 $ (122,724.55) PROPANE (LPl 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 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 17,462.70 $ 0.53264 $ 9,301.33 $ 9,301.33 $ 9,429.88 $ 128.55 $ (788.04) 0.54/0.59 Jun-96 15,174.30 $ 0.53264 $ 8,082.44 $ 8,082.44 $ 8,355.78 $ 273.34 $ (514.70) 0.54/0.59 Jul-96 11,724.70 $ 0.51768 $ 6,069.64 $ 6,069.64 $ 7,295.01 $ 1,225.37 $ 710.67 0.54/0.59 Aug-96 12,000.00 $ 0.50802 $ 6,096.24 $ 6,096.24 $ 6,480.00 $ 383.76 $ 1,094.43 0.54/0.59 Sep-96 13,000.00 $ 0.50500 $ 6,565.00 $ 6,565.00 $ 7,020.00 $ 455.00 $ 1,549.43 0.54/0.59 Total YTD 182,977.58 $ 0.50600 $ 92,586.96 $ 92,586.96 $ 94,136.39 $ 1,549.43 ENERGY CONSERVATION ADJUSTMENT fECAl I Monthly Cummulative Budget Cost Center I 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 $ 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 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 $ 34,315.84 $ (16,551.36) $(136,111.98) 0.03 Apr-96 $ 34,725.65 $ 34,725.65 $ 42,412.02 $ 7,686.37 $ (128,425.61) 0.03 May-96 $ 46,002.60 $ 46,002.60 $ 35,827.74 $ (10,174.86) $ (138,600.47) 0.03 Jun-96 $ 23,810.00 $ 23,810.00 $ 28,781.31 $ 4,971.31 $ (133,629.16) 0.03 Jul-96 $ 53,601.05 $ 53,601.05 $ 52,153.33 $ (1,447.72) $ (135,076.88) 0.07 Aug-96 $ 35,000.00 $ 35,000.00 $ 55,860.00 $ 20,860.00 $ (114,216.88) 0.07 Sep-96 $ 35,000.00 $ 35,000.00 $ 57,407.00 $ 22,407.00 $ (91,809.88) 0.07 Total YTD $ 543,829.74 $ 543,829.74 $ 452,019.86 $ (91,809.88) Page 1 U :chucklwindows Imsoffice\excellgasratesladjcalc2 . i~ II I ATIACHMENTt1 i I Page 2 of 2 ENVIRONMENTAL IMPOSITION ADJUSTMENT tElA) Monthly Cummulatlve Budget Cost Center Total EIA Total EIA Overage YTD Overage EIA Month Expenses Notes/Exceptional Items Expen.e. 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 i $ 2,057.59 $ 2,057.59 $ 6,330.53 $ 4,272.94 $(119,002.01) 0.005 Jan-96 i $ 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 $ - $ - $ 7,467.51 $ 7,467.51 $ (113,214.19) 0.005 Apr-96 $ 3,741.40 :$ 3,741.40 $ 7,079.03 $ 3,337.63 $ (109,876.56) 0.005 May-96 I $ 1,198.41 $ 1,198.41 $ 5,979.02 $ 4,780.61 $ (105,095.95) 0.005 Jun-96 I $ 27,620.00 Berry Site Remediation (1st) $ 27,620.00 $ 4,803.50 $ (22,816.50) $ (127,912.45) 0.005 Jul-96 1$ 27,041.00 Berry Site Remediation (2nd) $ 27,041.00 $ 7,449.58 $ (19,591.42) $ (147,503.87) 0.01 Aug-96 $ 10,000.00 Berry Site Remediation (3rd) $ 10,000.00 $ 7,980.00 $ (2,020.00) $ (149,523.87) 0.01 Sep-96 $ (30,000.00) Recovery of Ins. ($50K) + MGP $ (30,000.00) $ 8,201.00 $ 38,201.00 $ (111,322.87) 0.01 Total YTD $ 191,891.66 $ 191,891.66 $ 80,568.79 $ (111,322.87) TOTAL ALL COST RECOVERY ADJUSTMENT CLAUSES (Both PGAs + ECA + EIA) Monthly Cummulatlve 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) 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 $ 674,023.93 $ (7,970.46) $ (446,956.05) Apr-96 $ 630,750.36 $ 647,412.62 $ 16,662.26 $ (430,293.79) May-96 $ 514,499.80 $ 552,572.80 $ 38,073.00 $ (392,220.80) Jun-96 $ 475,889.40 $ 459,337.78 $ (16,551.62) $ (408,772.42) Jul-96 $ 456,669.87 $ 430,257.66 $ (26,412.21) $ (435,184.63) Aug-96 $ 434,346.24 $ 465,390.00 $ 31,043.76 $ (404,140.87) Sep-96 $ 399,565.00 $ 479,398.00 $ 79,833.00 $ (324,307.87) Total YTD $ 6,769,719.74 $ 6,445,411.87 $ (324,307.87) Page 2 U :chucklwindowslmsofflC8\excel\gasrates \adjcalc2 CSW:08/21 196 I I ATTACHMENT '2 Page 1 of 2 PURCHASED GAS ADJUSTMENT lPOA) CALCULATIONS FOR THE BILLING PERIOD OF 10101/98 - 03/31/97 I. Celculation of the Differentia' between the Natural Ges 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 Racent 12 Months (8/95 - 7196) = $1,543,178.53 (See Page 2 for Detail) B. Standard Rate Schedule Therm Usage for the Most Recent 12 Months (See Page 2 for Detail) 8/95 - 7/96 Total Therm Usage 8/95 - 7/96 Non-Standard Usage 8/95 - 7/96 Standard Usage 17,273,820 13.571.0631 13,702,757 100.0% 20.7% 79.3% C. PGA Billing Differential Applicable for Interruptible & Contract Rate Schedules for 10/1/96 -3131/97 A C $1.543.778.53 13,702,757 $0.113 II. Calculation of the Required Natural Gas PGA WACOG for FY 96/97 A. Therm Sales Projection for 10/1/96 - 9/30/97 = 18,630,000 B. Projected NG Reservation Cost 10/1/96 - 9/30/97 = Projected NG Commodity Cost 10/1/96 - 9/30/97 = Budgeted Other Supply Related Expenses = Estimated 40% of Terry Neenan's Salary = Total Recoyery Needed for FY 96/97 only = Projected (Oyer) Under Recoyery from FY 95/96 = Total Annualized Recoyery Needed for FY 96/97 = $ 1,600,000.00 4.400,000.00 128,640.00 22.000.00 $ 6,150,640.00 122.724.55 . 8,273,364.55 C. Required Weighted Ayerage Recoyery CostlTherm = $ 0.337 75.0% Standard = ~ Non-Standard = 100.0% 13,972,500 Therms @ 4.657.500 Therms @ 18,630,000 Therms $ $ WACOO 0.365 0.252 Recoyerv $ 5,099,963 $ 1.175.265 . 8,275,227 $ 5,731,222 $ 542.143 $ 8,273,365 D. Projected NG PGA Annual Reyenue = Pinellas NG PGA = Pasco NG PGA = Total NG PGA = III. Required Natural Gas PGA Billing Factors for 10/1/96 - 3/31/97 A. Proyide a $0.030 differential between winter & summer WACOG; therefore increase the aboye calculation by $0.015 for the Winter Billing Period B. Required Standard Rate PGA Billing Factor for the Winter Period $0.380 C. Less Non-Standard Differential for Reservation Cost 1 $0 1131 D. Required Non-Standard PGA Billing Factor for the Winter Period $0.267 III. Propane (LP) Gas PGA Estimate for 10/1/96 - 3/31/97 A. Projected LP Supply Cost for FY 96/97 = Projected (Oyer) Under Recoyery from FY 95/96 = Total Annualized Recoyery Needed during FY 96/97 = $ 126,620.00 $ 11.549.431 $ 125,070.57 240.000 $ 0.521 $ 0.530 B. Projected LP Gallons to be Sold in FY 96/97 = C. Required Annualized LP WACOG for FY 96/97 = D. Round Proposed LP PGA Recoyery Rate to E. Projected LP PGA Annual Reyenue = Pinellas LP PGA = Pasco LP PGA = Total LP PGA = $ 95.400.00 31.800.00 $ 127,200.00 u:Jchuck\excel\gaarlt8s\pga _1 h97 .xl. ATTACHMENT 12 Page 2 of 2 CLEARWATER GAS SYSTEM ANALYSIS OF STANDARD VS. NON-STANDARD THERMS & RESERVATION CHARGES FOR 8/1195. 7/31/96 - Subtotal Subtotal Net Net Charge Per Billing Total Interruptible % Contract % Non-Standard % Non- Standard % Reservation Standard M2nth Ih.twnI Ih.twnI InterruDtible IIwml Contract IIwml Standard Ih.twnI Standard ~ lhIIIn Aug 1995 1,097,612 217,381 19.8% 26,521 2.4% 243,902 22.2% 853,710 17 .8% $ 62.226.28 $ 0.073 Sep 1995 1,064,081 228,368 21.5% 23,623 2.2% 251,991 23.7% 812,090 76.3% $ 90,814.62 $ 0.112 Oct 1 995 985.485 221.255 22.5% 23,674 2.4% 244,929 24.9% 740,556 75.1% $ 123,043.58 $ 0.166 Nay 1 995 1,097,755 234,135 21.3% 22,727 2.1 % 256,862 23.4% 840,893 76.6% $ 169,542.26 $ 0.202 Dec 1995 1,534,189 249,200 16.2% 32,300 2.1% 281,500 18.3% 1,252,689 81.7% $ 178,384.56 $ 0.142 Jan 1996 2,036,285 272.486 13.4% 59,916 2.9% 332,402 16.3% 1,703,883 83.7% $ 174,798.92 $ 0.103 Feb 1996 2.119,870 308,624 14.6% 53,913 2.5% 362,537 17.1% 1,757,333 82.9% $ 160,615.00 $ 0.091 Mar 1996 1,811,600 288,558 15.9% 46,908 2.6% 335.466 18.5% 1.476,134 81.5% $ 169,019.00 $ 0.115 Apr 1996 1,742,874 297.899 17.1% 47.489 2.7% 345,388 19.8% 1,397.486 80.2% $ 163,759.00 $ 0.117 May 1996 1.496,388 274,839 18.4% 41,243 2.8% 316,082 21.1% 1,180.306 78.9% $ 17,511.00 $ 0.066 Jun 1996 1.263,385 258,270 20.4% 56,680 4.5% 314,950 24.9% 948.435 75.1% $ 87,625.39 $ 0.092 Jul 1996 1,024,296 239,811 23.4% 45,243 4.4% 285,054 27.8% 739,242 72.2% $ 86.438.92 $ 0.117 Total 8/95-7/96 17,273,820 3,090,826 17.9% 480,237 2.8% 3,571,063 20.7% 13,702.757 79.3% $ 1,543,778.53 . 0.113- For ComDarison 2/95 - 1/96 16,030,288 2,949.686 18.4% 372,830 2.3% 3.322,516 20.7% 12.707.172 79.3% $ 1,396,068.60 $ 0.110 Change 1,243,532 141,140 -0.5% 107.407 0.5% 248,547 NC 994,985 NC $ 147,709.93 . 0.003 I I CSW:08/20/96 ATTACHMENT #3 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 only = Projected (Over) Under Recovery of ECA from FY 95/96 = Total Annualized ECA Recovery Needed during FY 96/97 = $ 400,000.00 91,809 88 $ 491,809.88 Projected Therm Sales for FY96/97 Applicable to ECA Recovery = (Natural Gas @ 75% Standard = 13,972,500 and LP @ 50% Standard = 109,800 or 14,082,300 Total Applicable Therms) 14,082,300 Computed ECA Recovery Factor Necessary = $ 0.0349 Round Proposed ECA Recovery Rate to $ 0.040 Annual ECA Revenue Projection @ Proposed Recovery Rate = $ 563,292.00 II. Calculation of the Environmental Imposition Adjustment (EIA) Required for FY 96/97 Budgeted EIA Requirements for FY 96/97 only = Projected (Over) Under Recovery of EIA from FY 95/96 = Total Annualized EIA Recovery Needed during FY 96/97 = $ 100,000.00 111,32287 $ 211,322.87 Projected Therm Sales for FY 96/97 Applicable to EIA = 14,082,300 Times 2 Years Recovery Period x.2 Projected Therms for Recovery Timetable = 28,164,600 Computed EIA Recovery Factor Necessary for FY 96/97 = $ 0.00750 Round Proposed EIA Recovery Rate to $ 0.010 Annual ECA Revenue Projection @ Proposed Recovery Rate = $ 140,823.00 u:/chuck\excel\gasrates\eca_1 h97 .xls I I ATTACHMENT #4 CLEARWATER GAS SYSTEM TYPICAL RESIDENTIAL CUSTOMER BILL Based on an average monthly consumption of 25 therDlS in October, 1996: Customer Charge $ 6.00 Non-Fuel Energy Charges @ 58t 1 therm 14.50 Purchased Gas Charges @ 38t 1 therm ~ Monthly CGS Bill $30.00* Plus: State Gross Receipts Tax Municipal Utility Tax - typically about Municipal Franchise Fees - typically about 2.564 % 7.5 % 5 % Total TaxeslImpositions - about 15 % *For an equivalent amount of energy this compares to $61.35 $39 - $47 $25 - $30 for Electric Service or 105 % more for Propane (LP) Gas Service or 40-70% more for Fuel Oil Service or about the same CSW: 8/21/96 CSW:08/21 196 Applicabla AlJnual Tharm Range or Other Rate Determinant Monthly Customar Cha,ga Non.Fuel En.ray Ch...a.lTh.rm NOIJ-Fua' ElJorgy Charga Energy Conservation Adj. (ECAI Environment.' Imposition Adj. (EIA) Weather No,malizatlolJ Adj. (WNAI Total Non-Fual Energy Charge Purchased Gas Adjustment (PGAI Total Energy ChargeITherm MilJimum Monthly 8i11 Compara. to LP/G.non R.t. 01 with 8.0% FralJchila Change Irom 9/96 Therm Rete Utility Tax Note" Fuel Rate per Therm 10101173 Non-Utility Taxable Fuel/The,m ---8&.... ....IML JMdL -LML NA (1 - NA (4 + NA (4 + NA (4 + 3 UlJitsl UlJltsl Unltsl Unltsl $6.00 $15.00 $20.00 $60.00 $0.530 $0.530 $0.530 $0.530 0.040 0.040 0.040 0.040 0.010 0.010 0.010 0.010 Q.QQQ Q.QQQ Q.lllXI Q.lllXI $0.580 $0.680 $0.580 $0.580 lU8Q lU8Q lU8Q lU8Q $0.980 $0.960 $0.960 $0.960 $6.00 $15.00 $20.00 $50.00 0.878 $ 0.878 $ 0.1178 $ 0.878 0.931 $ 0.931 $ 0.931 $ 0.931 $ 0.010 $ 0.060 $ 0.110 $ 0.160 $ $0.069 $0.069 $0.069 $0.069 $0.311 $0.311 $0.311 $0.311 Bl\I FACTOR - THERMS/l00 CU81C FEET ICCFI Firm Service Rates Interruptible Service Rates 1M2 .1.1lH CLEARWATER GAS SYSTEM NATURAL GAS RATE BILLING FACTORS FOR 10/01196 - 03131197 BASED ON NEW GAS RATES I. ADJUSTMENT FACTORS Firm Natura. 0.. A_t. Schedul.. ...HL. ....IMlL ....LliL ~ .JJAC.... $15.00 0- 18,000- 17,999 99,999 $20.00 $0.470 $0.520 $0.900 $15.00 $0.410 0.040 0.040 100,000 .. up $60.00 $0.360 $0.400 $0.780 $60.00 NA(I- 3 Unltsl $8.0011 not prev. billed $0.200 0.040 0.010 Q.lllXI Q.lllXI NA (0. NA (150 149 tonsl tons" + I ~ $15.00 il not prev. billed $0.150 0.040 0.040 0.010 0.010 $0.069 $0.311 $0.250 lU8Q ll.3.m 0.010 0.010 $15.00 II not prev. billed $0.100 0.040 0.010 Q.lllXI $0.150 lU8Q $6.00 @ $15.00 @ $15.00 @ premise premise premise $0.530 $0.069 $0.311 lMLlZ .....IL SL w/MI. BtUgJn NA NA $15.00 $0.200 0.040 0.010 Q.lllXI $0.250 ll.3.m $0.630 $15.00 + FAC 0.485 $ 0.578 0.514 $ 0.611 ...1il1L NA $15.00 $6 Re.'./ $15 as II not prev. billed $0.300 $0.100 $0.350 $0.730 $15.00 + FAC $0.069 $0.311 0.040 0.040 0.010 0.010 $25.00 + FAC $ 10.0101 $ 10.0201 $ 10.0401 $ 10.0401 $ 10.0401 $ (0.0401 $ 10.040) $ (0.0401 $ Ima". lm.Ba1I ...NIL ---'L.. NA 100,000 .. up $25.00 $100.00 NA NA ATTACHMENT '5 Contt_ ~ ~ -, NA By Contract By Contract NA NA --.lfA By Contr_ lUU $0.267 + Non-fual Cuatomer Charge + Non-Fuel Theon Rate tor Contract , 01 Thermo -, $ 10.006) $0.069 $0.198 1ZlH lUllU Q.lllXI Q.lllXI $0.630 Q.lllXI $0.200 ll.3.m $0.580 0.824 $ 0.769 $ 0.714 $ 0.576 $ 0.531 0.873 $ 0.815 $ 0.757 $ 0.611 $ 0.563 $0.069 $0.311 $0.460 ll.3.m ll.3.m $0.840 $20.00 $0.069 $0.311 2ZllI2 Q3LI2 $0.069 $0.311 ll51IZ $0.069 $0.311 ~ fl1lJ1 $0.069 $0.311 lll!lSZ Q.lllXI Q.lllXI $0.150 ll.3.m ll.3.m $0.530 $6 Re.1.I $15 as C!l preml.e ~ FAC 0.6S8 $ 0.4811 0.708 $ 0.514 $0.069 $0.311 ~ $0.470 $0.280 0.040 0.010 Q.lllXI --.lfA $0.520 $0.280 lU8Q Q.ZU $0.900 $0.547 $100.00 + Non-Fuel Therm Rill 'or 250 thermo X , Oays IIJ Mo. 0.824 $ 0.501 0.873 $ 0.531 $ 0.014 $0.069 $0.055 $0.311 $0.212 '~ CSW:08/21 196 ATTACHMENT #6 CLEARWATER GAS SYSTEM BTU Factor: .2....l.1.! Gallons/100 cubic feet lCCF) PROPANE (LP) RATE BILLING FACTORS BTU Factor: .2..!8.3. Therms/100 cubic feet (CCF) FOR 10101196 - 03/31/97 BASED ON NEW GAS RATES & ADJUSTMENT FACTORS Therm Factor: ~ Therms/Gallon Contract LP Syc. - RLP MLP GLP LLP LPV LPS CLP Appl. Annual Gallon (Therm) Range NA NA o - 2.499 Gallons 2,500 Gallons & Up NA NA NA or Other Rate Determinant (1 - 3 Units) 14 + Units) (0-2,287 Thermsl (2,288 Therms & Up) Monthly Customer Charge $6.00 $15.00 $15.00 $20.00 $6.00 Res!. or $25.00 Set By Contract $15.00 GS if not Non-Fuel Energy CharGe: prey. billed @ premise Non-Fuel Energy Charge IGallon $0.700 $0.700 $0.390 $0.320 $0.100 $0.390 By Contract /Therm $0.765 $0.765 $0.426 $0.350 $0.109 $0.426 By Contr. Energy Conservation Adj. IGallon 0.037 0.037 0.037 0.037 0.037 0.037 NA (ECA) /Therm 0.040 0.040 0.040 0.040 0.040 0.040 NA Enyironm'l Imposition Adj. IGallon 0.009 0.009 0.009 0.009 0.009 0.009 NA (EIA) /Therm 0.010 0.010 0.010 0.010 0.010 0.010 NA Weather Normalization Adj./Gallon Q...QQQ Q...QQQ Q.QQQ Q.QQQ Q.QQQ Q...QQQ ----1lA lWNA) /Therm Q...QQQ Q...QQQ Q.QQQ Q...QQQ Q...QQQ Q...QQQ ---1iA Total Non-Fuel ChargelGellon $0.746 $0.746 $0.436 $0.366 $0.146 $0.436 By Contract ITharm $0.815 $0.815 $0.476 $0.400 $0.159 $0.476 By Cntr. - Purchased Gas Adjustment/Gallon 2..5.3.Q 2..5.3.Q 2..5.3.Q 2..5.3.Q 2..5.3.Q 2..5.3.Q 2..5.3.Q (PGA) /Therm ~ ~ ~ ~ ~ ~ ~ Total Energy Charges /Gallon $1.276 $1.276 $0.966 $0.896 $0.676 $0.966 $0.530 ITherm $1.394 $1.394 $1.055 $0.979 $0.738 $1 .055 + NF $0.579 + NF Minimum Monthly Bill $6.00 $15.00 $15.00 $20.00 Any Applicable $25.00 Customer Charge + Customer Charge Non-Fuel Energy Chg. + Any Applicable for the Contracted Facility Charges , of Gallons/Mo. Change from 9/96 /Gallon Rate $ 0.013 $ 0.313 $ 0.003 $ (0.0071 $ (0.0371 $ 0.003 $ (0.0101 ITherm Rate $ 0.014 $ 0.341 $ 0.002 $ (0.008) $ (0.0411 $ 0.002 $ (0.0111 Note: Utiliy Tax is billed on total LP bill.