electric utility 's total margin represents total revenues less total cost of sales and electric utility gross receipts taxes , of $ 4.8 million and $ 5.6 million during fiscal 2016 and fiscal 2015 , respectively . gross receipt taxes are included in taxes other than income taxes on the consolidated statements of income . ( b ) deviation from average heating degree days for the 15-year period 2000-2014 based upon weather statistics provided by the national oceanic and atmospheric administration ( “ noaa ” ) for airports located within gas utility 's service territory . ( c ) amounts exclude png gas ' heating , ventilation and air-conditioning service business sold in june 2015 ( see note 16 to consolidated financial statements ) . temperatures in gas utility 's service territory during fiscal 2016 based upon heating degree days were 13.6 % warmer than normal and 17.8 % warmer than fiscal 2015. in particular , gas utility temperatures in the critical heating-season month of december were 37 % warmer than normal . gas utility core market volumes declined 15.1 bcf ( 18.6 % ) reflecting the effects of the significantly warmer weather . total gas utility fiscal 2016 distribution system throughput was about equal to fiscal 2015 as the lower core market volumes were substantially offset by higher large firm delivery service volumes . gas utility 's core market customers comprise firm- residential , commercial and industrial ( “ retail core-market ” ) customers who purchase their gas from gas utility and , to a much lesser extent , residential and small commercial customers who purchase their gas from others . electric utility kilowatt-hour sales were 4.8 % lower than in the prior year principally reflecting the impact of the warmer weather on heating-related sales . ugi utilities revenues decreased $ 273.1 million principally reflecting a $ 255.7 million decrease in gas utility revenues and a $ 16.5 million decrease in electric utility revenues . the lower gas utility revenues principally reflect a decrease in core market revenues ( $ 203.1 million ) and lower off-system sales revenues ( $ 51.4 million ) . the $ 203.1 million decrease in fiscal 2016 gas utility core market revenues reflects the effects of the lower core market throughput ( $ 135.4 million ) and lower average pgc rates ( $ 67.7 million ) . the lower electric utility revenues principally resulted from lower ds rates ( $ 8.0 million ) , lower sales 15 volumes ( $ 5.4 million ) and lower transmission revenue ( $ 2.6 million ) . because gas utility and electric utility are subject to reconcilable pgc and ds recovery mechanisms , increases or decreases in the actual cost of gas or electricity associated with customers who purchase their gas or electricity from ugi utilities impact revenues and cost of sales but have no direct effect on retail core-market margin ( see note 4 to consolidated financial statements for a discussion of these recovery mechanisms ) . ugi utilities cost of sales was $ 289.8 million in fiscal 2016 compared with $ 510.8 million in fiscal 2015 principally reflecting the combined effects of the lower average gas utility pgc rates ( $ 92.3 million ) , lower cost of sales associated with gas utility off-system sales ( $ 51.4 million ) and lower gas utility retail core-market volumes sold ( $ 67.5 million ) . electric utility cost of sales was $ 11.5 million lower reflecting lower ds rates ( $ 8.5 million ) and the lower volumes sold . ugi utilities fiscal 2016 total margin decreased $ 51.3 million principally reflecting lower gas utility total margin from core market customers ( $ 43.3 million ) . the decrease in gas utility core market margin reflects the lower core market throughput . electric utility total margin decreased $ 4.2 million principally reflecting the lower volume sales as a result of the warmer fiscal 2016 weather and the lower transmission revenue . ugi utilities operating income and income before income taxes decreased $ 40.8 million and $ 37.3 million , respectively . the decreases in operating income and income before income taxes principally reflects the decrease in total margin ( $ 51.3 million ) , higher depreciation expense ( $ 4.4 million ) and lower other operating income ( $ 10.9 million ) which includes , among other things , higher environmental matters expense ( $ 4.1 million ) , lower margin from off-system sales ( $ 2.2 million ) , lower revenue from construction services ( $ 2.1 million ) and higher interest on pgc overcollections ( $ 1.1 million ) . these were partially offset by operating and administrative expenses that were $ 25.6 million lower than the prior year primarily reflecting lower net preliminary development stage expenses associated with an information technology ( “ it ” ) project ( $ 8.6 million ) , including the year-over-year impact of the current year capitalization of $ 5.4 million of such it costs expensed in prior years ( see note 4 to consolidated financial statements ) , and , to a lesser extent , lower uncollectible accounts ( $ 5.7 million ) , system maintenance expenses ( $ 4.8 million ) and employee benefits ( $ 4.7 million ) . interest expense and income taxes . our interest expense in fiscal 2016 was $ 3.5 million lower than in fiscal 2015 principally reflecting ugi utilities ' lower average long-term debt outstanding and lower average interest rates . our effective income tax rate in fiscal 2016 was slightly higher than in the prior year . fiscal 2015 compared with fiscal 2014 replace_table_token_1_th ( a ) gas utility 's total margin represents total revenues less total cost of sales . electric utility 's total margin represents total revenues less total cost of sales and electric utility gross receipts taxes , of $ 5.6 million and $ 5.8 million during fiscal 2015 and fiscal 2014 , respectively . story_separator_special_tag ugi utilities also transferred certain associated storage inventories upon the commencement of the scaas , receives a transfer of storage inventories at the end of the scaas , and makes payments associated with refilling storage inventories during the term of the scaas . energy services , in turn , provides a firm delivery service and makes certain payments to ugi utilities for its various obligations under the scaas . during fiscal 2016 , fiscal 2015 and fiscal 2014 , these payments were not material . ugi utilities incurred costs associated with energy services ' scaas totaling $ 12.7 million , $ 16.8 million and $ 38.3 million in fiscal 2016 , fiscal 2015 and fiscal 2014 , respectively . in conjunction with the scaas , ugi utilities received security deposits from energy services . the amounts of such security deposits , which are included in other current liabilities on the consolidated balance sheets , were $ 8.1 million and $ 10.7 million at september 30 , 2016 and 2015 , respectively . ugi utilities reflects the historical cost of the gas storage inventories and any exchange receivable from energy services ( representing amounts of natural gas inventories used but not yet replenished by energy services ) on its balance sheet under the caption inventories . the carrying values of these gas storage inventories at september 30 , 2016 and 2015 , comprising approximately 4.6 bcf and 5.0 bcf of natural gas , were $ 11.1 million and $ 12.9 million , respectively . ugi utilities has gas supply and delivery service agreements with energy services pursuant to which energy services provides certain gas supply and related delivery service to gas utility primarily during the heating season months of november through march . the aggregate amount of these transactions ( exclusive of transactions pursuant to the scaas ) during fiscal 2016 , fiscal 2015 and fiscal 2014 totaled $ 63.3 million , $ 47.8 million and $ 35.8 million , respectively . 21 from time to time , the company sells natural gas or pipeline capacity to energy services . during fiscal 2016 , fiscal 2015 and fiscal 2014 , revenues associated with sales to energy services totaled $ 30.7 million , $ 79.2 million and $ 109.9 million , respectively . also from time to time , the company purchases natural gas , pipeline capacity and electricity from energy services ( in addition to those transactions already described above ) and purchases a firm storage service from ugi storage company , a subsidiary of energy services , under one-year agreements . during fiscal 2016 , fiscal 2015 and fiscal 2014 , such purchases totaled $ 35.1 million , $ 85.4 million and $ 128.1 million , respectively . off-balance-sheet arrangements we do not have any off-balance-sheet arrangements that are expected to have an effect on the company 's financial condition , revenues and expenses , results of operations , liquidity , capital expenditures or capital resources . market risk disclosures our primary market risk exposures are ( 1 ) commodity price risk and ( 2 ) interest rate risk . although we use derivative financial and commodity instruments to reduce market price risk associated with forecasted transactions , we do not use derivative financial and commodity instruments for speculative or trading purposes . commodity price risk gas utility 's tariffs contain clauses that permit recovery of all of the prudently incurred costs of natural gas it sells to its retail core-market customers , including the cost of financial instruments used to hedge purchased gas costs . the recovery clauses provide for periodic adjustments for the difference between the total amounts actually collected from customers through pgc rates and the recoverable costs incurred . because of this ratemaking mechanism , there is limited commodity price risk associated with our gas utility operations . gas utility uses derivative financial instruments including natural gas futures and option contracts traded on the new york mercantile exchange ( “ nymex ” ) to reduce volatility in the cost of gas it purchases for its retail core-market customers . the cost of these derivative financial instruments , net of any associated gains or losses , is included in gas utility 's pgc recovery mechanism . the change in market value of natural gas futures contracts can require daily deposits of cash in futures accounts . at september 30 , 2016 and 2015 , gas utility had $ 0.6 million and $ 6.6 million of restricted cash in brokerage accounts , respectively . at september 30 , 2016 and 2015 , the fair values of our natural gas futures and option contracts were gains and ( losses ) of $ 4.3 million and $ ( 3.3 ) million , respectively . electric utility 's ds tariffs contain clauses which permit recovery of all prudently incurred power costs , including the cost of financial instruments used to hedge electricity costs , through the application of ds rates . because of this ratemaking mechanism , there is limited power cost risk , including the cost of financial transmission rights ( “ ftrs ” ) and forward electricity purchase contracts , associated with our electric utility operations . at september 30 , 2016 , all of our electric utility 's forward electricity purchase contracts were subject to the normal purchase and normal sale ( “ npns ” ) exception . in addition , gas utility and electric utility from time to time enter into exchange-traded gasoline futures contracts for a portion of gasoline volumes expected to be used in their operations . these gasoline futures contracts are recorded at fair value with changes in fair value reflected in operating expenses and other income . the amount of unrealized gains on these contracts and associated volumes under contract at september 30 , 2016 and 2015 , were not material . interest rate risk we have both fixed-rate debt and variable rate debt . changes in interest rates impact the cash flows

capitalization and liquidity ugi utilities ' total debt outstanding was $ 783.9 million at september 30 , 2016 , which includes $ 112.5 million of short-term borrowings , compared with total debt outstanding of $ 691.5 million at september 30 , 2015 , which includes $ 71.7 million of short-term borrowings . ugi utilities ' total long-term debt outstanding at september 30 , 2016 , comprises $ 575.0 million of senior notes and $ 100.0 million of medium-term notes , and is net of $ 3.6 million of unamortized debt issuance costs . in april 2016 , ugi utilities entered into a note purchase agreement ( the “ 2016 note purchase agreement ” ) with a consortium of lenders . pursuant to the 2016 note purchase agreement , ugi utilities issued $ 100 million aggregate principal amount of 2.95 % senior notes due june 2026 and $ 200 million aggregate principal amount of 4.12 % senior notes due september 2046 in june 2016 and september 2016 , respectively . in october 2016 , ugi utilities issued $ 100 million aggregate principal amount of 4.12 % senior notes due in october 2046. the net proceeds of the issuance of these senior notes were used 1 ) to repay ugi utilities ' maturing 5.75 % senior notes , 7.37 % medium-term notes and 5.64 % medium-term notes ; 2 ) to provide additional financing for ugi utilities ' infrastructure replacement and betterment capital program and information technology initiatives ; and 3 ) for general corporate purposes . 17 ugi utilities has a credit agreement ( the “ credit agreement ” ) with a group of banks providing for borrowings of up to $ 300 million ( including a $ 100 million sublimit for letters of credit ) which expires in march 2020. borrowings under the credit agreement are classified as short-term borrowings on the consolidated balance sheets . during fiscal 2016 and fiscal 2015 , average daily short-term borrowings under the credit agreement were $ 150.8 million and $ 61.7 million , respectively , and peak short-term borrowings totaled $ 232.0 million and $ 163.6 million , respectively .


 Write a concise suspicious activity report of the following text delimited by triple backquotes. Return your response as a formal report which covers the key points highlighting the location,dates,entity names and account holder information in chronological order of the text.
     ```capitalization and liquidity ugi utilities ' total debt outstanding was $ 783.9 million at september 30 , 2016 , which includes $ 112.5 million of short-term borrowings , compared with total debt outstanding of $ 691.5 million at september 30 , 2015 , which includes $ 71.7 million of short-term borrowings . ugi utilities ' total long-term debt outstanding at september 30 , 2016 , comprises $ 575.0 million of senior notes and $ 100.0 million of medium-term notes , and is net of $ 3.6 million of unamortized debt issuance costs . in april 2016 , ugi utilities entered into a note purchase agreement ( the “ 2016 note purchase agreement ” ) with a consortium of lenders . pursuant to the 2016 note purchase agreement , ugi utilities issued $ 100 million aggregate principal amount of 2.95 % senior notes due june 2026 and $ 200 million aggregate principal amount of 4.12 % senior notes due september 2046 in june 2016 and september 2016 , respectively . in october 2016 , ugi utilities issued $ 100 million aggregate principal amount of 4.12 % senior notes due in october 2046. the net proceeds of the issuance of these senior notes were used 1 ) to repay ugi utilities ' maturing 5.75 % senior notes , 7.37 % medium-term notes and 5.64 % medium-term notes ; 2 ) to provide additional financing for ugi utilities ' infrastructure replacement and betterment capital program and information technology initiatives ; and 3 ) for general corporate purposes . 17 ugi utilities has a credit agreement ( the “ credit agreement ” ) with a group of banks providing for borrowings of up to $ 300 million ( including a $ 100 million sublimit for letters of credit ) which expires in march 2020. borrowings under the credit agreement are classified as short-term borrowings on the consolidated balance sheets . during fiscal 2016 and fiscal 2015 , average daily short-term borrowings under the credit agreement were $ 150.8 million and $ 61.7 million , respectively , and peak short-term borrowings totaled $ 232.0 million and $ 163.6 million , respectively .
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 Suspicious Activity Report : electric utility 's total margin represents total revenues less total cost of sales and electric utility gross receipts taxes , of $ 4.8 million and $ 5.6 million during fiscal 2016 and fiscal 2015 , respectively . gross receipt taxes are included in taxes other than income taxes on the consolidated statements of income . ( b ) deviation from average heating degree days for the 15-year period 2000-2014 based upon weather statistics provided by the national oceanic and atmospheric administration ( “ noaa ” ) for airports located within gas utility 's service territory . ( c ) amounts exclude png gas ' heating , ventilation and air-conditioning service business sold in june 2015 ( see note 16 to consolidated financial statements ) . temperatures in gas utility 's service territory during fiscal 2016 based upon heating degree days were 13.6 % warmer than normal and 17.8 % warmer than fiscal 2015. in particular , gas utility temperatures in the critical heating-season month of december were 37 % warmer than normal . gas utility core market volumes declined 15.1 bcf ( 18.6 % ) reflecting the effects of the significantly warmer weather . total gas utility fiscal 2016 distribution system throughput was about equal to fiscal 2015 as the lower core market volumes were substantially offset by higher large firm delivery service volumes . gas utility 's core market customers comprise firm- residential , commercial and industrial ( “ retail core-market ” ) customers who purchase their gas from gas utility and , to a much lesser extent , residential and small commercial customers who purchase their gas from others . electric utility kilowatt-hour sales were 4.8 % lower than in the prior year principally reflecting the impact of the warmer weather on heating-related sales . ugi utilities revenues decreased $ 273.1 million principally reflecting a $ 255.7 million decrease in gas utility revenues and a $ 16.5 million decrease in electric utility revenues . the lower gas utility revenues principally reflect a decrease in core market revenues ( $ 203.1 million ) and lower off-system sales revenues ( $ 51.4 million ) . the $ 203.1 million decrease in fiscal 2016 gas utility core market revenues reflects the effects of the lower core market throughput ( $ 135.4 million ) and lower average pgc rates ( $ 67.7 million ) . the lower electric utility revenues principally resulted from lower ds rates ( $ 8.0 million ) , lower sales 15 volumes ( $ 5.4 million ) and lower transmission revenue ( $ 2.6 million ) . because gas utility and electric utility are subject to reconcilable pgc and ds recovery mechanisms , increases or decreases in the actual cost of gas or electricity associated with customers who purchase their gas or electricity from ugi utilities impact revenues and cost of sales but have no direct effect on retail core-market margin ( see note 4 to consolidated financial statements for a discussion of these recovery mechanisms ) . ugi utilities cost of sales was $ 289.8 million in fiscal 2016 compared with $ 510.8 million in fiscal 2015 principally reflecting the combined effects of the lower average gas utility pgc rates ( $ 92.3 million ) , lower cost of sales associated with gas utility off-system sales ( $ 51.4 million ) and lower gas utility retail core-market volumes sold ( $ 67.5 million ) . electric utility cost of sales was $ 11.5 million lower reflecting lower ds rates ( $ 8.5 million ) and the lower volumes sold . ugi utilities fiscal 2016 total margin decreased $ 51.3 million principally reflecting lower gas utility total margin from core market customers ( $ 43.3 million ) . the decrease in gas utility core market margin reflects the lower core market throughput . electric utility total margin decreased $ 4.2 million principally reflecting the lower volume sales as a result of the warmer fiscal 2016 weather and the lower transmission revenue . ugi utilities operating income and income before income taxes decreased $ 40.8 million and $ 37.3 million , respectively . the decreases in operating income and income before income taxes principally reflects the decrease in total margin ( $ 51.3 million ) , higher depreciation expense ( $ 4.4 million ) and lower other operating income ( $ 10.9 million ) which includes , among other things , higher environmental matters expense ( $ 4.1 million ) , lower margin from off-system sales ( $ 2.2 million ) , lower revenue from construction services ( $ 2.1 million ) and higher interest on pgc overcollections ( $ 1.1 million ) . these were partially offset by operating and administrative expenses that were $ 25.6 million lower than the prior year primarily reflecting lower net preliminary development stage expenses associated with an information technology ( “ it ” ) project ( $ 8.6 million ) , including the year-over-year impact of the current year capitalization of $ 5.4 million of such it costs expensed in prior years ( see note 4 to consolidated financial statements ) , and , to a lesser extent , lower uncollectible accounts ( $ 5.7 million ) , system maintenance expenses ( $ 4.8 million ) and employee benefits ( $ 4.7 million ) . interest expense and income taxes . our interest expense in fiscal 2016 was $ 3.5 million lower than in fiscal 2015 principally reflecting ugi utilities ' lower average long-term debt outstanding and lower average interest rates . our effective income tax rate in fiscal 2016 was slightly higher than in the prior year . fiscal 2015 compared with fiscal 2014 replace_table_token_1_th ( a ) gas utility 's total margin represents total revenues less total cost of sales . electric utility 's total margin represents total revenues less total cost of sales and electric utility gross receipts taxes , of $ 5.6 million and $ 5.8 million during fiscal 2015 and fiscal 2014 , respectively . story_separator_special_tag ugi utilities also transferred certain associated storage inventories upon the commencement of the scaas , receives a transfer of storage inventories at the end of the scaas , and makes payments associated with refilling storage inventories during the term of the scaas . energy services , in turn , provides a firm delivery service and makes certain payments to ugi utilities for its various obligations under the scaas . during fiscal 2016 , fiscal 2015 and fiscal 2014 , these payments were not material . ugi utilities incurred costs associated with energy services ' scaas totaling $ 12.7 million , $ 16.8 million and $ 38.3 million in fiscal 2016 , fiscal 2015 and fiscal 2014 , respectively . in conjunction with the scaas , ugi utilities received security deposits from energy services . the amounts of such security deposits , which are included in other current liabilities on the consolidated balance sheets , were $ 8.1 million and $ 10.7 million at september 30 , 2016 and 2015 , respectively . ugi utilities reflects the historical cost of the gas storage inventories and any exchange receivable from energy services ( representing amounts of natural gas inventories used but not yet replenished by energy services ) on its balance sheet under the caption inventories . the carrying values of these gas storage inventories at september 30 , 2016 and 2015 , comprising approximately 4.6 bcf and 5.0 bcf of natural gas , were $ 11.1 million and $ 12.9 million , respectively . ugi utilities has gas supply and delivery service agreements with energy services pursuant to which energy services provides certain gas supply and related delivery service to gas utility primarily during the heating season months of november through march . the aggregate amount of these transactions ( exclusive of transactions pursuant to the scaas ) during fiscal 2016 , fiscal 2015 and fiscal 2014 totaled $ 63.3 million , $ 47.8 million and $ 35.8 million , respectively . 21 from time to time , the company sells natural gas or pipeline capacity to energy services . during fiscal 2016 , fiscal 2015 and fiscal 2014 , revenues associated with sales to energy services totaled $ 30.7 million , $ 79.2 million and $ 109.9 million , respectively . also from time to time , the company purchases natural gas , pipeline capacity and electricity from energy services ( in addition to those transactions already described above ) and purchases a firm storage service from ugi storage company , a subsidiary of energy services , under one-year agreements . during fiscal 2016 , fiscal 2015 and fiscal 2014 , such purchases totaled $ 35.1 million , $ 85.4 million and $ 128.1 million , respectively . off-balance-sheet arrangements we do not have any off-balance-sheet arrangements that are expected to have an effect on the company 's financial condition , revenues and expenses , results of operations , liquidity , capital expenditures or capital resources . market risk disclosures our primary market risk exposures are ( 1 ) commodity price risk and ( 2 ) interest rate risk . although we use derivative financial and commodity instruments to reduce market price risk associated with forecasted transactions , we do not use derivative financial and commodity instruments for speculative or trading purposes . commodity price risk gas utility 's tariffs contain clauses that permit recovery of all of the prudently incurred costs of natural gas it sells to its retail core-market customers , including the cost of financial instruments used to hedge purchased gas costs . the recovery clauses provide for periodic adjustments for the difference between the total amounts actually collected from customers through pgc rates and the recoverable costs incurred . because of this ratemaking mechanism , there is limited commodity price risk associated with our gas utility operations . gas utility uses derivative financial instruments including natural gas futures and option contracts traded on the new york mercantile exchange ( “ nymex ” ) to reduce volatility in the cost of gas it purchases for its retail core-market customers . the cost of these derivative financial instruments , net of any associated gains or losses , is included in gas utility 's pgc recovery mechanism . the change in market value of natural gas futures contracts can require daily deposits of cash in futures accounts . at september 30 , 2016 and 2015 , gas utility had $ 0.6 million and $ 6.6 million of restricted cash in brokerage accounts , respectively . at september 30 , 2016 and 2015 , the fair values of our natural gas futures and option contracts were gains and ( losses ) of $ 4.3 million and $ ( 3.3 ) million , respectively . electric utility 's ds tariffs contain clauses which permit recovery of all prudently incurred power costs , including the cost of financial instruments used to hedge electricity costs , through the application of ds rates . because of this ratemaking mechanism , there is limited power cost risk , including the cost of financial transmission rights ( “ ftrs ” ) and forward electricity purchase contracts , associated with our electric utility operations . at september 30 , 2016 , all of our electric utility 's forward electricity purchase contracts were subject to the normal purchase and normal sale ( “ npns ” ) exception . in addition , gas utility and electric utility from time to time enter into exchange-traded gasoline futures contracts for a portion of gasoline volumes expected to be used in their operations . these gasoline futures contracts are recorded at fair value with changes in fair value reflected in operating expenses and other income . the amount of unrealized gains on these contracts and associated volumes under contract at september 30 , 2016 and 2015 , were not material . interest rate risk we have both fixed-rate debt and variable rate debt . changes in interest rates impact the cash flows

