the following table summarizes the estimated net proved reserves and related standardized measure for the years indicated . the standardized measure is not intended to represent the current market value of our estimated oil and natural gas reserves . replace_table_token_16_th ( 1 ) december 31 , 2016 reserves were based on average prices of $ 42.75 wti per bbl of oil , $ 2.48 henry hub per mcf of natural gas and $ 19.70 per bbl of ngls . december 31 , 2015 reserves were based on average prices of $ 50.28 wti for oil , $ 2.59 henry hub for natural gas and $ 20.37 for ngls . december 31 , 2014 reserves were based on average prices of $ 94.99 wti for oil , $ 4.35 henry hub for natural gas and $ 39.65 for ngls . the following table summarizes the average sales prices received for oil , natural gas and ngls , before the effects of hedging contracts , for the years indicated : replace_table_token_17_th the following table summarizes the average sales prices received for oil , natural gas and ngls , after the effects of hedging contracts , for the years indicated : 38 replace_table_token_18_th commodity prices are inherently volatile and are influenced by many factors outside of our control . as of february 14 , 2017 , we have hedged 2,406,875 barrels of oil and 3,650,000 mmbtu of natural gas or approximately 50 % of our expected 2017 production and 864,250 barrels of oil for our 2018 production at price levels that provide some economic certainty to our cash flows . we focus our efforts on increasing oil , natural gas and ngls reserves and production while controlling costs at a level that is appropriate for long-term operations . our future earnings and cash flows are dependent on our ability to manage our revenues and overall cost structure to a level that allows for profitable production . on july 14 , 2016 , we closed on the sale of certain non-core assets in the uinta basin . total gross consideration , after initial closing adjustments , was $ 33.1 million , including cash proceeds of $ 28.3 million and $ 4.8 million related to the relief of asset retirement obligations . results of operations year ended december 31 , 2016 compared with year ended december 31 , 2015 the following table sets forth selected operating data for the periods indicated : 39 replace_table_token_19_th * not meaningful . ( 1 ) included in general and administrative expense is long-term cash and equity incentive compensation of $ 11.9 million ( or $ 1.96 per boe ) and $ 10.8 million ( or $ 1.64 per boe ) for the years ended december 31 , 2016 and 2015 , respectively . production revenues and volumes . production revenues decreased to $ 178.3 million for the year ended december 31 , 2016 from $ 204.5 million for the year ended december 31 , 2015 . the decrease in production revenues was due to an 8 % decrease in production volumes and a 6 % decrease in the average realized prices per boe before hedging . the decrease in 40 production volumes reduced production revenues by approximately $ 14.7 million , while the decrease in average prices decreased production revenues by approximately $ 11.5 million . total production volumes of 6.1 mmboe for the year ended december 31 , 2016 decreased from 6.6 mmboe for the year ended december 31 , 2015 . the decrease is primarily related to a 43 % decrease in production from the uinta oil program due to natural production declines with no significant drilling or recompletion activities to offset these declines as well as the sale of certain non-core uinta oil program assets during the year ended december 31 , 2016 . the overall production volume decrease was offset by an increase in the dj basin production volumes , which were partially offset by non-core asset sales completed during the year ended december 31 , 2015. additional information concerning production is in the following table : replace_table_token_20_th other operating revenues . other operating revenues decreased to $ 0.5 million for the year ended december 31 , 2016 from $ 3.4 million for the year ended december 31 , 2015 . other operating revenues for 2016 consisted of $ 1.2 million related to gathering and compression fees received from third parties , offset by revised third party gas processing statements , which reduced production revenues associated with sold properties in the piceance basin by $ 0.7 million . the piceance basin properties were sold in september 2014. other operating revenues for 2015 consisted of a $ 1.3 million true up related to the sold properties in the west tavaputs area of the uinta basin . the west tavaputs properties were sold in december 2013. in addition , other operating revenues for 2015 included income of $ 1.6 million related to gathering and compression fees received from third parties and $ 0.5 million related to the sale of seismic data . lease operating expense ( `` loe `` ) . loe decreased to $ 4.58 per boe for the year ended december 31 , 2016 from $ 6.48 per boe for the year ended december 31 , 2015 . the decrease per boe for the year ended december 31 , 2016 compared with the year ended december 31 , 2015 is primarily related to operational efficiencies , a decrease in service industry costs , reduced workover activity in the uinta basin and sales of certain non-core assets in the dj and uinta basins , which had higher loe costs on a per boe basis . production tax expense . total production taxes decreased to $ 10.6 million for the year ended december 31 , 2016 from $ 12.2 million for the year ended december 31 , 2015 . story_separator_special_tag the west tavaputs properties were sold in december 2013. in addition , other operating revenues for 2015 includes income of $ 1.6 million related to gathering and compression fees received from third parties and $ 0.5 million related to the sale of seismic data . other operating revenues increased to $ 8.2 million for the year ended december 31 , 2014 from $ 2.5 million for the year ended december 31 , 2013. other operating revenues for 2014 consisted of $ 5.9 million related to the recovery of processing deductions on ngl revenues and $ 2.3 million of income from gathering and compression fees received from third parties . the $ 5.9 million related to the recovery of processing deductions on ngl revenues is based on guidance provided by the office of natural resources revenue ( `` onrr `` ) . additional processing deductions were taken against ngl royalties paid on federal and state leases from 2008 through july 2013 in the west tavaputs area of the uinta basin . lease operating expense . loe decreased to $ 6.48 per boe for the year ended december 31 , 2015 from $ 6.62 per boe for the year ended december 31 , 2014. the decrease per boe for the year ended december 31 , 2015 compared with the year ended december 31 , 2014 is related to operational efficiencies , a decrease in service industry costs , reduced workover activity in the uinta basin and our decision to shut-in certain uinta basin wells due to the current low commodity price environment . 46 gathering , transportation and processing expense ( `` gtp `` ) . gtp expense decreased to $ 0.53 per boe for the year ended december 31 , 2015 from $ 3.89 per boe for the year ended december 31 , 2014. gtp on a per boe basis decreased due to inherently lower gtp from our oil producing properties in the dj and uinta basin development areas and due to the sale of natural gas properties with higher gtp expense per boe in the piceance divestiture . in addition , beginning october 1 , 2014 , costs associated with unused firm natural gas pipeline transportation contracts have been included in unused commitments in the consolidated statements of operations . see `` unused commitments `` below for further information . production tax expense . total production taxes decreased to $ 12.2 million for the year ended december 31 , 2015 from $ 31.3 million for the year ended december 31 , 2014. the overall decrease in production tax expense is related to lower sales volumes as the result of the piceance divestiture and the powder river oil divestitures and a 39 % decrease in average realized prices before hedging . production taxes are primarily based on the wellhead values of production , which exclude gains and losses associated with hedging activities . production taxes as a percentage of oil , natural gas and ngl sales before hedging adjustments were 6.0 % and 6.8 % for the years ended december 31 , 2015 and december 31 , 2014 , respectively . production tax rates vary across the different areas in which we operate . as the proportion of our production changes from area to area , our average production tax rate will vary depending on the quantities produced from each area and the production tax rates in effect for those areas . impairment , dry hole costs and abandonment expense . our impairment , dry hole costs and abandonment expense for the years ended december 31 , 2015 and 2014 is summarized below : replace_table_token_26_th ( 1 ) due to the decline in oil prices , we recognized a non-cash impairment charge associated with the proved and unproved oil and gas properties in the uinta oil program for the year ended december 31 , 2015 . ( 2 ) as the result of the powder river oil divestiture , the carrying values of the remaining properties were analyzed relative to their estimated fair market values . as a result , we recognized impairment expense on proved properties of $ 14.8 million for the year ended december 31 , 2014. these properties were classified as held for sale as of december 31 , 2014. in addition , $ 1.0 million of proved property impairment expense was incurred during the year ended december 31 , 2014 related to the west tavaputs divestiture based upon a true-up of previously estimated carrying value . see note 4 of the notes to consolidated financial statements for more information related to these divestitures . ( 3 ) as a result of unsuccessful drilling and completion activity by an industry partner in the paradox basin , we recognized impairment expense of $ 11.6 million during the year ended december 31 , 2014 related to the remaining unproved property in the paradox basin . we recognized impairment expense of $ 6.1 million related to certain unproved oil and gas properties in the uinta basin as a result of having no future plans to evaluate the acreage . in addition , we recognized impairment expense of $ 6.4 million as the result of the powder river oil divestiture as discussed above . ( gain ) loss on sale of properties . ( gain ) loss on sale of properties decreased to a loss of $ 1.7 million for the year ended december 31 , 2015 from a loss of $ 100.4 million for the year ended december 31 , 2014 . ( gain ) loss on sale of properties for the year ended december 31 , 2015 was primarily related to the loss on the sale of frac tank trailers previously used in completion operations in the amount of $ 2.4 million , offset by net gains related to purchase price adjustments for the piceance divestiture and powder river oil divestiture . ( gain ) loss on sale of properties for the year ended december 31 , 2014 consisted of

net cash provided by operating activities was $ 121.7 million , $ 193.7 million and $ 261.7 million in 2016 , 2015 and 2014 , respectively . the changes in net cash provided by operating activities are discussed above in `` results of operations '' . the continued decrease in net cash provided by operating activities from 2014 to 2015 and from 2015 to 2016 was primarily due to a decrease in production revenues related to asset sales in 2014 and 2015 and lower commodity prices in 2015 and 2016 , offset by lower lease operating and production tax expenses in 2015 and 2016. we estimate that cash flows provided by hedging activities will decrease in 2017 due to lower contractual fixed prices . the weighted average fixed price for our oil hedge contracts scheduled to settle in 2017 is $ 58.59 compared to $ 76.88 in 2016. commodity hedging activities our operating cash flow is sensitive to many variables , the most significant of which is the volatility of prices for oil , natural gas and ngls . prices for these commodities are determined primarily by prevailing market conditions . national and worldwide economic activity and political stability , weather , infrastructure capacity to reach markets , supply levels and other variable factors influence market conditions for these products . these factors are beyond our control and are difficult to predict . to mitigate some of the potential negative impact on cash flow caused by changes in oil , natural gas and ngl prices , we have entered into financial commodity swap contracts to receive fixed prices for a portion of our production revenue . at december 31 , 2016 , we had in place crude oil swaps covering portions of our 2017 and 2018 production and natural gas swaps covering portions of our 2017 production . in addition to financial contracts , we may at times enter into various physical commodity contracts for the sale of oil and natural gas that cover varying periods of time and have varying pricing provisions .


 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.
     ```net cash provided by operating activities was $ 121.7 million , $ 193.7 million and $ 261.7 million in 2016 , 2015 and 2014 , respectively . the changes in net cash provided by operating activities are discussed above in `` results of operations '' . the continued decrease in net cash provided by operating activities from 2014 to 2015 and from 2015 to 2016 was primarily due to a decrease in production revenues related to asset sales in 2014 and 2015 and lower commodity prices in 2015 and 2016 , offset by lower lease operating and production tax expenses in 2015 and 2016. we estimate that cash flows provided by hedging activities will decrease in 2017 due to lower contractual fixed prices . the weighted average fixed price for our oil hedge contracts scheduled to settle in 2017 is $ 58.59 compared to $ 76.88 in 2016. commodity hedging activities our operating cash flow is sensitive to many variables , the most significant of which is the volatility of prices for oil , natural gas and ngls . prices for these commodities are determined primarily by prevailing market conditions . national and worldwide economic activity and political stability , weather , infrastructure capacity to reach markets , supply levels and other variable factors influence market conditions for these products . these factors are beyond our control and are difficult to predict . to mitigate some of the potential negative impact on cash flow caused by changes in oil , natural gas and ngl prices , we have entered into financial commodity swap contracts to receive fixed prices for a portion of our production revenue . at december 31 , 2016 , we had in place crude oil swaps covering portions of our 2017 and 2018 production and natural gas swaps covering portions of our 2017 production . in addition to financial contracts , we may at times enter into various physical commodity contracts for the sale of oil and natural gas that cover varying periods of time and have varying pricing provisions .
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 Suspicious Activity Report : the following table summarizes the estimated net proved reserves and related standardized measure for the years indicated . the standardized measure is not intended to represent the current market value of our estimated oil and natural gas reserves . replace_table_token_16_th ( 1 ) december 31 , 2016 reserves were based on average prices of $ 42.75 wti per bbl of oil , $ 2.48 henry hub per mcf of natural gas and $ 19.70 per bbl of ngls . december 31 , 2015 reserves were based on average prices of $ 50.28 wti for oil , $ 2.59 henry hub for natural gas and $ 20.37 for ngls . december 31 , 2014 reserves were based on average prices of $ 94.99 wti for oil , $ 4.35 henry hub for natural gas and $ 39.65 for ngls . the following table summarizes the average sales prices received for oil , natural gas and ngls , before the effects of hedging contracts , for the years indicated : replace_table_token_17_th the following table summarizes the average sales prices received for oil , natural gas and ngls , after the effects of hedging contracts , for the years indicated : 38 replace_table_token_18_th commodity prices are inherently volatile and are influenced by many factors outside of our control . as of february 14 , 2017 , we have hedged 2,406,875 barrels of oil and 3,650,000 mmbtu of natural gas or approximately 50 % of our expected 2017 production and 864,250 barrels of oil for our 2018 production at price levels that provide some economic certainty to our cash flows . we focus our efforts on increasing oil , natural gas and ngls reserves and production while controlling costs at a level that is appropriate for long-term operations . our future earnings and cash flows are dependent on our ability to manage our revenues and overall cost structure to a level that allows for profitable production . on july 14 , 2016 , we closed on the sale of certain non-core assets in the uinta basin . total gross consideration , after initial closing adjustments , was $ 33.1 million , including cash proceeds of $ 28.3 million and $ 4.8 million related to the relief of asset retirement obligations . results of operations year ended december 31 , 2016 compared with year ended december 31 , 2015 the following table sets forth selected operating data for the periods indicated : 39 replace_table_token_19_th * not meaningful . ( 1 ) included in general and administrative expense is long-term cash and equity incentive compensation of $ 11.9 million ( or $ 1.96 per boe ) and $ 10.8 million ( or $ 1.64 per boe ) for the years ended december 31 , 2016 and 2015 , respectively . production revenues and volumes . production revenues decreased to $ 178.3 million for the year ended december 31 , 2016 from $ 204.5 million for the year ended december 31 , 2015 . the decrease in production revenues was due to an 8 % decrease in production volumes and a 6 % decrease in the average realized prices per boe before hedging . the decrease in 40 production volumes reduced production revenues by approximately $ 14.7 million , while the decrease in average prices decreased production revenues by approximately $ 11.5 million . total production volumes of 6.1 mmboe for the year ended december 31 , 2016 decreased from 6.6 mmboe for the year ended december 31 , 2015 . the decrease is primarily related to a 43 % decrease in production from the uinta oil program due to natural production declines with no significant drilling or recompletion activities to offset these declines as well as the sale of certain non-core uinta oil program assets during the year ended december 31 , 2016 . the overall production volume decrease was offset by an increase in the dj basin production volumes , which were partially offset by non-core asset sales completed during the year ended december 31 , 2015. additional information concerning production is in the following table : replace_table_token_20_th other operating revenues . other operating revenues decreased to $ 0.5 million for the year ended december 31 , 2016 from $ 3.4 million for the year ended december 31 , 2015 . other operating revenues for 2016 consisted of $ 1.2 million related to gathering and compression fees received from third parties , offset by revised third party gas processing statements , which reduced production revenues associated with sold properties in the piceance basin by $ 0.7 million . the piceance basin properties were sold in september 2014. other operating revenues for 2015 consisted of a $ 1.3 million true up related to the sold properties in the west tavaputs area of the uinta basin . the west tavaputs properties were sold in december 2013. in addition , other operating revenues for 2015 included income of $ 1.6 million related to gathering and compression fees received from third parties and $ 0.5 million related to the sale of seismic data . lease operating expense ( `` loe `` ) . loe decreased to $ 4.58 per boe for the year ended december 31 , 2016 from $ 6.48 per boe for the year ended december 31 , 2015 . the decrease per boe for the year ended december 31 , 2016 compared with the year ended december 31 , 2015 is primarily related to operational efficiencies , a decrease in service industry costs , reduced workover activity in the uinta basin and sales of certain non-core assets in the dj and uinta basins , which had higher loe costs on a per boe basis . production tax expense . total production taxes decreased to $ 10.6 million for the year ended december 31 , 2016 from $ 12.2 million for the year ended december 31 , 2015 . story_separator_special_tag the west tavaputs properties were sold in december 2013. in addition , other operating revenues for 2015 includes income of $ 1.6 million related to gathering and compression fees received from third parties and $ 0.5 million related to the sale of seismic data . other operating revenues increased to $ 8.2 million for the year ended december 31 , 2014 from $ 2.5 million for the year ended december 31 , 2013. other operating revenues for 2014 consisted of $ 5.9 million related to the recovery of processing deductions on ngl revenues and $ 2.3 million of income from gathering and compression fees received from third parties . the $ 5.9 million related to the recovery of processing deductions on ngl revenues is based on guidance provided by the office of natural resources revenue ( `` onrr `` ) . additional processing deductions were taken against ngl royalties paid on federal and state leases from 2008 through july 2013 in the west tavaputs area of the uinta basin . lease operating expense . loe decreased to $ 6.48 per boe for the year ended december 31 , 2015 from $ 6.62 per boe for the year ended december 31 , 2014. the decrease per boe for the year ended december 31 , 2015 compared with the year ended december 31 , 2014 is related to operational efficiencies , a decrease in service industry costs , reduced workover activity in the uinta basin and our decision to shut-in certain uinta basin wells due to the current low commodity price environment . 46 gathering , transportation and processing expense ( `` gtp `` ) . gtp expense decreased to $ 0.53 per boe for the year ended december 31 , 2015 from $ 3.89 per boe for the year ended december 31 , 2014. gtp on a per boe basis decreased due to inherently lower gtp from our oil producing properties in the dj and uinta basin development areas and due to the sale of natural gas properties with higher gtp expense per boe in the piceance divestiture . in addition , beginning october 1 , 2014 , costs associated with unused firm natural gas pipeline transportation contracts have been included in unused commitments in the consolidated statements of operations . see `` unused commitments `` below for further information . production tax expense . total production taxes decreased to $ 12.2 million for the year ended december 31 , 2015 from $ 31.3 million for the year ended december 31 , 2014. the overall decrease in production tax expense is related to lower sales volumes as the result of the piceance divestiture and the powder river oil divestitures and a 39 % decrease in average realized prices before hedging . production taxes are primarily based on the wellhead values of production , which exclude gains and losses associated with hedging activities . production taxes as a percentage of oil , natural gas and ngl sales before hedging adjustments were 6.0 % and 6.8 % for the years ended december 31 , 2015 and december 31 , 2014 , respectively . production tax rates vary across the different areas in which we operate . as the proportion of our production changes from area to area , our average production tax rate will vary depending on the quantities produced from each area and the production tax rates in effect for those areas . impairment , dry hole costs and abandonment expense . our impairment , dry hole costs and abandonment expense for the years ended december 31 , 2015 and 2014 is summarized below : replace_table_token_26_th ( 1 ) due to the decline in oil prices , we recognized a non-cash impairment charge associated with the proved and unproved oil and gas properties in the uinta oil program for the year ended december 31 , 2015 . ( 2 ) as the result of the powder river oil divestiture , the carrying values of the remaining properties were analyzed relative to their estimated fair market values . as a result , we recognized impairment expense on proved properties of $ 14.8 million for the year ended december 31 , 2014. these properties were classified as held for sale as of december 31 , 2014. in addition , $ 1.0 million of proved property impairment expense was incurred during the year ended december 31 , 2014 related to the west tavaputs divestiture based upon a true-up of previously estimated carrying value . see note 4 of the notes to consolidated financial statements for more information related to these divestitures . ( 3 ) as a result of unsuccessful drilling and completion activity by an industry partner in the paradox basin , we recognized impairment expense of $ 11.6 million during the year ended december 31 , 2014 related to the remaining unproved property in the paradox basin . we recognized impairment expense of $ 6.1 million related to certain unproved oil and gas properties in the uinta basin as a result of having no future plans to evaluate the acreage . in addition , we recognized impairment expense of $ 6.4 million as the result of the powder river oil divestiture as discussed above . ( gain ) loss on sale of properties . ( gain ) loss on sale of properties decreased to a loss of $ 1.7 million for the year ended december 31 , 2015 from a loss of $ 100.4 million for the year ended december 31 , 2014 . ( gain ) loss on sale of properties for the year ended december 31 , 2015 was primarily related to the loss on the sale of frac tank trailers previously used in completion operations in the amount of $ 2.4 million , offset by net gains related to purchase price adjustments for the piceance divestiture and powder river oil divestiture . ( gain ) loss on sale of properties for the year ended december 31 , 2014 consisted of

