the increase in depreciation , depletion , and amortization during the current successor period when compared to the 2017 successor period primarily correlates to an increase in capital expenditures . abandonment and impairment of unproved properties . during the year ended december 31 , 2018 , abandonment and impairment of unproved properties of $ 5.3 million was due to the standard annual amortization of our emergence leases that were not held by production at the time of our emergence . there were no abandonment and impairment of unproved properties during the 2017 successor and predecessor periods . please refer to part ii , item 8 , note 1 - summary of significant accounting policies for additional discussion on our impairment policy and practices . unused commitments . there were immaterial amounts of unused commitments during the year ended december 31 , 2018. no amounts of unused commitments were incurred during the 2017 successor period . during the 2017 predecessor period , we incurred $ 1.0 million in unused commitment fees on a water supply contract in the wattenberg field . general and administrative expense . our general and administrative expense per boe was $ 6.62 , $ 11.34 , and $ 7.28 for the year ended december 31 , 2018 , 2017 successor period , and 2017 predecessor period , respectively . the 2017 successor period reflects a one-time cash and non-cash $ 9.6 million , or $ 2.55 per boe , severance charge primarily related to the company 's former chief executive officer 's separation from the company . the remaining decrease in expense for the year ended december 31 , 2018 when compared to the combined 2017 successor and predecessor periods was due to decreases in consultant restructuring fees of $ 5.4 million and wages and benefits of $ 2.7 million , partially offset by increases in employee bonuses of $ 1.6 million and professional services of $ 0.8 million . derivative gain ( loss ) . our derivative gain for the year ended december 31 , 2018 was $ 30.3 million as compared to a loss of $ 15.4 million for the 2017 successor period . we had no derivative contracts during the 2017 predecessor period . during the year ended december 31 , 2018 , we entered into several oil and gas costless collars , puts , and swap contracts . our derivative gain is primarily due to fair market value adjustments caused by market prices being lower than our contracted hedge prices . please refer to part ii , item 8 , note 13 - derivatives for additional discussion . interest expense . our interest expense for the year ended december 31 , 2018 , the 2017 successor period , and the 2017 predecessor period was $ 2.6 million , $ 0.8 million , and $ 5.7 million , respectively . during the year ended december 31 , 2018 , the company incurred $ 1.4 million in interest expense associated with its current and prior credit facilities , commitment fees of $ 0.9 million , and miscellaneous fees of $ 0.3 million related to its current and prior credit facilities . the company incurred $ 0.7 million in commitment fees on the available borrowing base under the prior credit facility during the 2017 successor period . interest expense on the company 's senior notes was $ 1.0 million for the 2017 predecessor period , with the remaining interest expense relating to the predecessor credit facility . the company had no outstanding debt during the 2017 successor period . average debt outstanding for the year ended december 31 , 2018 and the 2017 predecessor period was $ 26.8 million and $ 991.7 million , respectively . 62 year ended december 31 , 2017 compared to year ended december 31 , 2016 the table below presents revenues , sales volumes , and average sales prices for the periods indicated ( in thousands , except per boe amounts ) : replace_table_token_18_th ( 1 ) crude oil sales excludes $ 0.2 million , $ 0.1 million , and $ 0.5 million of oil transportation revenues from third parties , which do not have associated sales volumes , for the 2017 successor period , 2017 predecessor period , and the 2016 predecessor period , respectively . ( 2 ) natural gas sales excludes $ 0.8 million , $ 0.4 million , and $ 1.5 million of gas gathering revenues from third parties , which do not have associated sales volumes , for the 2017 successor period , 2017 predecessor period , and the 2016 predecessor period , respectively . ( 3 ) determined using the ratio of 6 mcf of natural gas to 1 bbl of crude oil . ( 4 ) the derivatives economically hedge the price we receive for crude oil . for the 2017 successor period , the derivative cash settlement loss was $ 1.5 million and the derivative cash settlement gain was $ 18.3 million for the 2016 predecessor period . please refer to part ii , item 8 , note 13 - derivatives for additional disclosures . operating revenues decreased by 1 % to $ 190.6 million for the year ended december 31 , 2017 compared to $ 193.3 million for the year ended december 31 , 2016 , largely due to a 26 % decrease in sales volumes offset by a 34 % increase in oil equivalent pricing . story_separator_special_tag the discounted obligations are recorded as liabilities on our accompanying balance sheets as of december 31 , 2018 and 2017. because these costs typically extend many years into the future , management prepares estimates and makes judgments that are subject to future revisions based upon numerous factors . please refer to part ii , item 8 , note 11 - asset retirement obligation , for additional discussion . critical accounting policies and estimates the discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements , which have been prepared in accordance with accounting principles generally accepted in the united states . the preparation of our financial statements requires us to make estimates and assumptions that affect the reported amounts of assets , liabilities , revenues , and expenses and related disclosure of contingent assets and liabilities . certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions , or if different assumptions had been used . we evaluate our estimates and assumptions on a regular basis . we base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances , the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources . actual results may differ from these estimates and assumptions used in preparation of our consolidated financial statements . we provide expanded discussion of our more significant accounting policies , estimates , and judgments below . we believe these accounting policies reflect our more significant estimates and assumptions used in preparation of our consolidated financial statements . please refer to part ii , item 8 , note 1 - summary of significant accounting policies to our audited consolidated financial statements for a discussion of additional accounting policies and estimates made by management . method of accounting for oil and natural gas properties oil and natural gas exploration and development activities are accounted for using the successful efforts method . under this method , all property acquisition costs and costs of exploratory and development wells are capitalized at cost when incurred , pending determination of whether the well has found proved reserves . if an exploratory well does not find proved reserves , the costs of drilling the well are charged to expense . the costs of development wells are capitalized whether 68 productive or nonproductive . all capitalized well costs and other associated costs and leasehold costs of proved properties are amortized on a unit-of-production basis over the remaining life of proved developed reserves and proved reserves , respectively . costs of retired , sold , or abandoned properties that constitute a part of an amortization base ( partial field ) are charged or credited , net of proceeds , to accumulated depreciation , depletion , and amortization unless doing so significantly affects the unit-of-production amortization rate for an entire field , in which case a gain or loss is recognized currently . gains or losses from the disposal of properties are recognized currently . expenditures for maintenance , repairs , and minor renewals necessary to maintain properties in operating condition are expensed as incurred . major betterments , replacements , and renewals are capitalized to the appropriate property and equipment accounts . estimated dismantlement and abandonment costs for oil and natural gas properties are capitalized , net of salvage , at their estimated net present value and amortized on a unit-of-production basis over the remaining life of the related proved developed reserves . unproved properties consist of costs incurred to acquire unproved leases , or lease acquisition costs . unproved lease acquisition costs are capitalized until the leases expire or when we specifically identify leases that will revert to the lessor , at which time we expense the associated unproved lease acquisition costs . the expensing or expiration of unproved lease acquisition costs are recorded as abandonment or impairment of unproved properties in the statements of operations and comprehensive income ( loss ) in our consolidated financial statements . lease acquisition costs are reclassified to proved properties and depleted on a unit-of-production basis once proved reserves have been assigned . for sales of entire working interests in unproved properties , gain or loss is recognized to the extent of the difference between the proceeds received and the net carrying value of the property . proceeds from sales of partial interests in unproved properties are accounted for as a recovery of costs unless the proceeds exceed the entire cost of the property . oil and natural gas reserve quantities and standardized measure in the current and prior year , our third-party petroleum consultant prepared our estimates of oil and natural gas reserves and associated future net revenues . during 2016 , our internal corporate reservoir engineering group prepared , and our third-party petroleum engineering consultant audited our estimates of oil and natural gas reserves and associated future net revenues . while the sec has adopted rules which allow us to disclose proved , probable , and possible reserves , we have elected to disclose only proved reserves in this annual report on form 10-k. the sec 's revised rules define proved reserves as the quantities of oil and gas , which , by analysis of geoscience and engineering data , can be estimated with reasonable certainty to be economically producible - from a given date forward , from known reservoirs , and under existing economic conditions , operating methods , and government regulations - prior to the time at which contracts providing the right to operate expire , unless evidence indicates that renewal is reasonably certain , regardless of whether deterministic or probabilistic methods are used for the estimation . the project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the

net cash provided by operating activities was $ 116.6 million as of december 31 , 2018 ; total liquidity of $ 312.9 million at december 31 , 2018 , consisting of our year-end cash balance plus funds available under the current credit facility ; wattenberg field sales volumes increased by 24 % for the year ended december 31 , 2018 when compared to the same period in 2017 ; rapidly improving well performance yielded over 1,000 srl equivalent economic drilling locations in wattenberg field ; secured our $ 750.0 million current credit facility with a borrowing base of $ 350.0 million on december 7 , 2018 ; wattenberg field proved reserves of 116.8 mmboe as of december 31 , 2018 increased 29 % when compared to the same period in 2017 ; pv-10 reserve value increased by 60 % to $ 955.0 million as of december 31 , 2018 when compared to the same period in 2017 ; divested of our mid-continent assets for net proceeds of $ 102.9 million and our north park basin assets for minimal net proceeds and full release of all current and future obligations ; invested $ 275.3 million to drill 78 gross wells and turning to sales 42 gross wells ; continued to increase our takeaway capacity utilizing four gas processors via eleven interconnects . chief executive officer appointment effective april 11 , 2018 , the company appointed eric t. greager as the new president and chief executive officer of the company . mr. greager has over 20 years of experience in the oil and gas industry , including exposure to both the operating and technical aspects of the industry . mr. greager , 47 , previously served as a vice president and general manager at encana oil & gas ( usa ) inc. mr. greager joined encana in 2006 and served in various management and executive positions , including as a member of the boards of directors of encana procurement inc. and encana oil & gas ( usa ) inc. mr. greager previously served on the board of directors of western energy alliance and the board of managers of hunter ridge energy services .


 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 $ 116.6 million as of december 31 , 2018 ; total liquidity of $ 312.9 million at december 31 , 2018 , consisting of our year-end cash balance plus funds available under the current credit facility ; wattenberg field sales volumes increased by 24 % for the year ended december 31 , 2018 when compared to the same period in 2017 ; rapidly improving well performance yielded over 1,000 srl equivalent economic drilling locations in wattenberg field ; secured our $ 750.0 million current credit facility with a borrowing base of $ 350.0 million on december 7 , 2018 ; wattenberg field proved reserves of 116.8 mmboe as of december 31 , 2018 increased 29 % when compared to the same period in 2017 ; pv-10 reserve value increased by 60 % to $ 955.0 million as of december 31 , 2018 when compared to the same period in 2017 ; divested of our mid-continent assets for net proceeds of $ 102.9 million and our north park basin assets for minimal net proceeds and full release of all current and future obligations ; invested $ 275.3 million to drill 78 gross wells and turning to sales 42 gross wells ; continued to increase our takeaway capacity utilizing four gas processors via eleven interconnects . chief executive officer appointment effective april 11 , 2018 , the company appointed eric t. greager as the new president and chief executive officer of the company . mr. greager has over 20 years of experience in the oil and gas industry , including exposure to both the operating and technical aspects of the industry . mr. greager , 47 , previously served as a vice president and general manager at encana oil & gas ( usa ) inc. mr. greager joined encana in 2006 and served in various management and executive positions , including as a member of the boards of directors of encana procurement inc. and encana oil & gas ( usa ) inc. mr. greager previously served on the board of directors of western energy alliance and the board of managers of hunter ridge energy services .
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 Suspicious Activity Report : the increase in depreciation , depletion , and amortization during the current successor period when compared to the 2017 successor period primarily correlates to an increase in capital expenditures . abandonment and impairment of unproved properties . during the year ended december 31 , 2018 , abandonment and impairment of unproved properties of $ 5.3 million was due to the standard annual amortization of our emergence leases that were not held by production at the time of our emergence . there were no abandonment and impairment of unproved properties during the 2017 successor and predecessor periods . please refer to part ii , item 8 , note 1 - summary of significant accounting policies for additional discussion on our impairment policy and practices . unused commitments . there were immaterial amounts of unused commitments during the year ended december 31 , 2018. no amounts of unused commitments were incurred during the 2017 successor period . during the 2017 predecessor period , we incurred $ 1.0 million in unused commitment fees on a water supply contract in the wattenberg field . general and administrative expense . our general and administrative expense per boe was $ 6.62 , $ 11.34 , and $ 7.28 for the year ended december 31 , 2018 , 2017 successor period , and 2017 predecessor period , respectively . the 2017 successor period reflects a one-time cash and non-cash $ 9.6 million , or $ 2.55 per boe , severance charge primarily related to the company 's former chief executive officer 's separation from the company . the remaining decrease in expense for the year ended december 31 , 2018 when compared to the combined 2017 successor and predecessor periods was due to decreases in consultant restructuring fees of $ 5.4 million and wages and benefits of $ 2.7 million , partially offset by increases in employee bonuses of $ 1.6 million and professional services of $ 0.8 million . derivative gain ( loss ) . our derivative gain for the year ended december 31 , 2018 was $ 30.3 million as compared to a loss of $ 15.4 million for the 2017 successor period . we had no derivative contracts during the 2017 predecessor period . during the year ended december 31 , 2018 , we entered into several oil and gas costless collars , puts , and swap contracts . our derivative gain is primarily due to fair market value adjustments caused by market prices being lower than our contracted hedge prices . please refer to part ii , item 8 , note 13 - derivatives for additional discussion . interest expense . our interest expense for the year ended december 31 , 2018 , the 2017 successor period , and the 2017 predecessor period was $ 2.6 million , $ 0.8 million , and $ 5.7 million , respectively . during the year ended december 31 , 2018 , the company incurred $ 1.4 million in interest expense associated with its current and prior credit facilities , commitment fees of $ 0.9 million , and miscellaneous fees of $ 0.3 million related to its current and prior credit facilities . the company incurred $ 0.7 million in commitment fees on the available borrowing base under the prior credit facility during the 2017 successor period . interest expense on the company 's senior notes was $ 1.0 million for the 2017 predecessor period , with the remaining interest expense relating to the predecessor credit facility . the company had no outstanding debt during the 2017 successor period . average debt outstanding for the year ended december 31 , 2018 and the 2017 predecessor period was $ 26.8 million and $ 991.7 million , respectively . 62 year ended december 31 , 2017 compared to year ended december 31 , 2016 the table below presents revenues , sales volumes , and average sales prices for the periods indicated ( in thousands , except per boe amounts ) : replace_table_token_18_th ( 1 ) crude oil sales excludes $ 0.2 million , $ 0.1 million , and $ 0.5 million of oil transportation revenues from third parties , which do not have associated sales volumes , for the 2017 successor period , 2017 predecessor period , and the 2016 predecessor period , respectively . ( 2 ) natural gas sales excludes $ 0.8 million , $ 0.4 million , and $ 1.5 million of gas gathering revenues from third parties , which do not have associated sales volumes , for the 2017 successor period , 2017 predecessor period , and the 2016 predecessor period , respectively . ( 3 ) determined using the ratio of 6 mcf of natural gas to 1 bbl of crude oil . ( 4 ) the derivatives economically hedge the price we receive for crude oil . for the 2017 successor period , the derivative cash settlement loss was $ 1.5 million and the derivative cash settlement gain was $ 18.3 million for the 2016 predecessor period . please refer to part ii , item 8 , note 13 - derivatives for additional disclosures . operating revenues decreased by 1 % to $ 190.6 million for the year ended december 31 , 2017 compared to $ 193.3 million for the year ended december 31 , 2016 , largely due to a 26 % decrease in sales volumes offset by a 34 % increase in oil equivalent pricing . story_separator_special_tag the discounted obligations are recorded as liabilities on our accompanying balance sheets as of december 31 , 2018 and 2017. because these costs typically extend many years into the future , management prepares estimates and makes judgments that are subject to future revisions based upon numerous factors . please refer to part ii , item 8 , note 11 - asset retirement obligation , for additional discussion . critical accounting policies and estimates the discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements , which have been prepared in accordance with accounting principles generally accepted in the united states . the preparation of our financial statements requires us to make estimates and assumptions that affect the reported amounts of assets , liabilities , revenues , and expenses and related disclosure of contingent assets and liabilities . certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions , or if different assumptions had been used . we evaluate our estimates and assumptions on a regular basis . we base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances , the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources . actual results may differ from these estimates and assumptions used in preparation of our consolidated financial statements . we provide expanded discussion of our more significant accounting policies , estimates , and judgments below . we believe these accounting policies reflect our more significant estimates and assumptions used in preparation of our consolidated financial statements . please refer to part ii , item 8 , note 1 - summary of significant accounting policies to our audited consolidated financial statements for a discussion of additional accounting policies and estimates made by management . method of accounting for oil and natural gas properties oil and natural gas exploration and development activities are accounted for using the successful efforts method . under this method , all property acquisition costs and costs of exploratory and development wells are capitalized at cost when incurred , pending determination of whether the well has found proved reserves . if an exploratory well does not find proved reserves , the costs of drilling the well are charged to expense . the costs of development wells are capitalized whether 68 productive or nonproductive . all capitalized well costs and other associated costs and leasehold costs of proved properties are amortized on a unit-of-production basis over the remaining life of proved developed reserves and proved reserves , respectively . costs of retired , sold , or abandoned properties that constitute a part of an amortization base ( partial field ) are charged or credited , net of proceeds , to accumulated depreciation , depletion , and amortization unless doing so significantly affects the unit-of-production amortization rate for an entire field , in which case a gain or loss is recognized currently . gains or losses from the disposal of properties are recognized currently . expenditures for maintenance , repairs , and minor renewals necessary to maintain properties in operating condition are expensed as incurred . major betterments , replacements , and renewals are capitalized to the appropriate property and equipment accounts . estimated dismantlement and abandonment costs for oil and natural gas properties are capitalized , net of salvage , at their estimated net present value and amortized on a unit-of-production basis over the remaining life of the related proved developed reserves . unproved properties consist of costs incurred to acquire unproved leases , or lease acquisition costs . unproved lease acquisition costs are capitalized until the leases expire or when we specifically identify leases that will revert to the lessor , at which time we expense the associated unproved lease acquisition costs . the expensing or expiration of unproved lease acquisition costs are recorded as abandonment or impairment of unproved properties in the statements of operations and comprehensive income ( loss ) in our consolidated financial statements . lease acquisition costs are reclassified to proved properties and depleted on a unit-of-production basis once proved reserves have been assigned . for sales of entire working interests in unproved properties , gain or loss is recognized to the extent of the difference between the proceeds received and the net carrying value of the property . proceeds from sales of partial interests in unproved properties are accounted for as a recovery of costs unless the proceeds exceed the entire cost of the property . oil and natural gas reserve quantities and standardized measure in the current and prior year , our third-party petroleum consultant prepared our estimates of oil and natural gas reserves and associated future net revenues . during 2016 , our internal corporate reservoir engineering group prepared , and our third-party petroleum engineering consultant audited our estimates of oil and natural gas reserves and associated future net revenues . while the sec has adopted rules which allow us to disclose proved , probable , and possible reserves , we have elected to disclose only proved reserves in this annual report on form 10-k. the sec 's revised rules define proved reserves as the quantities of oil and gas , which , by analysis of geoscience and engineering data , can be estimated with reasonable certainty to be economically producible - from a given date forward , from known reservoirs , and under existing economic conditions , operating methods , and government regulations - prior to the time at which contracts providing the right to operate expire , unless evidence indicates that renewal is reasonably certain , regardless of whether deterministic or probabilistic methods are used for the estimation . the project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the

