during the fourth quarter 2018 , the company brought 12 net wells online . for the full year , the company drilled 33 net wells and completed 32 net wells . the number of wells completed is above the company 's prior guidance of 25-27 net wells . the company drilled in all areas of its portfolio during 2018 and more recently has increased its investment in liquids opportunities . in the webb county gas area , which includes fasken , the company brought 13 net wells online in 2018. the company focused on developing its high return lower eagle ford wells and strategically appraising and delineating its upper eagle ford locations . the fasken development demonstrates the company 's shift to selectively employing high intensity slickwater fracs across its portfolio . for the second half of 2018 , the company averaged a completion intensity of approximately 2,700 pounds of proppant per lateral foot and 59 barrels of fluid per lateral foot , an increase of 71 % and 161 % , respectively , from the first half of the year . the company continues to value fasken 's consistent performance , low operating expense and upside potential . in the la salle condensate area , which includes artesia , the company brought five net wells online in 2018. due to operational improvements and service price reductions , the company realized an 18 % reduction in total well cost per foot from a two-well pad that was brought online in the third quarter and a three-well pad that was brought online in the fourth quarter . all five wells were completed similarly and averaged approximately 2,400 pounds of proppant per lateral foot and 64 barrels of slickwater fluid 33 per lateral foot . based on these results , the company plans to accelerate the development of the la salle condensate area in 2019 , which it believes will increase its oil and natural gas liquids production . in the southern eagle ford gas fairway , which includes oro grande , uno mas and south awp , the company carried forward its successful delineation and appraisal across its 60,000 gross acre position . the company continues to realize operational efficiencies with its nmc 6h well costing 30 % less and being drilled 35 % faster than the average of its nmc 1h through nmc 5h wells . in addition , the company continued to add to its position through leasing and acreage trades . the company swapped 2,300 net isolated acres for 4,300 net acres contiguous to its southern eagle ford gas area . in total , this acreage trade added 35 gross drilling locations . additionally , the acreage the company traded away was stranded and would have required a significant amount of midstream capital investment in order to develop . in the mcmullen oil area , which includes north awp and where the company had not been active for several years , the team set a company record by drilling an 11,400 foot lateral in the fourth quarter with a second well on this pad also exceeding 11,000 feet . during 2018 , the company decreased its drilling cost per lateral foot on a recent three-well pad by 27 % compared to a three-well pad drilled in 2014. these developments have affected both the cost and the speed of drilling , with the team setting a spud to total depth company record of 6.8 days on the smr 21h , a 31 % reduction from the prior company record . in 2018 , the company conducted numerous initiatives to reduce capital expenditures , including moving to offline production cementing , using significant amounts of regional sand and the more widespread utilization of simultaneous-operations . offline production cementing , which allows drilling rigs to reduce walking time in-between wells , saved roughly one-half day per well on multi-well pads . in 2018 , the company pumped over 200 million pounds of regional sand , over 30 % of the total sand pumped for the year , and aims to increase this percentage in 2019 due to its compelling value proposition . the company 's use of simultaneous-operations , including flowback and drill out activities , helped decrease the time to bring a well online by two days on average . these shortened cycle times , combined with our artificial intelligence guided rate-transient analysis , allow the company to turn wells online faster and manage them better during the critical initial flowback period . 2018 cost reduction initiatives : the company continues to focus on cost reduction measures and took additional actions in 2018 to reduce operating and overhead costs . these initiatives included field staff reductions , the use of regional sand in completions , disposition of uneconomic and higher cost properties , improved utilization of existing facilities , elimination of redundant equipment , and replacement of rental equipment with company-owned equipment . as previously mentioned , the company continues to improve its process for drilling and completing wells . the company 's procurement team takes a process-oriented approach to reducing the total delivered costs of purchased services by examining costs at their most detailed level . services are commonly sourced directly from the suppliers , which has led to a significant reduction in the company 's overall lease operating expenses at the field level . for example , the company 's lease operating expenses were $ 0.26 per mcfe for the year ended december 31 , 2018 , compared to $ 0.39 per mcfe for 2017 . additionally , our significant operational control , as well as our manageable leasehold obligations , provide us the flexibility to control our costs as we transition to a development mode across our portfolio . story_separator_special_tag we compute the provision for depreciation , depletion , and amortization ( “ dd & a ” ) of oil and natural gas properties using the unit-of-production method . the costs of unproved properties not being amortized are assessed quarterly , on a property-by-property basis , to determine whether such properties have been impaired . in determining whether such costs should be impaired , we evaluate current drilling results , lease expiration dates , current oil and gas industry conditions , international economic conditions , capital availability , and available geological and geophysical information . as these factors may change from period to period , our evaluation of these factors will change . any impairment assessed is added to the cost of proved properties being amortized . the calculation of the provision for dd & a requires us to use estimates related to quantities of proved oil and natural gas reserves and estimates of the impairment of unproved properties . the estimation process for both reserves and the impairment of unproved properties is subjective , and results may change over time based on current information and industry conditions . we believe our estimates and assumptions are reasonable ; however , such estimates and assumptions are subject to a number of risks and uncertainties that may cause actual results to differ materially from such estimates . full-cost ceiling test . at the end of each quarterly reporting period , the unamortized cost of oil and natural gas properties ( including natural gas processing facilities , capitalized asset retirement obligations and deferred income taxes , and excluding the recognized asset retirement obligation liability ) is limited to the sum of the estimated future net revenues from proved properties ( excluding cash outflows from recognized asset retirement obligations , including future development and abandonment costs of wells to be drilled , using the preceding 12-months ' average price based on closing prices on the first day of each month , adjusted for price differentials , discounted at 10 % , and the lower of cost or fair value of unproved properties ) adjusted for related income tax effects ( `` ceiling test `` ) . we believe our estimates and assumptions are reasonable ; however , such estimates and assumptions are subject to a number of risks and uncertainties that may cause actual results to differ materially from such estimates . if future capital expenditures outpace future discounted net cash flows in our reserve calculations , if we have significant declines in our oil and natural gas reserves volumes ( which also reduces our estimate of discounted future net cash flows from proved oil and natural gas reserves ) or if oil or natural gas prices decline , it is possible that non-cash write-downs of our oil and natural gas properties will occur in the future . we can not control and can not predict what future prices for oil and natural gas will be , thus we can not estimate the amount or timing of any potential future non-cash write-down of our oil and natural gas properties due to decreases in oil or natural gas prices . new accounting pronouncements . in february 2016 , the fasb issued asu 2016-02 , which requires lessees to record most leases on the balance sheet . under the new guidance , lease classification as either a finance lease or an operating lease will determine how lease-related revenue and expense are recognized . the guidance is effective for fiscal years beginning after december 15 , 2018 , including interim periods within those fiscal years . the company adopted this guidance on january 1 , 2019 , with no significant impact on the company 's financial statements resulting from implementation . see note 2 to our consolidated financial statements for more information . 41 forward-looking statements this report includes forward-looking statements intended to qualify for the safe harbors from liability established by the private securities litigation reform act of 1995 , section 27a of the securities act of 1933 , as amended , and section 21e of the securities exchange act of 1934 , as amended ( the `` exchange act `` ) . these forward-looking statements are subject to a number of risks and uncertainties , many of which are beyond our control . all statements , other than statements of historical fact included in this report , regarding our strategy , future operations , financial position , estimated production levels , expected oil and natural gas pricing , estimated oil and natural gas reserves or the present value thereof , reserve increases , capital expenditures , budget , projected costs , prospects , plans and objectives of management are forward-looking statements . when used in this report , the words “ could , ” “ believe , ” “ anticipate , ” “ intend , ” “ estimate , ” “ budgeted , ” “ expect , ” “ may , ” “ continue , ” “ predict , ” “ potential , ” “ project ” and similar expressions are intended to identify forward-looking statements , although not all forward-looking statements contain such identifying words . important factors that could cause actual results to differ materially from our expectations include , but are not limited to , the following risks and uncertainties : volatility in natural gas , oil and ngl prices ; future cash flows and their adequacy to maintain our ongoing operations ; liquidity , including our ability to satisfy our short- or long-term liquidity needs ; our borrowing capacity , future covenant compliance , cash flows and liquidity ; operating results ; asset disposition efforts or the timing or outcome thereof ; ongoing and prospective joint ventures , their structure and substance , and the likelihood of their finalization or the timing thereof ; the amount , nature and timing of capital expenditures , including future development costs ; timing , cost and amount of future production of oil and natural

cash flows : for the year ended december 31 , 2018 , the company generated cash from operating activities of $ 121.6 million , of which $ 23.7 million was attributable to changes in working capital . cash used for property additions was $ 266.5 million . this excluded $ 45.3 million attributable to a net increase of capital related payables and accrued costs . additionally , $ 8.7 million was paid during the year for property sale obligations related to the sale of our former bay de chene field . the company 's net borrowings under its revolving credit facility were $ 122.0 million for the year ended december 31 , 2018 . for the year ended december 31 , 2017 , the company generated cash from operating activities of $ 107.8 million , of which $ 0.7 million was attributable to changes in working capital . cash used for property additions was $ 193.0 million . this included $ 9.9 million attributable to a net increase of capital related payables and accrued costs . the company 's net payments on the credit facility were $ 125.0 million which includes the pay down on credit facility borrowings with proceeds from the second lien facility . 35 contractual commitments and obligations our contractual commitments for the next five years and thereafter are shown below as of december 31 , 2018 ( in thousands ) : replace_table_token_15_th ( 1 ) amounts shown represent fees for the minimum delivery obligations . any amount of transportation utilized in excess of the minimum will reduce future year obligations . ( 2 ) interest on our credit facility is estimated using the weighted average interest rate of 4.9 % for the quarter ended december 31 , 2018 , while interest on our second lien is estimated using libor plus 7.5 % .


 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.
     ```cash flows : for the year ended december 31 , 2018 , the company generated cash from operating activities of $ 121.6 million , of which $ 23.7 million was attributable to changes in working capital . cash used for property additions was $ 266.5 million . this excluded $ 45.3 million attributable to a net increase of capital related payables and accrued costs . additionally , $ 8.7 million was paid during the year for property sale obligations related to the sale of our former bay de chene field . the company 's net borrowings under its revolving credit facility were $ 122.0 million for the year ended december 31 , 2018 . for the year ended december 31 , 2017 , the company generated cash from operating activities of $ 107.8 million , of which $ 0.7 million was attributable to changes in working capital . cash used for property additions was $ 193.0 million . this included $ 9.9 million attributable to a net increase of capital related payables and accrued costs . the company 's net payments on the credit facility were $ 125.0 million which includes the pay down on credit facility borrowings with proceeds from the second lien facility . 35 contractual commitments and obligations our contractual commitments for the next five years and thereafter are shown below as of december 31 , 2018 ( in thousands ) : replace_table_token_15_th ( 1 ) amounts shown represent fees for the minimum delivery obligations . any amount of transportation utilized in excess of the minimum will reduce future year obligations . ( 2 ) interest on our credit facility is estimated using the weighted average interest rate of 4.9 % for the quarter ended december 31 , 2018 , while interest on our second lien is estimated using libor plus 7.5 % .
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 Suspicious Activity Report : during the fourth quarter 2018 , the company brought 12 net wells online . for the full year , the company drilled 33 net wells and completed 32 net wells . the number of wells completed is above the company 's prior guidance of 25-27 net wells . the company drilled in all areas of its portfolio during 2018 and more recently has increased its investment in liquids opportunities . in the webb county gas area , which includes fasken , the company brought 13 net wells online in 2018. the company focused on developing its high return lower eagle ford wells and strategically appraising and delineating its upper eagle ford locations . the fasken development demonstrates the company 's shift to selectively employing high intensity slickwater fracs across its portfolio . for the second half of 2018 , the company averaged a completion intensity of approximately 2,700 pounds of proppant per lateral foot and 59 barrels of fluid per lateral foot , an increase of 71 % and 161 % , respectively , from the first half of the year . the company continues to value fasken 's consistent performance , low operating expense and upside potential . in the la salle condensate area , which includes artesia , the company brought five net wells online in 2018. due to operational improvements and service price reductions , the company realized an 18 % reduction in total well cost per foot from a two-well pad that was brought online in the third quarter and a three-well pad that was brought online in the fourth quarter . all five wells were completed similarly and averaged approximately 2,400 pounds of proppant per lateral foot and 64 barrels of slickwater fluid 33 per lateral foot . based on these results , the company plans to accelerate the development of the la salle condensate area in 2019 , which it believes will increase its oil and natural gas liquids production . in the southern eagle ford gas fairway , which includes oro grande , uno mas and south awp , the company carried forward its successful delineation and appraisal across its 60,000 gross acre position . the company continues to realize operational efficiencies with its nmc 6h well costing 30 % less and being drilled 35 % faster than the average of its nmc 1h through nmc 5h wells . in addition , the company continued to add to its position through leasing and acreage trades . the company swapped 2,300 net isolated acres for 4,300 net acres contiguous to its southern eagle ford gas area . in total , this acreage trade added 35 gross drilling locations . additionally , the acreage the company traded away was stranded and would have required a significant amount of midstream capital investment in order to develop . in the mcmullen oil area , which includes north awp and where the company had not been active for several years , the team set a company record by drilling an 11,400 foot lateral in the fourth quarter with a second well on this pad also exceeding 11,000 feet . during 2018 , the company decreased its drilling cost per lateral foot on a recent three-well pad by 27 % compared to a three-well pad drilled in 2014. these developments have affected both the cost and the speed of drilling , with the team setting a spud to total depth company record of 6.8 days on the smr 21h , a 31 % reduction from the prior company record . in 2018 , the company conducted numerous initiatives to reduce capital expenditures , including moving to offline production cementing , using significant amounts of regional sand and the more widespread utilization of simultaneous-operations . offline production cementing , which allows drilling rigs to reduce walking time in-between wells , saved roughly one-half day per well on multi-well pads . in 2018 , the company pumped over 200 million pounds of regional sand , over 30 % of the total sand pumped for the year , and aims to increase this percentage in 2019 due to its compelling value proposition . the company 's use of simultaneous-operations , including flowback and drill out activities , helped decrease the time to bring a well online by two days on average . these shortened cycle times , combined with our artificial intelligence guided rate-transient analysis , allow the company to turn wells online faster and manage them better during the critical initial flowback period . 2018 cost reduction initiatives : the company continues to focus on cost reduction measures and took additional actions in 2018 to reduce operating and overhead costs . these initiatives included field staff reductions , the use of regional sand in completions , disposition of uneconomic and higher cost properties , improved utilization of existing facilities , elimination of redundant equipment , and replacement of rental equipment with company-owned equipment . as previously mentioned , the company continues to improve its process for drilling and completing wells . the company 's procurement team takes a process-oriented approach to reducing the total delivered costs of purchased services by examining costs at their most detailed level . services are commonly sourced directly from the suppliers , which has led to a significant reduction in the company 's overall lease operating expenses at the field level . for example , the company 's lease operating expenses were $ 0.26 per mcfe for the year ended december 31 , 2018 , compared to $ 0.39 per mcfe for 2017 . additionally , our significant operational control , as well as our manageable leasehold obligations , provide us the flexibility to control our costs as we transition to a development mode across our portfolio . story_separator_special_tag we compute the provision for depreciation , depletion , and amortization ( “ dd & a ” ) of oil and natural gas properties using the unit-of-production method . the costs of unproved properties not being amortized are assessed quarterly , on a property-by-property basis , to determine whether such properties have been impaired . in determining whether such costs should be impaired , we evaluate current drilling results , lease expiration dates , current oil and gas industry conditions , international economic conditions , capital availability , and available geological and geophysical information . as these factors may change from period to period , our evaluation of these factors will change . any impairment assessed is added to the cost of proved properties being amortized . the calculation of the provision for dd & a requires us to use estimates related to quantities of proved oil and natural gas reserves and estimates of the impairment of unproved properties . the estimation process for both reserves and the impairment of unproved properties is subjective , and results may change over time based on current information and industry conditions . we believe our estimates and assumptions are reasonable ; however , such estimates and assumptions are subject to a number of risks and uncertainties that may cause actual results to differ materially from such estimates . full-cost ceiling test . at the end of each quarterly reporting period , the unamortized cost of oil and natural gas properties ( including natural gas processing facilities , capitalized asset retirement obligations and deferred income taxes , and excluding the recognized asset retirement obligation liability ) is limited to the sum of the estimated future net revenues from proved properties ( excluding cash outflows from recognized asset retirement obligations , including future development and abandonment costs of wells to be drilled , using the preceding 12-months ' average price based on closing prices on the first day of each month , adjusted for price differentials , discounted at 10 % , and the lower of cost or fair value of unproved properties ) adjusted for related income tax effects ( `` ceiling test `` ) . we believe our estimates and assumptions are reasonable ; however , such estimates and assumptions are subject to a number of risks and uncertainties that may cause actual results to differ materially from such estimates . if future capital expenditures outpace future discounted net cash flows in our reserve calculations , if we have significant declines in our oil and natural gas reserves volumes ( which also reduces our estimate of discounted future net cash flows from proved oil and natural gas reserves ) or if oil or natural gas prices decline , it is possible that non-cash write-downs of our oil and natural gas properties will occur in the future . we can not control and can not predict what future prices for oil and natural gas will be , thus we can not estimate the amount or timing of any potential future non-cash write-down of our oil and natural gas properties due to decreases in oil or natural gas prices . new accounting pronouncements . in february 2016 , the fasb issued asu 2016-02 , which requires lessees to record most leases on the balance sheet . under the new guidance , lease classification as either a finance lease or an operating lease will determine how lease-related revenue and expense are recognized . the guidance is effective for fiscal years beginning after december 15 , 2018 , including interim periods within those fiscal years . the company adopted this guidance on january 1 , 2019 , with no significant impact on the company 's financial statements resulting from implementation . see note 2 to our consolidated financial statements for more information . 41 forward-looking statements this report includes forward-looking statements intended to qualify for the safe harbors from liability established by the private securities litigation reform act of 1995 , section 27a of the securities act of 1933 , as amended , and section 21e of the securities exchange act of 1934 , as amended ( the `` exchange act `` ) . these forward-looking statements are subject to a number of risks and uncertainties , many of which are beyond our control . all statements , other than statements of historical fact included in this report , regarding our strategy , future operations , financial position , estimated production levels , expected oil and natural gas pricing , estimated oil and natural gas reserves or the present value thereof , reserve increases , capital expenditures , budget , projected costs , prospects , plans and objectives of management are forward-looking statements . when used in this report , the words “ could , ” “ believe , ” “ anticipate , ” “ intend , ” “ estimate , ” “ budgeted , ” “ expect , ” “ may , ” “ continue , ” “ predict , ” “ potential , ” “ project ” and similar expressions are intended to identify forward-looking statements , although not all forward-looking statements contain such identifying words . important factors that could cause actual results to differ materially from our expectations include , but are not limited to , the following risks and uncertainties : volatility in natural gas , oil and ngl prices ; future cash flows and their adequacy to maintain our ongoing operations ; liquidity , including our ability to satisfy our short- or long-term liquidity needs ; our borrowing capacity , future covenant compliance , cash flows and liquidity ; operating results ; asset disposition efforts or the timing or outcome thereof ; ongoing and prospective joint ventures , their structure and substance , and the likelihood of their finalization or the timing thereof ; the amount , nature and timing of capital expenditures , including future development costs ; timing , cost and amount of future production of oil and natural

