the repurchase program authorizes us to make repurchases on a discretionary basis as determined by management , subject to market conditions , applicable legal requirements , available liquidity , and other appropriate factors . all or a portion of any repurchases may be made under a rule 10b5-1 plan , which would permit common units to be repurchased when we might otherwise be precluded from doing so under applicable laws . the repurchase program does not obligate us to acquire any particular amount of common units and may be modified or suspended at any time and could be terminated prior to completion . we will periodically report the number of common units repurchased . in 2018 , we repurchased a total of 128,627 common units for an aggregate cost of $ 2.0 million . the program is funded from cash on hand or through borrowings under the credit facility . any repurchased units are canceled . business environment the information below is designed to give a broad overview of the oil and natural gas business environment as it affects us . commodity prices and demand oil and natural gas prices have been historically volatile based upon the dynamics of supply and demand . the eia forecasts that wti oil prices will average approximately $ 54.79 per bbl in 2019 and $ 58.00 per bbl in 2020 . during the year ended december 31 , 2018 , the wti oil spot price reached a high of $ 77.41 per bbl on june 27 , 2018 but decreased to a low of $ 44.48 per bbl on december 27 , 2018. the eia forecasts that the henry hub spot natural gas price will average $ 2.83 per mmbtu for 2019 and $ 2.80 per mmbtu for 2020 . during the year ended december 31 , 2018 , henry hub spot natural gas prices ranged from a high of $ 6.24 per mmbtu on january 3 , 2018 to a low of $ 2.49 per mmbtu on february 16 , 2018. to manage the variability in cash flows associated with the projected sale of our oil and natural gas production , we use various derivative instruments , which have recently consisted of fixed-price swap contracts and costless collar contracts . the following table reflects commodity prices at the end of each quarter presented : replace_table_token_17_th 1 source : eia rig count as we are not the operator of record on any producing properties , drilling on our acreage is dependent upon the exploration and production companies that lease our acreage . in addition to drilling plans that we seek from our operators , we also monitor rig counts in an effort to identify existing and future leasing and drilling activity on our acreage . 52 the following table shows the rig count at the end of each quarter presented : replace_table_token_18_th 1 source : baker hughes incorporated natural gas storage a substantial portion of our revenue is derived from sales of oil production attributable to our interests ; however , the majority of our production is natural gas . natural gas prices are significantly influenced by storage levels throughout the year . accordingly , we monitor the natural gas storage reports regularly in the evaluation of our business and its outlook . historically , natural gas supply and demand fluctuates on a seasonal basis . from april to october , when the weather is warmer and natural gas demand is lower , natural gas storage levels generally increase . from november to march , storage levels typically decline as utility companies draw natural gas from storage to meet increased heating demand due to colder weather . in order to maintain sufficient storage levels for increased seasonal demand , a portion of natural gas production during the summer months must be used for storage injection . the portion of production used for storage varies from year to year depending on the demand from the previous winter and the demand for electricity used for cooling during the summer months . the eia forecasts that inventories will conclude the withdrawal season , which is the end of march 2019 , at 1,417 bcf , or 14 % below the five-year average . the eia expects inventories to build slightly over the five-year average to a projected 3,761 bcf at the end of october 2019 ; in 2020 , inventories are expected to be about 5 % higher on average than 2019 levels . the following table shows natural gas storage volumes by region at the end of each quarter presented : replace_table_token_19_th 1 source : eia 53 how we evaluate our operations we use a variety of operational and financial measures to assess our performance . among the measures considered by management are the following : volumes of oil and natural gas produced ; commodity prices including the effect of derivative instruments ; and adjusted ebitda and distributable cash flow . volumes of oil and natural gas produced in order to track and assess the performance of our assets , we monitor and analyze our production volumes from the various basins and plays that constitute our extensive asset base . we also regularly compare projected volumes to actual reported volumes and investigate unexpected variances . commodity prices factors affecting the sales price of oil and natural gas the prices we receive for oil , natural gas , and ngls vary by geographical area . the relative prices of these products are determined by the factors affecting global and regional supply and demand dynamics , such as economic conditions , production levels , availability of transportation , weather cycles , and other factors . in addition , realized prices are influenced by product quality and proximity to consuming and refining markets . any differences between realized prices and nymex prices are referred to as differentials . all our production is derived from properties located in the united states . oil . story_separator_special_tag our mineral and royalty interest oil and condensate volumes accounted for 83 % and 77 % of total oil and condensate volumes for the years ended december 31 , 2017 and 2016 , respectively . our oil and condensate volumes decreased slightly in 2017 . natural gas and natural gas liquids sales . natural gas and ngl sales increased for the year ended december 31 , 2017 as compared to 2016 . during 2017 , production from new wells in haynesville/bossier and wilcox plays combined with higher natural gas and ngl prices drove the increase in natural gas and ngl sales . mineral and royalty interest production accounted for 51 % and 59 % of our natural gas and ngl volumes for the years ended december 31 , 2017 and 2016 , respectively . 59 gain ( loss ) on commodity derivative instruments . in 2017 , we recognized $ 5.1 million of net losses from oil commodity contracts , which included cash received of $ 10.9 million , compared to $ 16.0 million of recognized net losses in 2016 . in 2017 , we recognized $ 32.0 million of net gains from natural gas commodity contracts , which included cash received of $ 4.3 million , compared to $ 20.5 million of net losses in 2016 . lease bonus and other income . when we lease our mineral interests , we generally receive an upfront cash payment , or a lease bonus . lease bonus and delay rental revenue increased for the year ended december 31 , 2017 , as compared to 2016 . in 2017 , we successfully closed several significant lease transactions in the austin chalk , bakken/three forks , haynesville/bossier and canyon lime plays as well as the anadarko and permian basins , compared to the majority of 2016 activity which came from the wolfcamp , austin chalk , and marcellus plays . operating expenses lease operating expense . lease operating expense includes normally recurring expenses associated with our non-operated working interests necessary to produce hydrocarbons from our oil and natural gas wells , as well as certain nonrecurring expenses , such as well repairs . lease operating expense decreased for the year ended december 31 , 2017 as compared to 2016 , primarily due to fewer remedial projects initiated by our operators . production costs and ad valorem taxes . production taxes include statutory amounts deducted from our production revenues by various state taxing entities . depending on the regulations of the states where the production originates , these taxes may be based on a percentage of the realized value or a fixed amount per production unit . this category also includes the costs to process and transport our production to applicable sales points . ad valorem taxes are jurisdictional taxes levied on the value of oil and natural gas minerals and reserves . rates , methods of calculating property values , and timing of payments vary between taxing authorities . for the year ended december 31 , 2017 , production and ad valorem taxes increased over the year ended december 31 , 2016 , generally as a result of higher production volumes and commodity prices . exploration expense . exploration expense typically consists of dry-hole expenses , delay rentals , and geological and geophysical costs , including seismic costs , and is expensed as incurred under the successful efforts method of accounting . exploration expense for 2017 represents costs incurred to acquire 3-d seismic information , related to our mineral and royalty interests , from a third-party service provider . depreciation , depletion , and amortization . depletion is the amount of cost basis of oil and natural gas properties attributable to the volume of hydrocarbons extracted during such period , calculated on a units-of-production basis . estimates of proved developed producing reserves are a major component of the calculation of depletion . we adjust our depletion rates semi-annually based upon the mid-year and year-end reserve reports , except when circumstances indicate that there has been a significant change in reserves or costs . depreciation , depletion , and amortization expense increased for the year ended december 31 , 2017 as compared to 2016 , primarily due to higher production volumes partially offset by lower depletion rates . impairment of oil and natural gas properties . individual categories of oil and natural gas properties are assessed periodically to determine if the net book value for these properties has been impaired . management periodically conducts an in-depth evaluation of the cost of property acquisitions , successful exploratory wells , development activities , unproved leasehold , and mineral interests to identify impairments . we did not incur any impairment in 2017 , while impairments for 2016 were $ 6.8 million . general and administrative . general and administrative expenses are costs not directly associated with the production of oil and natural gas and include the cost of employee salaries and related benefits , office expenses , and fees for professional services . for the year ended december 31 , 2017 , general and administrative expenses increased compared to 2016 . in 2017 , costs attributable to our long-term incentive plans were higher due to the achievement of certain performance targets ; we also incurred higher broker fees associated with increased acquisition activities . interest expense . interest expense increased due to higher average outstanding borrowings and higher interest rates under our credit facility , which were predominantly driven by increased acquisition of oil and natural gas properties in 2017 as compared to 2016 . 60 story_separator_special_tag style= `` line-height:120 % ; padding-top:16px ; text-indent:24px ; font-size:10pt ; `` > financing activities . cash flows provided by financing activities increased in 2017 as compared to 2016. the increase was primarily due to proceeds from the issuance of common units under our atm program and proceeds from the issuance of the series b cumulative convertible preferred units . decreased distributions to holders of the series a redeemable preferred

liquidity and capital resources overview our primary sources of liquidity are cash generated from operations , borrowings under our credit facility , and proceeds from the issuance of equity and debt . our primary uses of cash are for distributions to our unitholders and for investing in our business , specifically the acquisition of mineral and royalty interests and our selective participation on a non-operated working interest basis in the development of our oil and natural gas properties . the board of directors of our general partner has adopted a policy pursuant to which , at a minimum , distributions will be paid on each common and subordinated unit for each quarter to the extent we have sufficient cash generated from our operations after establishment of cash reserves , if any , and after we have made the required distributions to the holders of our outstanding preferred units . however , we do not have a legal or contractual obligation to pay distributions on our common and subordinated units quarterly or on any other basis , and there is no guarantee that we will pay distributions to our common and subordinated unitholders in any quarter . our minimum quarterly distribution provides the common unitholders a specified priority right to distributions over the subordinated unitholders . the priority right will cease to exist upon full conversion of the subordinated units to common units , which may occur as early as may of 2019. the board of directors of our general partner may change the foregoing distribution policy at any time and from time to time . we intend to finance our future acquisitions with cash generated from operations , borrowings from our credit facility , and proceeds from any future issuances of equity and debt .


 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.
     ```liquidity and capital resources overview our primary sources of liquidity are cash generated from operations , borrowings under our credit facility , and proceeds from the issuance of equity and debt . our primary uses of cash are for distributions to our unitholders and for investing in our business , specifically the acquisition of mineral and royalty interests and our selective participation on a non-operated working interest basis in the development of our oil and natural gas properties . the board of directors of our general partner has adopted a policy pursuant to which , at a minimum , distributions will be paid on each common and subordinated unit for each quarter to the extent we have sufficient cash generated from our operations after establishment of cash reserves , if any , and after we have made the required distributions to the holders of our outstanding preferred units . however , we do not have a legal or contractual obligation to pay distributions on our common and subordinated units quarterly or on any other basis , and there is no guarantee that we will pay distributions to our common and subordinated unitholders in any quarter . our minimum quarterly distribution provides the common unitholders a specified priority right to distributions over the subordinated unitholders . the priority right will cease to exist upon full conversion of the subordinated units to common units , which may occur as early as may of 2019. the board of directors of our general partner may change the foregoing distribution policy at any time and from time to time . we intend to finance our future acquisitions with cash generated from operations , borrowings from our credit facility , and proceeds from any future issuances of equity and debt .
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 Suspicious Activity Report : the repurchase program authorizes us to make repurchases on a discretionary basis as determined by management , subject to market conditions , applicable legal requirements , available liquidity , and other appropriate factors . all or a portion of any repurchases may be made under a rule 10b5-1 plan , which would permit common units to be repurchased when we might otherwise be precluded from doing so under applicable laws . the repurchase program does not obligate us to acquire any particular amount of common units and may be modified or suspended at any time and could be terminated prior to completion . we will periodically report the number of common units repurchased . in 2018 , we repurchased a total of 128,627 common units for an aggregate cost of $ 2.0 million . the program is funded from cash on hand or through borrowings under the credit facility . any repurchased units are canceled . business environment the information below is designed to give a broad overview of the oil and natural gas business environment as it affects us . commodity prices and demand oil and natural gas prices have been historically volatile based upon the dynamics of supply and demand . the eia forecasts that wti oil prices will average approximately $ 54.79 per bbl in 2019 and $ 58.00 per bbl in 2020 . during the year ended december 31 , 2018 , the wti oil spot price reached a high of $ 77.41 per bbl on june 27 , 2018 but decreased to a low of $ 44.48 per bbl on december 27 , 2018. the eia forecasts that the henry hub spot natural gas price will average $ 2.83 per mmbtu for 2019 and $ 2.80 per mmbtu for 2020 . during the year ended december 31 , 2018 , henry hub spot natural gas prices ranged from a high of $ 6.24 per mmbtu on january 3 , 2018 to a low of $ 2.49 per mmbtu on february 16 , 2018. to manage the variability in cash flows associated with the projected sale of our oil and natural gas production , we use various derivative instruments , which have recently consisted of fixed-price swap contracts and costless collar contracts . the following table reflects commodity prices at the end of each quarter presented : replace_table_token_17_th 1 source : eia rig count as we are not the operator of record on any producing properties , drilling on our acreage is dependent upon the exploration and production companies that lease our acreage . in addition to drilling plans that we seek from our operators , we also monitor rig counts in an effort to identify existing and future leasing and drilling activity on our acreage . 52 the following table shows the rig count at the end of each quarter presented : replace_table_token_18_th 1 source : baker hughes incorporated natural gas storage a substantial portion of our revenue is derived from sales of oil production attributable to our interests ; however , the majority of our production is natural gas . natural gas prices are significantly influenced by storage levels throughout the year . accordingly , we monitor the natural gas storage reports regularly in the evaluation of our business and its outlook . historically , natural gas supply and demand fluctuates on a seasonal basis . from april to october , when the weather is warmer and natural gas demand is lower , natural gas storage levels generally increase . from november to march , storage levels typically decline as utility companies draw natural gas from storage to meet increased heating demand due to colder weather . in order to maintain sufficient storage levels for increased seasonal demand , a portion of natural gas production during the summer months must be used for storage injection . the portion of production used for storage varies from year to year depending on the demand from the previous winter and the demand for electricity used for cooling during the summer months . the eia forecasts that inventories will conclude the withdrawal season , which is the end of march 2019 , at 1,417 bcf , or 14 % below the five-year average . the eia expects inventories to build slightly over the five-year average to a projected 3,761 bcf at the end of october 2019 ; in 2020 , inventories are expected to be about 5 % higher on average than 2019 levels . the following table shows natural gas storage volumes by region at the end of each quarter presented : replace_table_token_19_th 1 source : eia 53 how we evaluate our operations we use a variety of operational and financial measures to assess our performance . among the measures considered by management are the following : volumes of oil and natural gas produced ; commodity prices including the effect of derivative instruments ; and adjusted ebitda and distributable cash flow . volumes of oil and natural gas produced in order to track and assess the performance of our assets , we monitor and analyze our production volumes from the various basins and plays that constitute our extensive asset base . we also regularly compare projected volumes to actual reported volumes and investigate unexpected variances . commodity prices factors affecting the sales price of oil and natural gas the prices we receive for oil , natural gas , and ngls vary by geographical area . the relative prices of these products are determined by the factors affecting global and regional supply and demand dynamics , such as economic conditions , production levels , availability of transportation , weather cycles , and other factors . in addition , realized prices are influenced by product quality and proximity to consuming and refining markets . any differences between realized prices and nymex prices are referred to as differentials . all our production is derived from properties located in the united states . oil . story_separator_special_tag our mineral and royalty interest oil and condensate volumes accounted for 83 % and 77 % of total oil and condensate volumes for the years ended december 31 , 2017 and 2016 , respectively . our oil and condensate volumes decreased slightly in 2017 . natural gas and natural gas liquids sales . natural gas and ngl sales increased for the year ended december 31 , 2017 as compared to 2016 . during 2017 , production from new wells in haynesville/bossier and wilcox plays combined with higher natural gas and ngl prices drove the increase in natural gas and ngl sales . mineral and royalty interest production accounted for 51 % and 59 % of our natural gas and ngl volumes for the years ended december 31 , 2017 and 2016 , respectively . 59 gain ( loss ) on commodity derivative instruments . in 2017 , we recognized $ 5.1 million of net losses from oil commodity contracts , which included cash received of $ 10.9 million , compared to $ 16.0 million of recognized net losses in 2016 . in 2017 , we recognized $ 32.0 million of net gains from natural gas commodity contracts , which included cash received of $ 4.3 million , compared to $ 20.5 million of net losses in 2016 . lease bonus and other income . when we lease our mineral interests , we generally receive an upfront cash payment , or a lease bonus . lease bonus and delay rental revenue increased for the year ended december 31 , 2017 , as compared to 2016 . in 2017 , we successfully closed several significant lease transactions in the austin chalk , bakken/three forks , haynesville/bossier and canyon lime plays as well as the anadarko and permian basins , compared to the majority of 2016 activity which came from the wolfcamp , austin chalk , and marcellus plays . operating expenses lease operating expense . lease operating expense includes normally recurring expenses associated with our non-operated working interests necessary to produce hydrocarbons from our oil and natural gas wells , as well as certain nonrecurring expenses , such as well repairs . lease operating expense decreased for the year ended december 31 , 2017 as compared to 2016 , primarily due to fewer remedial projects initiated by our operators . production costs and ad valorem taxes . production taxes include statutory amounts deducted from our production revenues by various state taxing entities . depending on the regulations of the states where the production originates , these taxes may be based on a percentage of the realized value or a fixed amount per production unit . this category also includes the costs to process and transport our production to applicable sales points . ad valorem taxes are jurisdictional taxes levied on the value of oil and natural gas minerals and reserves . rates , methods of calculating property values , and timing of payments vary between taxing authorities . for the year ended december 31 , 2017 , production and ad valorem taxes increased over the year ended december 31 , 2016 , generally as a result of higher production volumes and commodity prices . exploration expense . exploration expense typically consists of dry-hole expenses , delay rentals , and geological and geophysical costs , including seismic costs , and is expensed as incurred under the successful efforts method of accounting . exploration expense for 2017 represents costs incurred to acquire 3-d seismic information , related to our mineral and royalty interests , from a third-party service provider . depreciation , depletion , and amortization . depletion is the amount of cost basis of oil and natural gas properties attributable to the volume of hydrocarbons extracted during such period , calculated on a units-of-production basis . estimates of proved developed producing reserves are a major component of the calculation of depletion . we adjust our depletion rates semi-annually based upon the mid-year and year-end reserve reports , except when circumstances indicate that there has been a significant change in reserves or costs . depreciation , depletion , and amortization expense increased for the year ended december 31 , 2017 as compared to 2016 , primarily due to higher production volumes partially offset by lower depletion rates . impairment of oil and natural gas properties . individual categories of oil and natural gas properties are assessed periodically to determine if the net book value for these properties has been impaired . management periodically conducts an in-depth evaluation of the cost of property acquisitions , successful exploratory wells , development activities , unproved leasehold , and mineral interests to identify impairments . we did not incur any impairment in 2017 , while impairments for 2016 were $ 6.8 million . general and administrative . general and administrative expenses are costs not directly associated with the production of oil and natural gas and include the cost of employee salaries and related benefits , office expenses , and fees for professional services . for the year ended december 31 , 2017 , general and administrative expenses increased compared to 2016 . in 2017 , costs attributable to our long-term incentive plans were higher due to the achievement of certain performance targets ; we also incurred higher broker fees associated with increased acquisition activities . interest expense . interest expense increased due to higher average outstanding borrowings and higher interest rates under our credit facility , which were predominantly driven by increased acquisition of oil and natural gas properties in 2017 as compared to 2016 . 60 story_separator_special_tag style= `` line-height:120 % ; padding-top:16px ; text-indent:24px ; font-size:10pt ; `` > financing activities . cash flows provided by financing activities increased in 2017 as compared to 2016. the increase was primarily due to proceeds from the issuance of common units under our atm program and proceeds from the issuance of the series b cumulative convertible preferred units . decreased distributions to holders of the series a redeemable preferred

