as a result of this sale , amounts related to the robinson 's bend field assets have been reported as discontinued operations in 2013. all prior year information relating to the robinson 's bend field assets has been restated as discontinued operations , and all information reported or discussed in this annual report on form 10-k reflects the treatment of the robinson 's bend field assets as discontinued operations . we amended our reserve-based credit facility to extend its maturity to may 2017 and expand our borrowing capacity . we acquired producing oil and natural gas assets in texas and louisiana from sep i. we executed a capital plan that allowed us to expand our oil production from 2010 to 201 3 by 262.3 % and increased our proved oil reserves to 2 . 2 million barrels at december 31 , 2013. oil revenues accounted for 50.5 % of our total unhedged revenue stream in 201 3 . we have reduced our outstanding debt by 77.0 % from a high of $ 220.0 million in 2009 to $ 50.7 million . in 2014 , we intend to focus our efforts on developing oil opportunities on our existing properties in the mid-continent region and in texas and louisiana , while pursuing opportunities to acquire additional properties in our operating area or merger and acquisition opportunities that could lead to enhanced unitholder value . for additional information on our business plan for 2014 , refer below to “ outlook . ” significant operational factors in 2013 realized prices . our average realized price for the twelve months ended december 31 , 2013 , including hedge settlements , was $ 7.49 per mcfe and $ 5.56 per mcfe excluding hedge settlements . after deducting the cost of sales associated with third party gathering , our average realized prices were $ 7.32 per mcfe including hedge settlements and $ 5.39 per mcfe excluding hedge settlements . production . our production for the twelve months ended december 31 , 2013 , was approxi mately 8.2 bcfe , or an average of 22,433 mcfe per day compared with approximately 8.2 bcfe , or an average of 22,418 mcfe per day for the twelve months ended december 31 , 2012. capital expenditures and drilling results . for the twelve months ended december 31 , 2013 , we spent approximately $ 35.9 million in cash capital expenditures , consisting of $ 15.3 million in development expenditures focused on oil completions in the cherokee basin , $ 0.1 million to acquire certain additional natural gas wells in the cherokee basin , $ 20.1 million to acquire sep i properties , and $ 0.4 million in development expenditures focused on sep i acquired properties . we c ompleted 64 net wells and 15 net recompletions during 2013 and had 6 net wells and recompletions in progress at december 31 , 2013. oil and natural gas reserves . our total year end 2013 proved reserves were 91.3 bcfe , which is 47.7 bcfe higher than our year end 2012 proved reserves of 43.6 bcfe , due to the sale of our black warrior basin assets , partially offset by higher sec natural gas and oil prices and the purchase of the sep i properties in texas and louisiana . our 2013 estimates of proved reserves were prepared in accordance with the sec rules for oil and natural gas reserve reporting that require our proved reserves to be calculated using an average of the nymex spot prices for the sales of oil and natural gas on the first calendar day of each month of the year , adjusted for basis differentials . we increased our proved oil reserves from 1.1 mbbl to 2 . 2 mbbl or by 100 % by focusing our capital programs on drilling locations that have oil completions . any of our locations that are scheduled to be drilled after five years are classified as probable or possible reserves if they are economic . our reserves are 85 % natural gas and are sensitive to lower sec-required prices for natural gas and basis differentials in the mid-continent region . the 12-month average sec-required price used to prepare our reserve report was $ 3.71 per mcf . although we utilize swaps and basis swaps to mitigate commodity price risk and basis differentials , these derivatives are not used when preparing our reserve report based on sec rules . we do not use the sec-required 12-month average price to make investment or drilling decisions . instead , we use estimates of expected future observable market prices for oil and natural gas . 35 story_separator_special_tag for the same period in 2012. for the year ended december 31 , 2013 , production taxes increased $ 1.0 million , or 58.0 % , to $ 2.6 million , compared to production taxes of $ 1.6 million for the same period in 2012. this increase is primarily the result of higher market prices for natural gas and oil in 2013. cost of sales . for the year ended dec ember 31 , 2013 , cost of sales in creased by $ 0.2 million , or 12.0 % , to $ 1.5 million , compared to $ 1.3 million for the same period in 2012. general and administrative expenses . general and administrative expenses include the costs of our employees , related benefits , professional fees , general business and public company expenses , and any other administrative costs not directly associated with field operations . general and administrative expenses increased $ 6.5 million , or 41.1 % , to $ 22.2 million for the y ear ended december 31 , 2013 , compared to $ 15 . story_separator_special_tag we have the ability to pay distributions to unitholders from available cash , including cash from borrowings under the reserve-based credit facility , as long as no event of default exists and provided that no distributions to unitholders may be made if the borrowings outstanding , net of available cash , under the reserve-based credit facility exceed 90 % of our borrowing base , after giving effect to the proposed distribution . our available cash is reduced by any cash reserves established by our board of managers for the proper conduct of our business and the payment of fees and expenses . as of december 31 , 2013 , we were restricted from paying distributions to unitholders as we had no available cash ( taking into account the cash reserves set by our board of managers for the proper conduct of our business ) from which to pay distributions . the reserve-based credit facility permits us to hedge our projected monthly production , provided that ( a ) for the immediately ensuing twelve-month period , the volumes of production hedged in any month may not exceed our reasonable business judgment of the production for such month consistent with the application of petroleum engineering methodologies for estimating proved developed producing reserves based on the then-current strip pricing ( provided that such projection shall not be more than 115 % of the proved developed producing reserves forecast for the same period derived from the most recent reserve report of our petroleum engineers using the then strip pricing ) , and ( b ) for the period beyond twelve months , the volumes of production hedged in any month may not exceed the reasonably anticipated projected production from proved developed producing reserves estimated by our petroleum engineers . the reserve-based credit facility also permits us to hedge the interest rate on up to 90 % of the then-outstanding principal amounts of our indebtedness for borrowed money . the reserve-based credit facility contains no covenants related to postrock 's , exelon 's or sog 's ownership in us . at december 31 , 2013 , we were in compliance with the financial covenant ratios contained in our reserve-based credit facility . we monitor compliance on an ongoing basis . as of december 31 , 2013 , our actual total net debt to actual adjusted ebitda ratio was 2.6 to 1.0 , compared to a required ratio of not greater than 3.5 to 1.0 ; our actual ratio of consolidated current assets to consolidated current liabilities was 1 .3 to 1.0 , compared to a required ratio of not less than 1.0 to 1.0 ; and our actual adjusted ebitda to cash interest expense ratio was 9.3 to 1.0 , compared to a required ratio of not less than 2.5 to 1.0. if we are unable to remain in compliance with the financial covenants contained in our reserve-based credit facility or maintain the required ratios discussed above , the lenders could call an event of default and accelerate the outstanding debt under the terms of our reserve-based credit facility , such that our outstanding debt could become then due and payable . we may request waivers of compliance from the violated financial covenants from the lenders , but there is no assurance that such waivers would be granted . the amount available for borrowing at any one time under the reserve-based credit facility is limited to the borrowing base for our oil and natural gas properties . as of december 31 , 2013 , our borrowing base was $ 55.0 million . the borrowing base is re-determined semi-annually , and may be re-determined at our request more frequently and by the lenders , in their sole discretion , based on reserve reports as prepared by petroleum engineers , using , among other things , the oil and natural gas prices prevailing at such time . outstanding borrowings in excess of our borrowing base must be repaid or we must pledge other oil and natural gas properties as additional collateral . we may elect to pay any borrowing base deficiency in three equal monthly installments such that the deficiency is eliminated in a period of three months . any increase in our borrowing base must be approved by all of the lenders . 41 discontinued operations we view periodic reserve sales as an opportunity to capture value , reduce reserve and price risk , in addition to being a source of funds for potentially higher rate of return on oil and natural gas exploration investments . we believe these periodic oil and natural gas property sales are an efficient strategy to meet our cash and liquidity needs by providing us with immediate cash , which would otherwise take years to realize through the production lives of the fields sold . we have in the past and could in the future continue to rely on the sales of assets to generate cash to fund our exploration investments and operations . these sales bring forward future revenues and cash flows , but our longer term liquidity could be impaired to the extent our exploration efforts in our remaining properties are not successful in generating new discoveries , production , revenues and cash flows . additionally , our longer term liquidity could be impaired due to the decrease in our inventory of producing properties that could be sold in future periods . further , as a result of our recent property sale , our ability to collateralize bank borrowings is reduced , which increases our dependence on more expensive mezzanine debt and potential equity sales . the availability of such funds will depend upon prevailing market conditions and other factors over which we have no control , as well as our financial condition and results of operations . cash flow from operations our net cash flow provided by operating activities for the year ended december 31 , 2013 , was $ 15.2 million , compared to net cash flow

reduction of outstanding debt . through december 31 , 2013 , we reduced our outstanding debt from a high of $ 220.0 million in 2009 to $ 50.7 million , or by 77.0 % , which currently leaves us with $ 4.3 million of funds available for borrowing under our reserve-based credit facility which matures on may 30 , 2017 . hedging activities . all of our derivatives are accounted for as mark-to-market activities . for the twelve months ended december 31 , 2013 , the non-cash mark-to-market loss was approximately $ 17.3 million , compared to non-cash mark-to-market loss of $ 8.7 million for the same period in 2012. we experience earnings volatility as a result of using the mark-to-market accounting method for our open derivative positions . this accounting treatment can cause extreme earnings volatility as the positions for future oil and natural gas production or interest rates are marked-to-market . these non-cash gains or losses are included in our current statement of operations until the derivatives are cash settled as the commodities are produced and sold or interest payments are made . further detail of our open derivative positions and their accounting treatment is outlined below in “ —cash flow from operations-open commodity hedge positions ” and “ critical accounting polices and estimates-hedging activities. ” operating expense reductions . we are currently implementing strategies to lower our operating expenses . for the year ended december 31 , 2013 , we have reduced our lease operating expenses by 2.8 % , compared to the same period in 2012 and reduced our general and administrative expenses by 10 % when not including litigation and accrued settlement charges in the fourth quarter of 2013. significant market factors postrock as an “ interested unitholder ” . in 2011 , postrock acquired certain of our class a and class b common units in two separate transactions which represented a 21.3 % ownership interest in us as of december 31 , 2013. approval of the purchase of these units was neither required nor given by our board of managers or conflicts committee .


 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.
     ```reduction of outstanding debt . through december 31 , 2013 , we reduced our outstanding debt from a high of $ 220.0 million in 2009 to $ 50.7 million , or by 77.0 % , which currently leaves us with $ 4.3 million of funds available for borrowing under our reserve-based credit facility which matures on may 30 , 2017 . hedging activities . all of our derivatives are accounted for as mark-to-market activities . for the twelve months ended december 31 , 2013 , the non-cash mark-to-market loss was approximately $ 17.3 million , compared to non-cash mark-to-market loss of $ 8.7 million for the same period in 2012. we experience earnings volatility as a result of using the mark-to-market accounting method for our open derivative positions . this accounting treatment can cause extreme earnings volatility as the positions for future oil and natural gas production or interest rates are marked-to-market . these non-cash gains or losses are included in our current statement of operations until the derivatives are cash settled as the commodities are produced and sold or interest payments are made . further detail of our open derivative positions and their accounting treatment is outlined below in “ —cash flow from operations-open commodity hedge positions ” and “ critical accounting polices and estimates-hedging activities. ” operating expense reductions . we are currently implementing strategies to lower our operating expenses . for the year ended december 31 , 2013 , we have reduced our lease operating expenses by 2.8 % , compared to the same period in 2012 and reduced our general and administrative expenses by 10 % when not including litigation and accrued settlement charges in the fourth quarter of 2013. significant market factors postrock as an “ interested unitholder ” . in 2011 , postrock acquired certain of our class a and class b common units in two separate transactions which represented a 21.3 % ownership interest in us as of december 31 , 2013. approval of the purchase of these units was neither required nor given by our board of managers or conflicts committee .
```    
 Suspicious Activity Report : as a result of this sale , amounts related to the robinson 's bend field assets have been reported as discontinued operations in 2013. all prior year information relating to the robinson 's bend field assets has been restated as discontinued operations , and all information reported or discussed in this annual report on form 10-k reflects the treatment of the robinson 's bend field assets as discontinued operations . we amended our reserve-based credit facility to extend its maturity to may 2017 and expand our borrowing capacity . we acquired producing oil and natural gas assets in texas and louisiana from sep i. we executed a capital plan that allowed us to expand our oil production from 2010 to 201 3 by 262.3 % and increased our proved oil reserves to 2 . 2 million barrels at december 31 , 2013. oil revenues accounted for 50.5 % of our total unhedged revenue stream in 201 3 . we have reduced our outstanding debt by 77.0 % from a high of $ 220.0 million in 2009 to $ 50.7 million . in 2014 , we intend to focus our efforts on developing oil opportunities on our existing properties in the mid-continent region and in texas and louisiana , while pursuing opportunities to acquire additional properties in our operating area or merger and acquisition opportunities that could lead to enhanced unitholder value . for additional information on our business plan for 2014 , refer below to “ outlook . ” significant operational factors in 2013 realized prices . our average realized price for the twelve months ended december 31 , 2013 , including hedge settlements , was $ 7.49 per mcfe and $ 5.56 per mcfe excluding hedge settlements . after deducting the cost of sales associated with third party gathering , our average realized prices were $ 7.32 per mcfe including hedge settlements and $ 5.39 per mcfe excluding hedge settlements . production . our production for the twelve months ended december 31 , 2013 , was approxi mately 8.2 bcfe , or an average of 22,433 mcfe per day compared with approximately 8.2 bcfe , or an average of 22,418 mcfe per day for the twelve months ended december 31 , 2012. capital expenditures and drilling results . for the twelve months ended december 31 , 2013 , we spent approximately $ 35.9 million in cash capital expenditures , consisting of $ 15.3 million in development expenditures focused on oil completions in the cherokee basin , $ 0.1 million to acquire certain additional natural gas wells in the cherokee basin , $ 20.1 million to acquire sep i properties , and $ 0.4 million in development expenditures focused on sep i acquired properties . we c ompleted 64 net wells and 15 net recompletions during 2013 and had 6 net wells and recompletions in progress at december 31 , 2013. oil and natural gas reserves . our total year end 2013 proved reserves were 91.3 bcfe , which is 47.7 bcfe higher than our year end 2012 proved reserves of 43.6 bcfe , due to the sale of our black warrior basin assets , partially offset by higher sec natural gas and oil prices and the purchase of the sep i properties in texas and louisiana . our 2013 estimates of proved reserves were prepared in accordance with the sec rules for oil and natural gas reserve reporting that require our proved reserves to be calculated using an average of the nymex spot prices for the sales of oil and natural gas on the first calendar day of each month of the year , adjusted for basis differentials . we increased our proved oil reserves from 1.1 mbbl to 2 . 2 mbbl or by 100 % by focusing our capital programs on drilling locations that have oil completions . any of our locations that are scheduled to be drilled after five years are classified as probable or possible reserves if they are economic . our reserves are 85 % natural gas and are sensitive to lower sec-required prices for natural gas and basis differentials in the mid-continent region . the 12-month average sec-required price used to prepare our reserve report was $ 3.71 per mcf . although we utilize swaps and basis swaps to mitigate commodity price risk and basis differentials , these derivatives are not used when preparing our reserve report based on sec rules . we do not use the sec-required 12-month average price to make investment or drilling decisions . instead , we use estimates of expected future observable market prices for oil and natural gas . 35 story_separator_special_tag for the same period in 2012. for the year ended december 31 , 2013 , production taxes increased $ 1.0 million , or 58.0 % , to $ 2.6 million , compared to production taxes of $ 1.6 million for the same period in 2012. this increase is primarily the result of higher market prices for natural gas and oil in 2013. cost of sales . for the year ended dec ember 31 , 2013 , cost of sales in creased by $ 0.2 million , or 12.0 % , to $ 1.5 million , compared to $ 1.3 million for the same period in 2012. general and administrative expenses . general and administrative expenses include the costs of our employees , related benefits , professional fees , general business and public company expenses , and any other administrative costs not directly associated with field operations . general and administrative expenses increased $ 6.5 million , or 41.1 % , to $ 22.2 million for the y ear ended december 31 , 2013 , compared to $ 15 . story_separator_special_tag we have the ability to pay distributions to unitholders from available cash , including cash from borrowings under the reserve-based credit facility , as long as no event of default exists and provided that no distributions to unitholders may be made if the borrowings outstanding , net of available cash , under the reserve-based credit facility exceed 90 % of our borrowing base , after giving effect to the proposed distribution . our available cash is reduced by any cash reserves established by our board of managers for the proper conduct of our business and the payment of fees and expenses . as of december 31 , 2013 , we were restricted from paying distributions to unitholders as we had no available cash ( taking into account the cash reserves set by our board of managers for the proper conduct of our business ) from which to pay distributions . the reserve-based credit facility permits us to hedge our projected monthly production , provided that ( a ) for the immediately ensuing twelve-month period , the volumes of production hedged in any month may not exceed our reasonable business judgment of the production for such month consistent with the application of petroleum engineering methodologies for estimating proved developed producing reserves based on the then-current strip pricing ( provided that such projection shall not be more than 115 % of the proved developed producing reserves forecast for the same period derived from the most recent reserve report of our petroleum engineers using the then strip pricing ) , and ( b ) for the period beyond twelve months , the volumes of production hedged in any month may not exceed the reasonably anticipated projected production from proved developed producing reserves estimated by our petroleum engineers . the reserve-based credit facility also permits us to hedge the interest rate on up to 90 % of the then-outstanding principal amounts of our indebtedness for borrowed money . the reserve-based credit facility contains no covenants related to postrock 's , exelon 's or sog 's ownership in us . at december 31 , 2013 , we were in compliance with the financial covenant ratios contained in our reserve-based credit facility . we monitor compliance on an ongoing basis . as of december 31 , 2013 , our actual total net debt to actual adjusted ebitda ratio was 2.6 to 1.0 , compared to a required ratio of not greater than 3.5 to 1.0 ; our actual ratio of consolidated current assets to consolidated current liabilities was 1 .3 to 1.0 , compared to a required ratio of not less than 1.0 to 1.0 ; and our actual adjusted ebitda to cash interest expense ratio was 9.3 to 1.0 , compared to a required ratio of not less than 2.5 to 1.0. if we are unable to remain in compliance with the financial covenants contained in our reserve-based credit facility or maintain the required ratios discussed above , the lenders could call an event of default and accelerate the outstanding debt under the terms of our reserve-based credit facility , such that our outstanding debt could become then due and payable . we may request waivers of compliance from the violated financial covenants from the lenders , but there is no assurance that such waivers would be granted . the amount available for borrowing at any one time under the reserve-based credit facility is limited to the borrowing base for our oil and natural gas properties . as of december 31 , 2013 , our borrowing base was $ 55.0 million . the borrowing base is re-determined semi-annually , and may be re-determined at our request more frequently and by the lenders , in their sole discretion , based on reserve reports as prepared by petroleum engineers , using , among other things , the oil and natural gas prices prevailing at such time . outstanding borrowings in excess of our borrowing base must be repaid or we must pledge other oil and natural gas properties as additional collateral . we may elect to pay any borrowing base deficiency in three equal monthly installments such that the deficiency is eliminated in a period of three months . any increase in our borrowing base must be approved by all of the lenders . 41 discontinued operations we view periodic reserve sales as an opportunity to capture value , reduce reserve and price risk , in addition to being a source of funds for potentially higher rate of return on oil and natural gas exploration investments . we believe these periodic oil and natural gas property sales are an efficient strategy to meet our cash and liquidity needs by providing us with immediate cash , which would otherwise take years to realize through the production lives of the fields sold . we have in the past and could in the future continue to rely on the sales of assets to generate cash to fund our exploration investments and operations . these sales bring forward future revenues and cash flows , but our longer term liquidity could be impaired to the extent our exploration efforts in our remaining properties are not successful in generating new discoveries , production , revenues and cash flows . additionally , our longer term liquidity could be impaired due to the decrease in our inventory of producing properties that could be sold in future periods . further , as a result of our recent property sale , our ability to collateralize bank borrowings is reduced , which increases our dependence on more expensive mezzanine debt and potential equity sales . the availability of such funds will depend upon prevailing market conditions and other factors over which we have no control , as well as our financial condition and results of operations . cash flow from operations our net cash flow provided by operating activities for the year ended december 31 , 2013 , was $ 15.2 million , compared to net cash flow

