the following table sets forth our oil and gas revenues , production quantities and average prices received during the fiscal years ended march 31 : replace_table_token_8_th ( a ) after giving effect to our derivative instruments , the average sales price per bbl of oil was $ 73.48 for year ended march 31 , 2015. after giving effect to our derivative instruments , the average sales price per bbl of oil was $ 93.33 for year ended march 31 , 2014. production and exploration . production costs were $ 1,300,820 in fiscal 2015 , a 6 % increase from $ 1,231,814 in fiscal 2014. this was the result of an increase in lease operating expenses resulting from acquisitions of working interests of non-operated properties partially offset by a decrease in production taxes due to the decrease in oil and gas revenue . 28 depreciation , depletion and amortization . depreciation , depletion and amortization ( “ dd & a ” ) expense was $ 1,362,862 in fiscal 2015 , an 18 % increase from $ 1,151,482 in fiscal 2014. this was due to an increase in oil and gas production and an increase in the full cost pool partially offset by an increase in oil and gas reserves . general and administrative expenses . general and administrative expenses were $ 1,239,750 for the year ended march 31 , 2015 , a 9 % increase from $ 1,136,939 for the year ended march 31 , 2014. this was primarily due to an increase in accounting , salary and insurance expenses . interest expense . interest expense was $ 99,240 in fiscal 2015 , a 52 % increase from $ 65,387 in fiscal 2014 , due to an increase in borrowings . derivatives . derivative realized gains of $ 102,069 were recorded during the year ended march 31 , 2015 resulting from our oil swap agreement . this compared to derivative losses of $ 99,262 recorded during the year ended march 31 , 2014 ( $ 54,281 of realized losses and $ 44,981 of unrealized losses . ) income taxes . there was an income tax benefit of $ 197,499 in fiscal 2015 compared to an income tax expense of $ 11,750 in fiscal 2014. the effective tax rate for fiscal 2015 was ( 37 % ) compared to 4 % for fiscal 2014. fiscal 2014 compared to fiscal 2013 we had a net income of $ 301,113 for the year ended march 31 , 2014 compared to a net loss of $ 176,374 for the year ended march 31 , 2013. oil and gas sales . revenue from oil and gas sales was $ 3,994,295 for the year ended march 31 , 2014 , a 30 % increase from $ 3,063,707 for the year ended march 31 , 2013. this resulted from an increase in oil production and an increase in oil and gas prices partially offset by a decrease in gas production . the following table sets forth our oil and gas revenues , production quantities and average prices received during the fiscal years ended march 31 : replace_table_token_9_th ( a ) after giving effect to our derivative instruments , the average sales price per bbl of oil was $ 93.33 for year ended march 31 , 2014. we did not have a price swap agreement on our oil production for the year ended march 31 , 2013. production and exploration . production costs were $ 1,231,814 in fiscal 2014 , a 14 % increase from $ 1,082,043 in fiscal 2013. this was primarily the result of an increase in taxes related to an increase in sales , and fiscal 2014 includes twelve months of costs from the tbo wells compared to 3 months in fiscal 2013. depreciation , depletion and amortization . depreciation , depletion and amortization ( “ dd & a ” ) expense was $ 1,151,482 in fiscal 2014 , a 5 % increase from $ 1,100,425 in fiscal 2013. this was due to an increase in oil production and a decrease in gas reserves partially offset by a decrease in gas production and an increase in oil reserves . general and administrative expenses . general and administrative expenses were $ 1,136,939 for the year ended march 31 , 2014 , an 11 % increase from $ 1,028,846 for the year ended march 31 , 2013. this was primarily due to an increase in engineering services , insurance , salaries and stock option compensation expense . interest expense . interest expense was $ 65,387 in fiscal 2014 , a 21 % increase from $ 53,832 in fiscal 2013 , due to an increase in borrowings . 29 derivatives . derivative losses of $ 99,262 were recorded during the year ended march 31 , 2014. this amount reflects $ 54,281 of realized losses and $ 44,981 of unrealized losses resulting from our oil swap agreement . income taxes . there was an income tax expense of $ 11,750 in fiscal 2014 compared to an income tax benefit of $ 31,504 in fiscal 2013. the effective tax rate for fiscal 2014 was 4 % compared to ( 15 % ) for fiscal 2013. contractual obligations we have no off-balance sheet debt or unrecorded obligations and have not guaranteed the debt of any other party . the following table summarizes future payments we are obligated to make based on agreements in place as of march 31 , 2015 : replace_table_token_10_th ( 1 ) these amounts represent the balances outstanding under the bank line of credit . these repayments assume that interest will be paid on a monthly basis , no additional funds will be drawn and does not include estimated interest of $ 159,326 less than 1 year , $ 477,978 1-3 years and $ 265,544 over 3 years . story_separator_special_tag estimates of our proved reserves are based on the quantities of oil and gas that engineering and geological analysis demonstrates , with reasonable certainty , to be recoverable from established reservoirs in the future under current operating and economic parameters . our reserve estimates and the projected cash flows are derived from these reserve estimates , in accordance with sec guidelines by an independent engineering firm based in part on data provided by us . the accuracy of a reserve estimate is a function of the quality and quantity of available data , the interpretation of that data , the accuracy of various mandated economic assumptions , and the judgment of the persons preparing the estimate . estimates prepared by other third parties may be higher or lower than those included herein . because these estimates depend on many assumptions , all of which may substantially differ from future actual results , reserve estimates will be different from the quantities of oil and gas that are ultimately recovered . in addition , results of drilling , testing and production after the date of an estimate may justify material revisions to the estimate . it should not be assumed that the present value of future net cash flows is the current market value of our estimated proved reserves . in accordance with sec requirements , the cost ceiling represents the present value ( discounted at 10 % ) of net cash flows from sales of future production using the average price over the prior 12-month period . the estimates of proved reserves materially impact dd & a expense . if the estimates of proved reserves decline , the rate at which we record dd & a expense will increase , reducing future net income . such a decline may result from lower market prices , which may make it uneconomic to drill for and produce higher cost projects . 31 use of estimates . in preparing financial statements in conformity with accounting principles generally accepted in the united states of america , management is required to make informed judgments , estimates and assumptions that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period . in addition , significant estimates are used in determining year end proved oil and gas reserves . although management believes its estimates and assumptions are reasonable , actual results may differ materially from those estimates . the estimate of our oil and natural gas reserves , which is used to compute dd & a and impairment of oil and gas properties , is the most significant of the estimates and assumptions that affect these reported results . excluded costs . oil and gas properties include costs that are excluded from capitalized costs being amortized . these amounts represent investments in unproved properties and major development projects . these costs are excluded until proved reserves are found or until it is determined that the costs are impaired . all costs excluded are reviewed at least quarterly to determine if impairment has occurred . the amount of any impairment is transferred to the capitalized costs being amortized ( the dd & a pool ) . impairments transferred to the dd & a pool increase the dd & a rate . revenue recognition . we recognize crude oil and natural gas revenue from our interest in producing wells as crude oil and natural gas are sold from those wells , net of royalties . we utilize the sales method to account for gas production volume imbalances . under this method , income is recorded based on our net revenue interest in production taken for delivery . asset retirement obligations . the estimated costs of plugging , restoration and removal of facilities are accrued . the fair value of a liability for an asset 's retirement obligation is recorded in the period in which it is incurred and the corresponding cost capitalized by increasing the carrying amount of the related long-lived asset . the liability is accreted to its then present value each period , and the capitalized cost is depreciated by the units of production method . if the liability is settled for an amount other than the recorded amount , a gain or loss is recognized . for all periods presented , we have included estimated future costs of abandonment and dismantlement in the full cost amortization base and amortize these costs as a component of our depletion expense . derivatives . the company uses price swap contracts to reduce price volatility associated with certain of its oil sales . all derivative financial instruments are recorded at fair value on the balance sheet as either assets or liabilities . the company has not designated its derivative instruments as hedges for accounting purposes and , as a result , marks its derivative instruments to fair value and recognizes the realized and unrealized changes in fair value in the consolidated statements of operations under the caption “ gain ( loss ) on derivative instruments . ” gas balancing . gas imbalances are accounted for under the sales method whereby revenues are recognized based on production sold . a liability is recorded when our excess takes of natural gas volumes exceed our estimated remaining recoverable reserves ( over produced ) . no receivables are recorded for those wells where mexco has taken less than its ownership share of gas production ( under produced ) . stock-based compensation . we use the binomial option pricing model to estimate the fair value of stock based compensation expenses at grant date . this expense is recognized as compensation expense in our financial statements over the vesting period . we recognize the fair value of stock based compensation awards as wages in the consolidated statements of operations based on a graded-vesting schedule over the vesting period . accounts receivable . our accounts receivable include trade receivables

liquidity and capital resources and commitments historically , we have funded our operations , acquisitions , exploration and development expenditures from cash generated by operating activities , bank borrowings and issuance of common stock . our primary financial resource is our base of oil and gas reserves . we pledge our producing oil and gas properties to secure our revolving line of credit . we do not have any delivery commitments to provide a fixed and determinable quantity of our oil and gas under any existing contract or agreement . our long term strategy is on increasing profit margins while concentrating on obtaining reserves with low cost operations by acquiring and developing oil and gas properties with potential for long-lived production . we focus our efforts on the acquisition of royalties and working interest , non-operated properties in areas with significant development potential . for the year ending march 31 , 2015 , cash flow from operations was $ 1,176,979 , a 35 % decrease when compared to the corresponding period of fiscal 2014. net cash of $ 3,525,000 was provided by the line of credit ; net cash of $ 4,774,705 was used for activity associated with oil and gas properties and other property and equipment ; and cash of $ 57,089 was provided by settlement of derivatives . accordingly , net cash decreased $ 59,998 . 26 we had working capital of $ 166,650 as of march 31 , 2015 compared to working capital of $ 522,216 as of march 31 , 2014 , a decrease of $ 355,566 for the reasons set forth below . acquisitions effective august 2014 , mexco purchased various royalty interests for $ 200,000 covering 43 wells in 12 counties of eight states . of these oil and gas reserves , approximately 54 % are in texas and 10 % in lousiana where there is acreage available for further development by horizontal drilling and fracturing . these royalty interests are free of expenses to mexco for drilling and operations . effective september 2014 , mexco purchased various royalty interests ranging from .0018 % to 1.1 % revenue interests at a price of $ 580,000 covering approximately 580 wells in 87 counties of eight states .


 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 and commitments historically , we have funded our operations , acquisitions , exploration and development expenditures from cash generated by operating activities , bank borrowings and issuance of common stock . our primary financial resource is our base of oil and gas reserves . we pledge our producing oil and gas properties to secure our revolving line of credit . we do not have any delivery commitments to provide a fixed and determinable quantity of our oil and gas under any existing contract or agreement . our long term strategy is on increasing profit margins while concentrating on obtaining reserves with low cost operations by acquiring and developing oil and gas properties with potential for long-lived production . we focus our efforts on the acquisition of royalties and working interest , non-operated properties in areas with significant development potential . for the year ending march 31 , 2015 , cash flow from operations was $ 1,176,979 , a 35 % decrease when compared to the corresponding period of fiscal 2014. net cash of $ 3,525,000 was provided by the line of credit ; net cash of $ 4,774,705 was used for activity associated with oil and gas properties and other property and equipment ; and cash of $ 57,089 was provided by settlement of derivatives . accordingly , net cash decreased $ 59,998 . 26 we had working capital of $ 166,650 as of march 31 , 2015 compared to working capital of $ 522,216 as of march 31 , 2014 , a decrease of $ 355,566 for the reasons set forth below . acquisitions effective august 2014 , mexco purchased various royalty interests for $ 200,000 covering 43 wells in 12 counties of eight states . of these oil and gas reserves , approximately 54 % are in texas and 10 % in lousiana where there is acreage available for further development by horizontal drilling and fracturing . these royalty interests are free of expenses to mexco for drilling and operations . effective september 2014 , mexco purchased various royalty interests ranging from .0018 % to 1.1 % revenue interests at a price of $ 580,000 covering approximately 580 wells in 87 counties of eight states .
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 Suspicious Activity Report : the following table sets forth our oil and gas revenues , production quantities and average prices received during the fiscal years ended march 31 : replace_table_token_8_th ( a ) after giving effect to our derivative instruments , the average sales price per bbl of oil was $ 73.48 for year ended march 31 , 2015. after giving effect to our derivative instruments , the average sales price per bbl of oil was $ 93.33 for year ended march 31 , 2014. production and exploration . production costs were $ 1,300,820 in fiscal 2015 , a 6 % increase from $ 1,231,814 in fiscal 2014. this was the result of an increase in lease operating expenses resulting from acquisitions of working interests of non-operated properties partially offset by a decrease in production taxes due to the decrease in oil and gas revenue . 28 depreciation , depletion and amortization . depreciation , depletion and amortization ( “ dd & a ” ) expense was $ 1,362,862 in fiscal 2015 , an 18 % increase from $ 1,151,482 in fiscal 2014. this was due to an increase in oil and gas production and an increase in the full cost pool partially offset by an increase in oil and gas reserves . general and administrative expenses . general and administrative expenses were $ 1,239,750 for the year ended march 31 , 2015 , a 9 % increase from $ 1,136,939 for the year ended march 31 , 2014. this was primarily due to an increase in accounting , salary and insurance expenses . interest expense . interest expense was $ 99,240 in fiscal 2015 , a 52 % increase from $ 65,387 in fiscal 2014 , due to an increase in borrowings . derivatives . derivative realized gains of $ 102,069 were recorded during the year ended march 31 , 2015 resulting from our oil swap agreement . this compared to derivative losses of $ 99,262 recorded during the year ended march 31 , 2014 ( $ 54,281 of realized losses and $ 44,981 of unrealized losses . ) income taxes . there was an income tax benefit of $ 197,499 in fiscal 2015 compared to an income tax expense of $ 11,750 in fiscal 2014. the effective tax rate for fiscal 2015 was ( 37 % ) compared to 4 % for fiscal 2014. fiscal 2014 compared to fiscal 2013 we had a net income of $ 301,113 for the year ended march 31 , 2014 compared to a net loss of $ 176,374 for the year ended march 31 , 2013. oil and gas sales . revenue from oil and gas sales was $ 3,994,295 for the year ended march 31 , 2014 , a 30 % increase from $ 3,063,707 for the year ended march 31 , 2013. this resulted from an increase in oil production and an increase in oil and gas prices partially offset by a decrease in gas production . the following table sets forth our oil and gas revenues , production quantities and average prices received during the fiscal years ended march 31 : replace_table_token_9_th ( a ) after giving effect to our derivative instruments , the average sales price per bbl of oil was $ 93.33 for year ended march 31 , 2014. we did not have a price swap agreement on our oil production for the year ended march 31 , 2013. production and exploration . production costs were $ 1,231,814 in fiscal 2014 , a 14 % increase from $ 1,082,043 in fiscal 2013. this was primarily the result of an increase in taxes related to an increase in sales , and fiscal 2014 includes twelve months of costs from the tbo wells compared to 3 months in fiscal 2013. depreciation , depletion and amortization . depreciation , depletion and amortization ( “ dd & a ” ) expense was $ 1,151,482 in fiscal 2014 , a 5 % increase from $ 1,100,425 in fiscal 2013. this was due to an increase in oil production and a decrease in gas reserves partially offset by a decrease in gas production and an increase in oil reserves . general and administrative expenses . general and administrative expenses were $ 1,136,939 for the year ended march 31 , 2014 , an 11 % increase from $ 1,028,846 for the year ended march 31 , 2013. this was primarily due to an increase in engineering services , insurance , salaries and stock option compensation expense . interest expense . interest expense was $ 65,387 in fiscal 2014 , a 21 % increase from $ 53,832 in fiscal 2013 , due to an increase in borrowings . 29 derivatives . derivative losses of $ 99,262 were recorded during the year ended march 31 , 2014. this amount reflects $ 54,281 of realized losses and $ 44,981 of unrealized losses resulting from our oil swap agreement . income taxes . there was an income tax expense of $ 11,750 in fiscal 2014 compared to an income tax benefit of $ 31,504 in fiscal 2013. the effective tax rate for fiscal 2014 was 4 % compared to ( 15 % ) for fiscal 2013. contractual obligations we have no off-balance sheet debt or unrecorded obligations and have not guaranteed the debt of any other party . the following table summarizes future payments we are obligated to make based on agreements in place as of march 31 , 2015 : replace_table_token_10_th ( 1 ) these amounts represent the balances outstanding under the bank line of credit . these repayments assume that interest will be paid on a monthly basis , no additional funds will be drawn and does not include estimated interest of $ 159,326 less than 1 year , $ 477,978 1-3 years and $ 265,544 over 3 years . story_separator_special_tag estimates of our proved reserves are based on the quantities of oil and gas that engineering and geological analysis demonstrates , with reasonable certainty , to be recoverable from established reservoirs in the future under current operating and economic parameters . our reserve estimates and the projected cash flows are derived from these reserve estimates , in accordance with sec guidelines by an independent engineering firm based in part on data provided by us . the accuracy of a reserve estimate is a function of the quality and quantity of available data , the interpretation of that data , the accuracy of various mandated economic assumptions , and the judgment of the persons preparing the estimate . estimates prepared by other third parties may be higher or lower than those included herein . because these estimates depend on many assumptions , all of which may substantially differ from future actual results , reserve estimates will be different from the quantities of oil and gas that are ultimately recovered . in addition , results of drilling , testing and production after the date of an estimate may justify material revisions to the estimate . it should not be assumed that the present value of future net cash flows is the current market value of our estimated proved reserves . in accordance with sec requirements , the cost ceiling represents the present value ( discounted at 10 % ) of net cash flows from sales of future production using the average price over the prior 12-month period . the estimates of proved reserves materially impact dd & a expense . if the estimates of proved reserves decline , the rate at which we record dd & a expense will increase , reducing future net income . such a decline may result from lower market prices , which may make it uneconomic to drill for and produce higher cost projects . 31 use of estimates . in preparing financial statements in conformity with accounting principles generally accepted in the united states of america , management is required to make informed judgments , estimates and assumptions that affect the reported amounts of assets and liabilities as of the date of the financial statements and affect the reported amounts of revenues and expenses during the reporting period . in addition , significant estimates are used in determining year end proved oil and gas reserves . although management believes its estimates and assumptions are reasonable , actual results may differ materially from those estimates . the estimate of our oil and natural gas reserves , which is used to compute dd & a and impairment of oil and gas properties , is the most significant of the estimates and assumptions that affect these reported results . excluded costs . oil and gas properties include costs that are excluded from capitalized costs being amortized . these amounts represent investments in unproved properties and major development projects . these costs are excluded until proved reserves are found or until it is determined that the costs are impaired . all costs excluded are reviewed at least quarterly to determine if impairment has occurred . the amount of any impairment is transferred to the capitalized costs being amortized ( the dd & a pool ) . impairments transferred to the dd & a pool increase the dd & a rate . revenue recognition . we recognize crude oil and natural gas revenue from our interest in producing wells as crude oil and natural gas are sold from those wells , net of royalties . we utilize the sales method to account for gas production volume imbalances . under this method , income is recorded based on our net revenue interest in production taken for delivery . asset retirement obligations . the estimated costs of plugging , restoration and removal of facilities are accrued . the fair value of a liability for an asset 's retirement obligation is recorded in the period in which it is incurred and the corresponding cost capitalized by increasing the carrying amount of the related long-lived asset . the liability is accreted to its then present value each period , and the capitalized cost is depreciated by the units of production method . if the liability is settled for an amount other than the recorded amount , a gain or loss is recognized . for all periods presented , we have included estimated future costs of abandonment and dismantlement in the full cost amortization base and amortize these costs as a component of our depletion expense . derivatives . the company uses price swap contracts to reduce price volatility associated with certain of its oil sales . all derivative financial instruments are recorded at fair value on the balance sheet as either assets or liabilities . the company has not designated its derivative instruments as hedges for accounting purposes and , as a result , marks its derivative instruments to fair value and recognizes the realized and unrealized changes in fair value in the consolidated statements of operations under the caption “ gain ( loss ) on derivative instruments . ” gas balancing . gas imbalances are accounted for under the sales method whereby revenues are recognized based on production sold . a liability is recorded when our excess takes of natural gas volumes exceed our estimated remaining recoverable reserves ( over produced ) . no receivables are recorded for those wells where mexco has taken less than its ownership share of gas production ( under produced ) . stock-based compensation . we use the binomial option pricing model to estimate the fair value of stock based compensation expenses at grant date . this expense is recognized as compensation expense in our financial statements over the vesting period . we recognize the fair value of stock based compensation awards as wages in the consolidated statements of operations based on a graded-vesting schedule over the vesting period . accounts receivable . our accounts receivable include trade receivables

