in early 2016 , we determined that additional development drilling is uneconomic at then current commodity prices . in january 2016 , we began demobilizing our contracted drilling rig and did not drill any wells in 2016 on the etame marin block . in june 2016 , we reached an agreement with the drilling contractor to pay $ 5.1 million net to vaalco 's interest for unused rig days under the contract . we paid this amount , plus the demobilization charges , in seven equal monthly installments beginning in july 2016. although prices continue to be low , if oil and natural gas prices continue at current levels ( and holding other variables constant ) , we believe that through march 31 , 2018 we will generate cash flows sufficient to cover our operating expenses . 2016 highlights as further discussed in notes 5 and 6 to the financial statements : · we recorded impairments on our proved oil and natural gas properties in periods prior to 2016. it is difficult to predict with reasonable certainty the amount of expected future impairments given the many factors impacting the calculation including , but not limited to , future pricing , operating costs , drilling and completion costs , and reserve additions and adjustments . our impairment calculations have been based upon reserve economics using forecasted future prices , adjusted for specifics related to our production . we may experience additional write-downs in the future . if the per barrel prices used in the impairment calculation made as of december 31 , 2016 had been $ 10.00 lower , there would still have been no impairment charges incurred for 2016. given the uncertainty associated with the factors used in these calculations , these estimates should not be construed as indicative of our future financial results . · o n september 30 , 2016 , we notified sonangol p & p , our joint venture partner in block 5 , that we were withdrawing from the block 5 joint operating agreement effective october 31 , 2016. in addition to the withdrawal , we have taken actions to begin closing our office in angola and do not intend to conduct future activities in angola . as a result of this strategic shift , the angola segment has been reflected as discontinued in our f inancial s tatements . · o n march 14 , 2016 , we received payment of $ 19.0 million from sonangol p & p for the full amount owed us as of december 31 , 2015 , including the $ 7.6 million of pre-assignment costs . the $ 7.6 million recovery is reflected in the “ bad debt expense and other ” line of our summarized results of discontinued operations . default interest of $ 3.2 million was received and is shown in the interest income line of our summarized results of discontinued operations . while this payment improved our liquidity in the short-term , we are continuing to pursue alternatives for increasing our liquidity . · in november 2016 , opec reached a decision to reduce its level of production effective january 1 , 2017. gabon , as a member of opec , agreed to reduce its production by up to 9,000 bbl per day . as a result , we expect our production reduction to be approximately 548.9 bbl per day ( 170.5 bbl per day net to vaalco ) . we anticipate being able to reduce our production by these amounts by delaying certain workover activities until later in 2017 and by natural production declines . · o n november 22 , 2016 , we closed on the purchase of an additional 2.98 % working interest ( 3.23 % p articipating interest ) in the etame marin block located offshore th e republic of gabon from sojitz , which represents all interest owned by sojitz in the concession . the acquisition has an effective date of august 1 , 2016. the transaction was funded from our cash on hand . · i n december 2016 , we completed the sale of our interests in two wells in the hefley field in north texas for $ 8 3 0,000 resulting in a minimal loss , and on october 17 , 2016 , we signed a letter of intent to sell our interests in the east poplar dome field in montana for $ 250,000. as we had fully impaired the book value for the east poplar dome assets , we expect a small gain if the sale is completed . as a result of signing the letter of intent to sell our interests in the two wells in north texas in q3 2016 , we performed an impairment test and determined that a $ 0.1 million impairment was required during the third quarter . as of december 31 , 2016 , no proved reserves remained in the united states . u.s. sales volumes for the year ended december 31 , 2016 were 24 mboe . 35 discontinued operations-angola in november 2006 , we signed a production sharing contract for block 5 offshore angola . the four year primary term , with an optional three year extension , awarded us exploration rights to 1.4 million acres offshore central angola , with a commitment to drill two exploratory wells . in october 2014 , we entered into the subsequent exploration phase ( “ sep ” ) which extended the exploration period to november 30 , 2017 and required us and our partner to drill two additional exploration wells . our working interest is 40 % and we carry the angolan national oil company , sonangol p & p , for 10 % of the work program . story_separator_special_tag as operator of the etame marin and mutamba iroru blocks in gabon , we enter into project related activities on behalf of our working interest partners . we generally obtain advances from partners prior to significant funding commitments . we currently sell our crude oil production from gabon under a term contract that ends in january 201 8 . pric ing under the contract is based upon an average of dated brent in the month of lifting , adjusted for location and market factors . ﻿ contractual obligations cash obligations the table below provides aggregated information on our net share of story_separator_special_tag . the revenue change s between the years ended december 31 , 2016 and 2015 identified as related to changes in price or volume are shown in the table below : ﻿ ﻿ ﻿ ( in thousands ) price $ ( 11,518 ) volume ( 9,409 ) other 266 ﻿ $ ( 20,661 ) ﻿ 40 the table below shows net production , sales volumes and realized prices for both years . ﻿ ﻿ ﻿ year ended december 31 , ﻿ 2016 2015 gabon net oil production ( mbbls ) 1,515 1,656 ﻿ gabon net oil sales ( mbbls ) 1,485 1,679 u.s. net oil sales ( mbbls ) 3 3 net oil sales ( mbbls ) 1,488 1,682 net natural gas sales ( mmcf ) 124 181 net oil equivalents ( mboe ) 1,509 1,712 ﻿ average realized oil price ( $ /bbl ) $ 40.13 $ 47.85 average realized natural gas price ( $ /mcf ) 1.95 2.21 weighted average realized price ( $ /boe ) 39.62 47.24 average dated brent spot * ( $ /bbl ) 43.67 52.32 * average of daily dated brent spot prices posted on the u.s. energy information administration website . crude oil sales are a function of the number and size of crude oil liftings from the fpso , and thus crude oil sales do not always coincide with volumes produced in any given period . we made 12 and 11 liftings in the years ended december 31 , 2016 and 2015 , respectively . our share of oil inventory aboard the fpso , excluding royalty barrels , was approximately 46,700 and 34,000 barrels at december 31 , 2016 and 2015 , respectively . production expenses decreased $ 2 . 5 million in 201 6 compared to 2015. production expenses included workover costs to replace esps which were $ 6.8 million in 2016 and $ 4.2 million in 2015 . 2015 production expenses are higher because they include $ 1.9 million related to studies to evaluate solutions for a centralized processing facility to remove h 2 s from the sour production on the block . excluding workovers and h 2 s studies , the overall decrease in production expense was $ 3 . 2 million , which reflects some success in ongoing cost cutting efforts . exploration expense was minimal in 201 6 compared to $ 10.4 million in 2015. during 2015 , we charged to dry hole costs $ 9.2 million of exploratory well costs incurred in 2012 related to the n'gongui no . 2 discovery that had been capitalized pending the determination of proved reserves . also in 2015 , we recorded impairments of $ 1.3 million related to undeveloped leasehold costs associated with poplar dome in the u.s. the following table shows exploration expense in detail . ﻿ replace_table_token_13_th depreciation , depletion and amortization ( “ dd & a ” ) expenses decreased $ 2 6.1 million in 2016 compared to 2015. dd & a per boe rates were lower in 2016 reflecting the impact of impairments in 2015 , particularly the $ 52.1 million impairment made in the fourth quarter of 2015. general and administrative expenses decreased $ 2 . 7 million in 201 6 compared to 2015. t his is primarily a result of a $ 3.6 million decrease in stock-based compensation expense reflecting forfeitures related to employee departures . in addition , we took steps beginning in 2015 to reduce overall general and administrative costs , with decreases realized in personnel costs , services and various other cost categories . however , the amount of overhead we we re able to recover from our partners in 2016 has decreased and more than offset the benefits from reductions in personnel and other costs . under our operating agreements the amount of overhead recoverable is larger when capital spending is higher , as it was in 2015 with the development program in gabon and the exploratory drilling in angola . impairment of proved properties is discussed in detail in note 6 to the financial statements . declining forecasted oil prices in 2015 caused us to record an impairment of $ 81.3 million . other operating loss , net in 2016 includes $ 2 .8 million , net to vaalco , of expense associated with the demobilization , $ 5.1 million related to the early release of the contracted drilling rig and $ 1 . 0 million accrued for certain payroll taxes in gabon which were not paid pertaining to labor provided to us over a number of years by a third-party contractor . in june 2016 , we reached an agreement with 41 the drilling contractor to pay less than our originally estimated maximum day rate , plus demobilization costs , in seven equal monthly installments beginning in july 2016. general and administrative related to shareholder matters for 2016 and 2015 reflects costs incurred related to shareholder litigation that was settled in 2016. for 2016 , the amounts also include the offsetting insurance proceeds related to these matters . bad debt expense and other for both the years ended december 31 , 2016 and 2015 includes bad debt expense related to value added tax ( “ vat ” ) which the government of gabon is required to reimburse but has not yet paid . other operating income ( loss ) , net decreased by $ 0.8

cash obligations and commitments at december 31 , 201 6 : ﻿ replace_table_token_12_th ( 1 ) see complete discussion of the facility above under “ — credit facility ” . interest estimated to be paid on the ifc credit facility in each of 201 7 through 2019 is $ 0 . 8 million , $ 0 . 4 million and $ 0 . 1 million . ( 2 ) included in these figures is our net share of charter payments for the fpso used on the etame marin block . see “ fpso charter ” in note 9 to the financial statements and “ —rig commitment ” below for further information . ( 3 ) represents final payment to be made for unused rig days and demobilization charges for a rig released under a long-term drilling rig contract . see “ rig commitment ” in note 9 to the financial statements for further information about the long-term drilling rig contract . ( 4 ) see “ abandonment funding ” in note 9 to the financial statements for further information . impairment in 2014 , we recorded an impairment loss of $ 98.3 million to write down our investment in certain fields comprising the etame marin block to fair value as a result of the declines in the forecasted oil prices used in the impairment testing and calculation . we recorded impairments totaling $ 81.3 million in 2015 to write down our investment in all fields comprising the etame marin block , as well as various u.s. fields , primarily as a result of lower forecasted oil prices as well as higher costs for planned development wells used in the impairment evaluation . impairments of proved properties were $ 0.1 million in the year ended december 31 , 2016 ( a ll related to u.s. properties ) . see “ — results of operations ” below and note 6 to the financial statements for further discussion of impairments .


 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 obligations and commitments at december 31 , 201 6 : ﻿ replace_table_token_12_th ( 1 ) see complete discussion of the facility above under “ — credit facility ” . interest estimated to be paid on the ifc credit facility in each of 201 7 through 2019 is $ 0 . 8 million , $ 0 . 4 million and $ 0 . 1 million . ( 2 ) included in these figures is our net share of charter payments for the fpso used on the etame marin block . see “ fpso charter ” in note 9 to the financial statements and “ —rig commitment ” below for further information . ( 3 ) represents final payment to be made for unused rig days and demobilization charges for a rig released under a long-term drilling rig contract . see “ rig commitment ” in note 9 to the financial statements for further information about the long-term drilling rig contract . ( 4 ) see “ abandonment funding ” in note 9 to the financial statements for further information . impairment in 2014 , we recorded an impairment loss of $ 98.3 million to write down our investment in certain fields comprising the etame marin block to fair value as a result of the declines in the forecasted oil prices used in the impairment testing and calculation . we recorded impairments totaling $ 81.3 million in 2015 to write down our investment in all fields comprising the etame marin block , as well as various u.s. fields , primarily as a result of lower forecasted oil prices as well as higher costs for planned development wells used in the impairment evaluation . impairments of proved properties were $ 0.1 million in the year ended december 31 , 2016 ( a ll related to u.s. properties ) . see “ — results of operations ” below and note 6 to the financial statements for further discussion of impairments .
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 Suspicious Activity Report : in early 2016 , we determined that additional development drilling is uneconomic at then current commodity prices . in january 2016 , we began demobilizing our contracted drilling rig and did not drill any wells in 2016 on the etame marin block . in june 2016 , we reached an agreement with the drilling contractor to pay $ 5.1 million net to vaalco 's interest for unused rig days under the contract . we paid this amount , plus the demobilization charges , in seven equal monthly installments beginning in july 2016. although prices continue to be low , if oil and natural gas prices continue at current levels ( and holding other variables constant ) , we believe that through march 31 , 2018 we will generate cash flows sufficient to cover our operating expenses . 2016 highlights as further discussed in notes 5 and 6 to the financial statements : · we recorded impairments on our proved oil and natural gas properties in periods prior to 2016. it is difficult to predict with reasonable certainty the amount of expected future impairments given the many factors impacting the calculation including , but not limited to , future pricing , operating costs , drilling and completion costs , and reserve additions and adjustments . our impairment calculations have been based upon reserve economics using forecasted future prices , adjusted for specifics related to our production . we may experience additional write-downs in the future . if the per barrel prices used in the impairment calculation made as of december 31 , 2016 had been $ 10.00 lower , there would still have been no impairment charges incurred for 2016. given the uncertainty associated with the factors used in these calculations , these estimates should not be construed as indicative of our future financial results . · o n september 30 , 2016 , we notified sonangol p & p , our joint venture partner in block 5 , that we were withdrawing from the block 5 joint operating agreement effective october 31 , 2016. in addition to the withdrawal , we have taken actions to begin closing our office in angola and do not intend to conduct future activities in angola . as a result of this strategic shift , the angola segment has been reflected as discontinued in our f inancial s tatements . · o n march 14 , 2016 , we received payment of $ 19.0 million from sonangol p & p for the full amount owed us as of december 31 , 2015 , including the $ 7.6 million of pre-assignment costs . the $ 7.6 million recovery is reflected in the “ bad debt expense and other ” line of our summarized results of discontinued operations . default interest of $ 3.2 million was received and is shown in the interest income line of our summarized results of discontinued operations . while this payment improved our liquidity in the short-term , we are continuing to pursue alternatives for increasing our liquidity . · in november 2016 , opec reached a decision to reduce its level of production effective january 1 , 2017. gabon , as a member of opec , agreed to reduce its production by up to 9,000 bbl per day . as a result , we expect our production reduction to be approximately 548.9 bbl per day ( 170.5 bbl per day net to vaalco ) . we anticipate being able to reduce our production by these amounts by delaying certain workover activities until later in 2017 and by natural production declines . · o n november 22 , 2016 , we closed on the purchase of an additional 2.98 % working interest ( 3.23 % p articipating interest ) in the etame marin block located offshore th e republic of gabon from sojitz , which represents all interest owned by sojitz in the concession . the acquisition has an effective date of august 1 , 2016. the transaction was funded from our cash on hand . · i n december 2016 , we completed the sale of our interests in two wells in the hefley field in north texas for $ 8 3 0,000 resulting in a minimal loss , and on october 17 , 2016 , we signed a letter of intent to sell our interests in the east poplar dome field in montana for $ 250,000. as we had fully impaired the book value for the east poplar dome assets , we expect a small gain if the sale is completed . as a result of signing the letter of intent to sell our interests in the two wells in north texas in q3 2016 , we performed an impairment test and determined that a $ 0.1 million impairment was required during the third quarter . as of december 31 , 2016 , no proved reserves remained in the united states . u.s. sales volumes for the year ended december 31 , 2016 were 24 mboe . 35 discontinued operations-angola in november 2006 , we signed a production sharing contract for block 5 offshore angola . the four year primary term , with an optional three year extension , awarded us exploration rights to 1.4 million acres offshore central angola , with a commitment to drill two exploratory wells . in october 2014 , we entered into the subsequent exploration phase ( “ sep ” ) which extended the exploration period to november 30 , 2017 and required us and our partner to drill two additional exploration wells . our working interest is 40 % and we carry the angolan national oil company , sonangol p & p , for 10 % of the work program . story_separator_special_tag as operator of the etame marin and mutamba iroru blocks in gabon , we enter into project related activities on behalf of our working interest partners . we generally obtain advances from partners prior to significant funding commitments . we currently sell our crude oil production from gabon under a term contract that ends in january 201 8 . pric ing under the contract is based upon an average of dated brent in the month of lifting , adjusted for location and market factors . ﻿ contractual obligations cash obligations the table below provides aggregated information on our net share of story_separator_special_tag . the revenue change s between the years ended december 31 , 2016 and 2015 identified as related to changes in price or volume are shown in the table below : ﻿ ﻿ ﻿ ( in thousands ) price $ ( 11,518 ) volume ( 9,409 ) other 266 ﻿ $ ( 20,661 ) ﻿ 40 the table below shows net production , sales volumes and realized prices for both years . ﻿ ﻿ ﻿ year ended december 31 , ﻿ 2016 2015 gabon net oil production ( mbbls ) 1,515 1,656 ﻿ gabon net oil sales ( mbbls ) 1,485 1,679 u.s. net oil sales ( mbbls ) 3 3 net oil sales ( mbbls ) 1,488 1,682 net natural gas sales ( mmcf ) 124 181 net oil equivalents ( mboe ) 1,509 1,712 ﻿ average realized oil price ( $ /bbl ) $ 40.13 $ 47.85 average realized natural gas price ( $ /mcf ) 1.95 2.21 weighted average realized price ( $ /boe ) 39.62 47.24 average dated brent spot * ( $ /bbl ) 43.67 52.32 * average of daily dated brent spot prices posted on the u.s. energy information administration website . crude oil sales are a function of the number and size of crude oil liftings from the fpso , and thus crude oil sales do not always coincide with volumes produced in any given period . we made 12 and 11 liftings in the years ended december 31 , 2016 and 2015 , respectively . our share of oil inventory aboard the fpso , excluding royalty barrels , was approximately 46,700 and 34,000 barrels at december 31 , 2016 and 2015 , respectively . production expenses decreased $ 2 . 5 million in 201 6 compared to 2015. production expenses included workover costs to replace esps which were $ 6.8 million in 2016 and $ 4.2 million in 2015 . 2015 production expenses are higher because they include $ 1.9 million related to studies to evaluate solutions for a centralized processing facility to remove h 2 s from the sour production on the block . excluding workovers and h 2 s studies , the overall decrease in production expense was $ 3 . 2 million , which reflects some success in ongoing cost cutting efforts . exploration expense was minimal in 201 6 compared to $ 10.4 million in 2015. during 2015 , we charged to dry hole costs $ 9.2 million of exploratory well costs incurred in 2012 related to the n'gongui no . 2 discovery that had been capitalized pending the determination of proved reserves . also in 2015 , we recorded impairments of $ 1.3 million related to undeveloped leasehold costs associated with poplar dome in the u.s. the following table shows exploration expense in detail . ﻿ replace_table_token_13_th depreciation , depletion and amortization ( “ dd & a ” ) expenses decreased $ 2 6.1 million in 2016 compared to 2015. dd & a per boe rates were lower in 2016 reflecting the impact of impairments in 2015 , particularly the $ 52.1 million impairment made in the fourth quarter of 2015. general and administrative expenses decreased $ 2 . 7 million in 201 6 compared to 2015. t his is primarily a result of a $ 3.6 million decrease in stock-based compensation expense reflecting forfeitures related to employee departures . in addition , we took steps beginning in 2015 to reduce overall general and administrative costs , with decreases realized in personnel costs , services and various other cost categories . however , the amount of overhead we we re able to recover from our partners in 2016 has decreased and more than offset the benefits from reductions in personnel and other costs . under our operating agreements the amount of overhead recoverable is larger when capital spending is higher , as it was in 2015 with the development program in gabon and the exploratory drilling in angola . impairment of proved properties is discussed in detail in note 6 to the financial statements . declining forecasted oil prices in 2015 caused us to record an impairment of $ 81.3 million . other operating loss , net in 2016 includes $ 2 .8 million , net to vaalco , of expense associated with the demobilization , $ 5.1 million related to the early release of the contracted drilling rig and $ 1 . 0 million accrued for certain payroll taxes in gabon which were not paid pertaining to labor provided to us over a number of years by a third-party contractor . in june 2016 , we reached an agreement with 41 the drilling contractor to pay less than our originally estimated maximum day rate , plus demobilization costs , in seven equal monthly installments beginning in july 2016. general and administrative related to shareholder matters for 2016 and 2015 reflects costs incurred related to shareholder litigation that was settled in 2016. for 2016 , the amounts also include the offsetting insurance proceeds related to these matters . bad debt expense and other for both the years ended december 31 , 2016 and 2015 includes bad debt expense related to value added tax ( “ vat ” ) which the government of gabon is required to reimburse but has not yet paid . other operating income ( loss ) , net decreased by $ 0.8

