we expect 2014 natural gas liquids prices will be range-bound and remain relatively flat compared to 2013. crude oil prices remained relatively stable throughout 2013 , and oil continues to be more valuable than natural gas on a relative energy-equivalent basis . as a result , we and other producers have been focused on growing oil production . north american crude oil supply continues to increase due to the continued use of horizontal drilling technology throughout the u.s. and expansions of heavy oil production operations primarily in canada . global crude oil demand is expected to grow with supply in 2014. as crude oil supply grows , transportation capacity to downstream markets will be increasingly important . bottlenecks and other transportation limitations may continue to add volatility among u.s. and canadian grades of oil . however , we expect 2014 oil prices will remain relatively consistent with 2013. we exited 2013 with a production profile comprised of roughly 55 percent natural gas , 25 percent oil , and 20 percent natural gas liquids . recognizing the relative value of crude oil , we are devoting the vast majority of our 2014 capital investment toward growing our oil production , particularly the sweet grades of oil found in the u.s. to make a significant shift in our production profile , we expect to complete a $ 6 billion acquisition of eagle ford shale assets in the first quarter of 2014 and divest non-core , dry natural gas assets throughout 2014. once these transactions are complete , we expect oil will represent more than 30 percent of our production profile . further enhancing the value of our assets , we are combining substantially all of our u.s. midstream assets with crosstex energy , inc. 's and crosstex energy , l.p. 's assets to form a new midstream business . the new business will consist of enlink midstream partners , l.p. ( the partnership ) and enlink midstream , llc ( enlink ) , a master limited partnership and a general partner entity , which will both be publicly traded entities . the new midstream business will own devon 's midstream assets in the barnett shale in north texas and the cana and arkoma woodford shales in oklahoma , as well as devon 's economic interest in gulf coast fractionators in mt . belvieu , texas . devon will own a 70 percent controlling interest in enlink and an approximate 53 percent controlling interest in the partnership . results of operations all amounts in this document related to our international operations are presented as discontinued . therefore , the production , revenue and expense amounts presented in this results of operations section exclude amounts related to our international assets unless otherwise noted . 26 oil , gas and ngl production replace_table_token_15_th 27 oil , gas and ngl pricing replace_table_token_16_th ( 1 ) prices presented exclude any effects due to oil , gas and ngl derivatives . commodity sales the volume and price changes in the tables above caused the following changes to our oil , gas and ngl sales . replace_table_token_17_th volumes 2013 vs. 2012  upstream sales increased $ 625 million due to a 15 percent increase in our liquids production , partially offset by a 7 percent decline in our gas production . oil production was the largest driver of the increase , accounting for 85 percent of the higher sales . largely due to continued development of our properties in the permian basin , the mississippian-woodford trend and the anadarko basin , our oil sales increased $ 531 million . bitumen sales increased $ 65 million due to development of our jackfish thermal heavy oil projects in canada . additionally , our ngl sales increased $ 181 million as a result of continued drilling in the liquids-rich gas portions of the barnett shale and the anadarko basin . these increases were partially offset by a 7 percent decrease in our 2013 gas production , resulting in a $ 152 million decline in sales . volumes 2012 vs. 2011  upstream sales increased $ 695 million due to a 4 percent increase in production . oil and bitumen production were the largest drivers of the increase , accounting for nearly 90 percent of the higher sales . as a result of continued development of our liquids-rich properties in the permian basin , our oil 28 sales increased $ 337 million . bitumen sales increased $ 273 million due to development of our jackfish thermal heavy oil projects in canada . additionally , our ngl sales increased $ 137 million as a result of continued drilling in the liquids-rich gas portions of the barnett shale and the anadarko basin . these increases were partially offset by a slight decrease in our 2012 gas production , resulting in a $ 52 million decline in sales . prices 2013 vs. 2012  upstream sales increased $ 744 million due to an 18 percent increase in our realized price without hedges . our gas sales were the most significantly impacted with a $ 639 million increase in sales . the change in our gas price was largely due to higher north american regional index prices upon which our gas sales are based . our liquid sales increased $ 105 million due to higher oil and bitumen sales partially offset by lower ngl sales . the largest contributors to the higher liquids prices were an increase in the average nymex west texas intermediate index price and a slightly higher bitumen realized price , partially offset by lower ngl prices at the mont belvieu , texas hub . prices 2012 vs. 2011  upstream sales decreased $ 1.9 billion due to a 17 percent decrease in our realized price without hedges . our gas sales were the most significantly impacted with a $ 1.1 billion decrease in sales . story_separator_special_tag if we were to repatriate a portion or all of the cash held by our foreign subsidiaries , we would recognize and pay current income taxes in accordance with current u. s. tax law . the payment of such additional income tax would materially decrease the amount of cash and short-term investments ultimately available to fund our business . credit availability we have a $ 3.0 billion syndicated , unsecured revolving line of credit ( the senior credit facility ) that matures on october 24 , 2018. amounts borrowed under the senior credit facility may , at our election , bear interest at various fixed rate options for periods of up to twelve months . such rates are generally less than the prime rate . however , we may elect to borrow at the prime rate . as of december 31 , 2013 , we had $ 2.9 billion of available capacity under our syndicated , unsecured senior credit facility , net of letters of credit outstanding . the senior credit facility contains only one material financial covenant . this covenant requires us to maintain a ratio of total funded debt to total capitalization , as defined in the credit agreement , of no more than 65 percent . the credit agreement defines total funded debt as funds received through the issuance of debt securities such as debentures , bonds , notes payable , credit facility borrowings and short-term commercial paper borrowings . in addition , total funded debt includes all obligations with respect to payments received in consideration for oil , gas and ngl production yet to be acquired or produced at the time of payment . funded debt excludes our outstanding letters of credit and trade payables . the credit agreement defines total capitalization as the sum of funded debt and stockholders ' equity adjusted for noncash financial write-downs , such as full cost ceiling impairments . as of december 31 , 2013 , we were in compliance with this covenant . our debt-to-capitalization ratio at december 31 , 2013 , as calculated pursuant to the terms of the agreement , was 25.7 percent . our access to funds from the senior credit facility is not restricted under any material adverse effect clauses . it is not uncommon for credit agreements to include such clauses . these clauses can remove the obligation of the banks to fund the credit line if any condition or event would reasonably be expected to have a material and adverse effect on the borrower 's financial condition , operations , properties or business considered as a whole , the borrower 's ability to make timely debt payments , or the enforceability of material terms of the credit agreement . while our credit facility includes covenants that require us to report a condition or event having a material adverse effect , the obligation of the banks to fund the credit facility is not conditioned on the absence of a material adverse effect . we also have access to $ 3.0 billion of short-term credit under our commercial paper program . commercial paper debt generally has a maturity of between 1 and 90 days , although it can have a maturity of up to 365 days , and bears interest at rates agreed to at the time of the borrowing . the interest rate is generally based on a standard index such as the federal funds rate , libor , or the money market rate as found in the commercial paper market . as of december 31 , 2013 , we had $ 1.3 billion of borrowings under our commercial paper program . 39 debt ratings we receive debt ratings from the major ratings agencies in the u.s. in determining our debt ratings , the agencies consider a number of qualitative and quantitative items including , but not limited to , commodity pricing levels , our liquidity , asset quality , reserve mix , debt levels , cost structure , planned asset sales , near-term and long-term production growth opportunities and capital allocation challenges . our current debt ratings are bbb with a stable outlook by fitch , bbb+ with a negative outlook by standard & poor 's , and baa1 with a review for downgrade by moody 's . there are no rating triggers in any of our debt contractual obligations that would accelerate scheduled maturities should our debt rating fall below a specified level . our cost of borrowing under our senior credit facility is predicated on our corporate debt rating . therefore , even though a ratings downgrade would not accelerate scheduled maturities , it would adversely impact the interest rate on any borrowings under our senior credit facility . under the terms of the senior credit facility , a one-notch downgrade would increase the fully-drawn borrowing costs from libor plus 112.5 basis points to a new rate of libor plus 125 basis points . a ratings downgrade could also adversely impact our ability to economically access debt markets in the future . capital expenditures excluding our planned $ 6 billion eagle ford shale acquisition , our 2014 capital expenditures are expected to range from $ 6.4 billion to $ 6.9 billion , including $ 5.4 billion to $ 5.8 billion for our oil and gas operations , which include capitalized g & a and interest . to a certain degree , the ultimate timing of these capital expenditures is within our control . therefore , if commodity prices fluctuate from our current estimates , we could choose to defer a portion of these planned 2014 capital expenditures until later periods or accelerate capital expenditures planned for periods beyond 2014 to achieve the desired balance between sources and uses of liquidity . based upon current price expectations for 2014 , our existing commodity hedging contracts , available cash balances and credit availability , we anticipate having adequate capital resources to fund our 2014 capital expenditures . additionally , our financial and operational

sources and uses of cash the following table presents the major source and use categories of our cash and cash equivalents . replace_table_token_31_th operating cash flow  continuing operations net cash provided by operating activities ( operating cash flow ) continued to be a significant source of capital and liquidity in 2013. our operating cash flow increased 10 percent during 2013 primarily due to higher commodity prices and production growth , partially offset by higher expenses . our operating cash flow decreased 21 percent during 2012 primarily due to lower commodity prices and higher expenses , partially offset by additional cash flow from our production growth and higher cash settlements from our commodity derivatives . during 2013 our operating cash flow funded approximately 80 percent of our cash payments for capital expenditures . leveraging our liquidity , we used cash balances , short-term debt and divestiture proceeds to fund the remainder of our cash-based capital expenditures . capital expenditures replace_table_token_32_th 36 our capital expenditures consist of amounts related to our oil and gas exploration and development operations , our midstream operations and other corporate activities . the vast majority of our capital expenditures are for the acquisition , drilling and development of oil and gas properties , which totaled $ 6.0 billion , $ 7.4 billion and $ 6.9 billion in 2013 , 2012 and 2011 , respectively . the 20 percent decline in exploration , development and acquisition capital spending in 2013 was primarily due to a decline in new venture acreage acquisitions and utilization of the drilling carries in 2013 from our sinopec and sumitomo joint venture arrangements . the higher exploration and development capital spending in 2012 and 2011 was primarily due to new venture acreage acquisitions and increased drilling and development . with rising oil prices and proceeds from our offshore divestitures , we increased our onshore north american acreage positions and associated exploration and development activities to drive near-term growth of our oil production .


 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.
     ```sources and uses of cash the following table presents the major source and use categories of our cash and cash equivalents . replace_table_token_31_th operating cash flow  continuing operations net cash provided by operating activities ( operating cash flow ) continued to be a significant source of capital and liquidity in 2013. our operating cash flow increased 10 percent during 2013 primarily due to higher commodity prices and production growth , partially offset by higher expenses . our operating cash flow decreased 21 percent during 2012 primarily due to lower commodity prices and higher expenses , partially offset by additional cash flow from our production growth and higher cash settlements from our commodity derivatives . during 2013 our operating cash flow funded approximately 80 percent of our cash payments for capital expenditures . leveraging our liquidity , we used cash balances , short-term debt and divestiture proceeds to fund the remainder of our cash-based capital expenditures . capital expenditures replace_table_token_32_th 36 our capital expenditures consist of amounts related to our oil and gas exploration and development operations , our midstream operations and other corporate activities . the vast majority of our capital expenditures are for the acquisition , drilling and development of oil and gas properties , which totaled $ 6.0 billion , $ 7.4 billion and $ 6.9 billion in 2013 , 2012 and 2011 , respectively . the 20 percent decline in exploration , development and acquisition capital spending in 2013 was primarily due to a decline in new venture acreage acquisitions and utilization of the drilling carries in 2013 from our sinopec and sumitomo joint venture arrangements . the higher exploration and development capital spending in 2012 and 2011 was primarily due to new venture acreage acquisitions and increased drilling and development . with rising oil prices and proceeds from our offshore divestitures , we increased our onshore north american acreage positions and associated exploration and development activities to drive near-term growth of our oil production .
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 Suspicious Activity Report : we expect 2014 natural gas liquids prices will be range-bound and remain relatively flat compared to 2013. crude oil prices remained relatively stable throughout 2013 , and oil continues to be more valuable than natural gas on a relative energy-equivalent basis . as a result , we and other producers have been focused on growing oil production . north american crude oil supply continues to increase due to the continued use of horizontal drilling technology throughout the u.s. and expansions of heavy oil production operations primarily in canada . global crude oil demand is expected to grow with supply in 2014. as crude oil supply grows , transportation capacity to downstream markets will be increasingly important . bottlenecks and other transportation limitations may continue to add volatility among u.s. and canadian grades of oil . however , we expect 2014 oil prices will remain relatively consistent with 2013. we exited 2013 with a production profile comprised of roughly 55 percent natural gas , 25 percent oil , and 20 percent natural gas liquids . recognizing the relative value of crude oil , we are devoting the vast majority of our 2014 capital investment toward growing our oil production , particularly the sweet grades of oil found in the u.s. to make a significant shift in our production profile , we expect to complete a $ 6 billion acquisition of eagle ford shale assets in the first quarter of 2014 and divest non-core , dry natural gas assets throughout 2014. once these transactions are complete , we expect oil will represent more than 30 percent of our production profile . further enhancing the value of our assets , we are combining substantially all of our u.s. midstream assets with crosstex energy , inc. 's and crosstex energy , l.p. 's assets to form a new midstream business . the new business will consist of enlink midstream partners , l.p. ( the partnership ) and enlink midstream , llc ( enlink ) , a master limited partnership and a general partner entity , which will both be publicly traded entities . the new midstream business will own devon 's midstream assets in the barnett shale in north texas and the cana and arkoma woodford shales in oklahoma , as well as devon 's economic interest in gulf coast fractionators in mt . belvieu , texas . devon will own a 70 percent controlling interest in enlink and an approximate 53 percent controlling interest in the partnership . results of operations all amounts in this document related to our international operations are presented as discontinued . therefore , the production , revenue and expense amounts presented in this results of operations section exclude amounts related to our international assets unless otherwise noted . 26 oil , gas and ngl production replace_table_token_15_th 27 oil , gas and ngl pricing replace_table_token_16_th ( 1 ) prices presented exclude any effects due to oil , gas and ngl derivatives . commodity sales the volume and price changes in the tables above caused the following changes to our oil , gas and ngl sales . replace_table_token_17_th volumes 2013 vs. 2012  upstream sales increased $ 625 million due to a 15 percent increase in our liquids production , partially offset by a 7 percent decline in our gas production . oil production was the largest driver of the increase , accounting for 85 percent of the higher sales . largely due to continued development of our properties in the permian basin , the mississippian-woodford trend and the anadarko basin , our oil sales increased $ 531 million . bitumen sales increased $ 65 million due to development of our jackfish thermal heavy oil projects in canada . additionally , our ngl sales increased $ 181 million as a result of continued drilling in the liquids-rich gas portions of the barnett shale and the anadarko basin . these increases were partially offset by a 7 percent decrease in our 2013 gas production , resulting in a $ 152 million decline in sales . volumes 2012 vs. 2011  upstream sales increased $ 695 million due to a 4 percent increase in production . oil and bitumen production were the largest drivers of the increase , accounting for nearly 90 percent of the higher sales . as a result of continued development of our liquids-rich properties in the permian basin , our oil 28 sales increased $ 337 million . bitumen sales increased $ 273 million due to development of our jackfish thermal heavy oil projects in canada . additionally , our ngl sales increased $ 137 million as a result of continued drilling in the liquids-rich gas portions of the barnett shale and the anadarko basin . these increases were partially offset by a slight decrease in our 2012 gas production , resulting in a $ 52 million decline in sales . prices 2013 vs. 2012  upstream sales increased $ 744 million due to an 18 percent increase in our realized price without hedges . our gas sales were the most significantly impacted with a $ 639 million increase in sales . the change in our gas price was largely due to higher north american regional index prices upon which our gas sales are based . our liquid sales increased $ 105 million due to higher oil and bitumen sales partially offset by lower ngl sales . the largest contributors to the higher liquids prices were an increase in the average nymex west texas intermediate index price and a slightly higher bitumen realized price , partially offset by lower ngl prices at the mont belvieu , texas hub . prices 2012 vs. 2011  upstream sales decreased $ 1.9 billion due to a 17 percent decrease in our realized price without hedges . our gas sales were the most significantly impacted with a $ 1.1 billion decrease in sales . story_separator_special_tag if we were to repatriate a portion or all of the cash held by our foreign subsidiaries , we would recognize and pay current income taxes in accordance with current u. s. tax law . the payment of such additional income tax would materially decrease the amount of cash and short-term investments ultimately available to fund our business . credit availability we have a $ 3.0 billion syndicated , unsecured revolving line of credit ( the senior credit facility ) that matures on october 24 , 2018. amounts borrowed under the senior credit facility may , at our election , bear interest at various fixed rate options for periods of up to twelve months . such rates are generally less than the prime rate . however , we may elect to borrow at the prime rate . as of december 31 , 2013 , we had $ 2.9 billion of available capacity under our syndicated , unsecured senior credit facility , net of letters of credit outstanding . the senior credit facility contains only one material financial covenant . this covenant requires us to maintain a ratio of total funded debt to total capitalization , as defined in the credit agreement , of no more than 65 percent . the credit agreement defines total funded debt as funds received through the issuance of debt securities such as debentures , bonds , notes payable , credit facility borrowings and short-term commercial paper borrowings . in addition , total funded debt includes all obligations with respect to payments received in consideration for oil , gas and ngl production yet to be acquired or produced at the time of payment . funded debt excludes our outstanding letters of credit and trade payables . the credit agreement defines total capitalization as the sum of funded debt and stockholders ' equity adjusted for noncash financial write-downs , such as full cost ceiling impairments . as of december 31 , 2013 , we were in compliance with this covenant . our debt-to-capitalization ratio at december 31 , 2013 , as calculated pursuant to the terms of the agreement , was 25.7 percent . our access to funds from the senior credit facility is not restricted under any material adverse effect clauses . it is not uncommon for credit agreements to include such clauses . these clauses can remove the obligation of the banks to fund the credit line if any condition or event would reasonably be expected to have a material and adverse effect on the borrower 's financial condition , operations , properties or business considered as a whole , the borrower 's ability to make timely debt payments , or the enforceability of material terms of the credit agreement . while our credit facility includes covenants that require us to report a condition or event having a material adverse effect , the obligation of the banks to fund the credit facility is not conditioned on the absence of a material adverse effect . we also have access to $ 3.0 billion of short-term credit under our commercial paper program . commercial paper debt generally has a maturity of between 1 and 90 days , although it can have a maturity of up to 365 days , and bears interest at rates agreed to at the time of the borrowing . the interest rate is generally based on a standard index such as the federal funds rate , libor , or the money market rate as found in the commercial paper market . as of december 31 , 2013 , we had $ 1.3 billion of borrowings under our commercial paper program . 39 debt ratings we receive debt ratings from the major ratings agencies in the u.s. in determining our debt ratings , the agencies consider a number of qualitative and quantitative items including , but not limited to , commodity pricing levels , our liquidity , asset quality , reserve mix , debt levels , cost structure , planned asset sales , near-term and long-term production growth opportunities and capital allocation challenges . our current debt ratings are bbb with a stable outlook by fitch , bbb+ with a negative outlook by standard & poor 's , and baa1 with a review for downgrade by moody 's . there are no rating triggers in any of our debt contractual obligations that would accelerate scheduled maturities should our debt rating fall below a specified level . our cost of borrowing under our senior credit facility is predicated on our corporate debt rating . therefore , even though a ratings downgrade would not accelerate scheduled maturities , it would adversely impact the interest rate on any borrowings under our senior credit facility . under the terms of the senior credit facility , a one-notch downgrade would increase the fully-drawn borrowing costs from libor plus 112.5 basis points to a new rate of libor plus 125 basis points . a ratings downgrade could also adversely impact our ability to economically access debt markets in the future . capital expenditures excluding our planned $ 6 billion eagle ford shale acquisition , our 2014 capital expenditures are expected to range from $ 6.4 billion to $ 6.9 billion , including $ 5.4 billion to $ 5.8 billion for our oil and gas operations , which include capitalized g & a and interest . to a certain degree , the ultimate timing of these capital expenditures is within our control . therefore , if commodity prices fluctuate from our current estimates , we could choose to defer a portion of these planned 2014 capital expenditures until later periods or accelerate capital expenditures planned for periods beyond 2014 to achieve the desired balance between sources and uses of liquidity . based upon current price expectations for 2014 , our existing commodity hedging contracts , available cash balances and credit availability , we anticipate having adequate capital resources to fund our 2014 capital expenditures . additionally , our financial and operational

