The contracts were valued as of April 1, 2002, and an asset and a corresponding gain of $127 million, net of income taxes, was recorded as a cumulative effect of a change in accounting principle in the second quarter of 2002.
The majority of the gain recorded relates to the Warrior Run contract, as the asset value of the Deepwater contract on April 1, 2002, was less than $1 million.
The Warrior Run contract qualifies and was designated as a cash flow hedge as defined by SFAS No.133 and hedge accounting is applied for this contract subsequent to April 1, 2002.
The contract valuations were performed using current forward electricity and gas price quotes and current market data for other contract variables.
The forward curves used to value the contracts include certain assumptions, including projections of future electricity and gas prices in periods where future prices are not quoted.
Fluctuations in market prices and their impact on the assumptions will cause the value of these contracts to change.
Such fluctuations will increase the volatility of the Company’s reported results of operations.11.
COMMITMENTS, CONTINGENCIES AND RISKS OPERATING LEASES—As of December 31, 2002, the Company was obligated under long-term non-cancelable operating leases, primarily for office rental and site leases.
Rental expense for operating leases, excluding amounts related to the sale/leaseback discussed below, was $31 million $32 million and $13 million in the years ended December 31, 2002, 2001and 2000, respectively, including commitments of businesses classified as discontinued amounting to $6 million in 2002, $16 million in 2001 and $6 million in 2000.
The future minimum lease commitments under these leases are as follows (in millions):
## Table 0 ##
SALE/LEASEBACK—In May 1999, a subsidiary of the Company acquired six electric generating stations from New York State Electric and Gas (‘‘NYSEG’’).
Concurrently, the subsidiary sold two of the plants to an unrelated third party for $666 million and simultaneously entered into a leasing arrangement with the unrelated party.
This transaction has been accounted for as a sale/leaseback with operating lease treatment.
Rental expense was $54 million, $58 million and $54 million in 2002, 2001 and 2000, respectively.
Future minimum lease commitments are as follows (in millions): In connection with the lease of the two power plants, the subsidiary is required to maintain a rent reserve account equal to the maximum semi-annual payment with respect to the sum of the basic rent (other then deferrable basic rent) and fixed charges expected to become due in the immediately succeeding three-year period.
At December 31, 2002, 2001 and 2000, the amount deposited in the rent reserve account approximated
The estimated fair values of the Company’s debt and derivative financial instruments as of December 31, 2002 and 2001 are as follows (in millions):
## Table 1 ##
Amounts in the table above include the carrying amount and fair value of financial instruments of discontinued operations and assets held for sale, except for preferred stock with mandatory redemption of one of our discontinued operations that has a carrying amount of $22 million.
As of December 31, 2002, discontinued operations and assets held for sale had non-recourse debt with a carrying amount and fair value of $3,415 million and $4,994 million, respectively, foreign currency forwards and swaps, net (assets), with a carrying amount and fair value of $13 million, interest rate swaps (liabilities) with a carrying amount and fair value of $103 million and interest rate caps and floors, net (liabilities), with a carrying amount and fair value of $43 million.
The fair value estimates presented herein are based on pertinent information as of December 31, 2002 and 2001.
The Company is not aware of any factors that would significantly affect the estimated fair value amounts since December 31, 2002.21.
NEW ACCOUNTING PRONOUNCEMENTS Asset retirement obligations.
In June 2001, the Financial Accounting Standards Board issued SFAS No.143, ‘‘Accounting for Asset Retirement Obligations.
’’ SFAS No.143, which is effective January 1, 2003, requires entities to record the fair value of a legal liability for an asset retirement obligation in the period in which it is incurred.
When a new liability is recorded beginning in 2003, the entity will capitalize the costs of the liability by increasing the carrying amount of the related long-lived asset.
The liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset.
Upon settlement of the liability, an entity settles the obligation for its recorded amount or incurs a gain or loss upon settlement.
The Company will adopt SFAS No.143 effective January 1, 2003.
The Company has completed a detailed assessment of the specific applicability and implications of SFAS No.143.
The scope of SFAS No.143 includes primarily active ash landfills, water treatment basins and the removal or dismantlement of certain plant and equipment.
As of December 31, 2002, the Company had a recorded liability of approximately $15 million related to asset retirement obligations.
Upon adoption of SFAS No.143, the Company will record an additional liability of approximately $13 million, a net asset of approximately $9 million, and a cumulative effect of a change in accounting principle of approximately $2 million, after income taxes.
Proforma net (loss) income and (loss) earnings per share have not been presented for the years ended December 31, 2002, 2001 and 2000 because the proforma application of SFAS No.143 to prior periods would result in proforma net (loss) income and (loss) earnings per share not materially different from the actual amounts reported for those periods in the accompanying consolidated statements of operations.
Review of Consolidated Results of Operations
## Table 2 ##
Components of Revenue, Cost of Sales and Operating Margin—Revenue includes revenue earned from the sale of energy from our utilities and the production of energy from our generation plants, which are classified as regulated and non-regulated on the Consolidated Statements of Operations, respectively.
Revenue also includes the gains or losses on derivatives associated with the sale of electricity.
Cost of sales includes costs incurred directly by the businesses in the ordinary course of business.
Examples include electricity and fuel purchases, O&M costs, depreciation and amortization expense, bad debt expense and recoveries, general administrative and support costs (including employee-related costs directly associated with the operations of the business).
Cost of sales also includes the gains or losses on derivatives (including embedded derivatives other than foreign currency embedded derivatives) associated with the purchase of electricity or fuel.
Operating margin is defined as revenue less cost of sales.
In March 2013, the Secretariat of Energy released Resolution 95/2013, which affects the remuneration of generators whose sales prices had been frozen since 2003.
This regulation is applicable to generation companies with certain exceptions.
It defined a compensation system based on compensating for fixed costs, non-fuel variable costs and an additional margin.
Resolution 95/2013 converted the Argentine electric market to an "average cost" compensation scheme.
Thermal units must achieve an availability target, which varies by technology, in order to receive full fixed cost revenues.
The Resolution also established that all fuels, except coal, are to be provided by CAMMESA.
Thermoelectric natural gas plants not affected by the Resolution, such as TermoAndes, are able to purchase gas directly from the producers for Energy Plus sales.
In May 2014, the Argentine government passed Resolution No.529/214 ("Resolution 529") which retroactively updated the prices of Resolution 95/2013 to February 1, 2014, changed target availability and added a remuneration for non-periodic maintenance.
This remuneration is aimed to cover the expenses that the generator incurs when performing major maintenances in its units.
Since 2014, this resolution has been updated annually, the most recent of which was issued in March 2016.
On February 2, 2017, the Ministry of Energy issued Resolution 19/2017 establishing changes to the Energia Base price framework.
Effective in February 2017, the framework will maintain the current tolling agreement structure, as fuels will continue to be sourced by CAMMESA.
A key change will be introduced to the tariff structure which will now have prices set in USD and also eliminates all future non-cash retention of margins.
In December 2015, the finance minister lifted foreign currency controls, allowing the peso to float under the administration of Argentinean Central Bank.
The newly freed currency fell by more than 30%.
Over the course of 2016, the Argentinean Peso devalued by approximately 22%.
At December 31, 2016, all transactions at our businesses in Argentina were translated using the official exchange rate published by the Argentine Central Bank.
See Note 7—Financing Receivables in Item 8.
—Financial Statements and Supplementary Data of this Form 10-K for further information on the long-term receivables.
Further weakening of the Argentine Peso and local economic activity could cause significant volatility in our results of operations, cash flows, the ability to pay dividends to the Parent Company, and the value of our assets.
Key Financial Drivers — Financial results are likely to be driven by many factors including, but not limited to: ?
Forced outages may impact earnings ?
FX exposure to fluctuations of the Argentine Peso ?
Hydrology ?
Timely collection of FONINVEMEM installment and outstanding receivables (See Note 7—Financing Receivables in Item 8.
—Financial Statements and Supplementary Data for further discussion) ?
Level of gas prices for contracted generation (Energy Plus) Brazil SBU Our Brazil SBU has generation and distribution businesses.
Tietê and Eletropaulo are publicly listed companies in Brazil.
AES has a 24% economic interest in Tietê and a 17% economic interest in Eletropaulo.
These businesses are consolidated in our financial statements as we maintain control over their operations.
Generation — Operating installed capacity of our Brazil SBU totals 2,658 MW in AES Tietê plants, located in the state of S?o Paulo.
As of December 31, 2016, Tietê represents approximately 10% of the total generation capacity in the state of S?o Paulo and is one of the largest generation companies in Brazil.
We also have another generation plant, AES Uruguaiana, located in southern Brazil with an installed capacity of 640 MW.
The following table lists our Brazil SBU generation facilities:

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Total	Discontinued Operations
2003	$30	$4
2004	20	4
2005	15	3
2006	11	1
2007	9	1
Thereafter	84	1
Total	$169	$14

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December 31, 2002	December 31, 2001
Carrying Amount	Fair Value	Carrying Amount	Fair Value
Assets:
Foreign currency forwards and swaps, net	$17	$17	$14	$14
Energy derivatives, net	201	201	7	7
Liabilities:
Non-recourse debt	17,658	20,447	16,857	17,064
Recourse debt	5,804	3,895	5,401	4,730
Tecons	978	284	978	626
Interest rate swaps	557	557	166	166
Interest rate caps and floors, net	115	115	72	72

', '

Years Ended December 31,
Results of operations	2014	2013	2012	% change 2014 vs. 2013	% change 2013 vs. 2012
(in millions, except per share amounts)
Revenue:
US SBU	$3,826	$3,630	$3,736	5%	-3%
Andes SBU	2,642	2,639	3,020	—%	-13%
Brazil SBU	6,009	5,015	5,788	20%	-13%
MCAC SBU	2,682	2,713	2,573	-1%	5%
Europe SBU	1,439	1,347	1,344	7%	—%
Asia SBU	558	550	733	1%	-25%
Corporate and Other	15	7	9	114%	-22%
Intersegment eliminations	-25	-10	-39	-150%	74%
Total Revenue	17,146	15,891	17,164	8%	-7%
Operating Margin:
US SBU	699	668	711	5%	-6%
Andes SBU	587	533	580	10%	-8%
Brazil SBU	742	871	969	-15%	-10%
MCAC SBU	541	543	560	—%	-3%
Europe SBU	403	415	504	-3%	-18%
Asia SBU	76	169	236	-55%	-28%
Corporate and Other	53	25	-15	112%	267%
Intersegment eliminations	-13	23	38	-157%	-39%
Total Operating Margin	3,088	3,247	3,583	-5%	-9%
General and administrative expenses	-187	-220	-274	15%	20%
Interest expense	-1,471	-1,482	-1,544	1%	4%
Interest income	365	275	348	33%	-21%
Loss on extinguishment of debt	-261	-229	-8	-14%	NM
Other expense	-68	-76	-82	11%	7%
Other income	124	125	98	-1%	28%
Gain on disposal and sale of investments	358	26	219	NM	-88%
Goodwill impairment expense	-164	-372	-1,817	56%	80%
Asset impairment expense	-91	-95	-73	4%	-30%
Foreign currency transaction gains (losses)	11	-22	-170	150%	87%
Other non-operating expense	-128	-129	-50	1%	-158%
Income tax expense	-419	-343	-685	-22%	50%
Net equity in earnings of affiliates	19	25	35	-24%	-29%
INCOME (LOSS) FROM CONTINUING OPERATIONS	1,176	730	-420	61%	274%
Income (loss) from operations of discontinued businesses	27	-27	47	200%	-157%
Net gain (loss) from disposal and impairments of discontinued operations	-56	-152	16	63%	NM
NET INCOME (LOSS)	1,147	551	-357	108%	254%
Noncontrolling interests:
(Income) from continuing operations attributable to noncontrolling interests	-387	-446	-540	13%	17%
(Income) loss from discontinued operations attributable to noncontrolling interests	9	9	-15	—%	160%
Net income (loss) attributable to The AES Corporation	$769	$114	$-912	575%	113%
AMOUNTS ATTRIBUTABLE TO THE AES CORPORATION COMMON STOCKHOLDERS:
Income (loss) from continuing operations, net of tax	$789	$284	$-960	178%	130%
Income (loss) from discontinued operations, net of tax	-20	-170	48	88%	-454%
Net income (loss)	$769	$114	$-912	575%	113%
Net cash provided by operating activities	$1,791	$2,715	$2,901	-34%	-6%
DIVIDENDS DECLARED PER COMMON SHARE	$0.25	$0.17	$0.08	47%	113%

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Question: what was the average rental expense in millions for 2000 through 2002?
Answer: 55.33333