SUPPLEMENTARY OIL AND GAS INFORMATION (UNAUDITED) (Tables)

12 Months Ended

Dec. 31, 2013

Supplementary Oil and Gas Information [Abstract]

Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]

FCX's oil and gas acquisition, exploration and development activities since the acquisitions of PXP and MMR follow:

Property acquisition costs:
Proved propertiesa	$	12,205
Unproved propertiesb	11,259
Exploration costs	502
Development costs	854
	$	24,820

a. Included $12.2 billion from the acquisitions of PXP and MMR.

b. Included $11.1 billion from the acquisitions of PXP and MMR.

Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]

The following table presents the aggregate capitalized costs subject to amortization for oil and gas properties and the aggregate related accumulated amortization as of December 31, 2013:

Properties subject to amortization	$	13,829
Accumulated amortization	(1,357		)
	$	12,472

Schedule of Capitalized Costs of Unproved Properties Excluded from Amortization [Table Text Block]

The following table summarizes the categories of costs comprising the amount of unproved properties not subject to amortization as of December 31, 2013:

U.S.:
Onshore
Acquisition costs	$	3,109
Exploration costs	8
Capitalized interest	11
Offshore
Acquisition costs	7,528
Exploration costs	163
Capitalized interest	53
International:
Offshore
Acquisition costs	15
Exploration costs	—
Capitalized interest	—
	$	10,887

Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block]

The results of operations from oil and gas producing activities from June 1, 2013, to December 31, 2013, presented below exclude non-oil and gas revenues, general and administrative expenses, interest expense and interest income. Income tax expense was determined by applying the statutory rates to pre-tax operating results:

Revenues from oil and gas producing activities	$	2,616
Production and delivery costs	(682		)
Depreciation, depletion and amortization	(1,358		)
Income tax expense (based on FCX's statutory tax rate)	(219		)
Results of operations from oil and gas producing activities (excluding general and administrative expenses, interest expense and interest income)	$	357

Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]

The following table sets forth certain data pertaining to proved, proved developed and proved undeveloped reserves all of which are in the U.S. for the period June 1, 2013, to December 31, 2013.

	Oil		Gas		Total
	(MMbls)a,b		(Bcf)a		(MMBOE)a
Proved reserves:
Acquisitions of PXP and MMR	368		626		472
Extensions and discoveries	20		20		24
Revisions of previous estimates	11		(26	)	7
Sale of reserves in-place	—		(3	)	(1	)
Production	(29	)	(55	)	(38	)
Balance at December 31, 2013	370		562		464
Proved developed reserves at December 31, 2013	236		423		307
Proved undeveloped reserves at December 31, 2013	134		139		157

a. MMbls = million barrels; Bcf = billion cubic feet; MMBOE = million BOE

b. Included 20 MMBbls of NGL proved reserves, consisting of 14 MMBbls of proved developed and 6 MMBbls of proved undeveloped at December 31, 2013.

Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]

The Standardized Measure related to proved oil and natural gas reserves as of December 31, 2013, follows:

Future cash inflows	$	38,901
Future production expense	(12,774		)
Future development costsa	(6,480		)
Future income tax expense	(4,935		)
Future net cash flows	14,712
Discounted at 10% per year	(5,295		)
Standardized Measure	$	9,417

a. Included estimated asset retirement costs of $1.8 billion.

Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]

The following table summarizes the principal sources of changes in the Standardized Measure from June 1, 2013, to December 31, 2013:

Reserves acquired in the acquisitions of PXP and MMR	$	14,467
Sales, net of production expenses	(2,296		)
Net changes in sales and transfer prices, net of production expenses	(459		)
Extensions, discoveries and improved recoveries	752
Changes in estimated future development costs	(1,190		)
Previously estimated development costs incurred during the year	578
Sales of reserves in-place	(12		)
Other purchases of reserves in-place	—
Revisions of quantity estimates	102
Accretion of discount	701
Net change in income taxes	(3,226		)
Balance at December 31, 2013	$	9,417