10-Q

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2015
OR
[  ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from	to
Commission File Number: 001-11307-01

Freeport-McMoRan Inc.

(Exact name of registrant as specified in its charter)

Delaware	74-2480931
(State or other jurisdiction of	(I.R.S. Employer Identification No.)
incorporation or organization)
333 North Central Avenue
Phoenix, AZ	85004-2189
(Address of principal executive offices)	(Zip Code)
(602) 366-8100
(Registrant's telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

þ Yes  o No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).       þ Yes  o No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer þ         Accelerated filer o          Non-accelerated filer o         Smaller reporting company o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

o Yes þ No

On July 31, 2015, there were issued and outstanding 1,040,228,261 shares of the registrant’s common stock, par value $0.10 per share.

FREEPORT-McMoRan INC.

TABLE OF CONTENTS

	Page
Part I. Financial Information	3
Item 1. Financial Statements:
Condensed Consolidated Balance Sheets (Unaudited)	3
Consolidated Statements of Operations (Unaudited)	4
Consolidated Statements of Comprehensive (Loss) Income (Unaudited)	5
Consolidated Statements of Cash Flows (Unaudited)	6
Consolidated Statement of Equity (Unaudited)	7
Notes to Consolidated Financial Statements (Unaudited)	8
Review Report of Independent Registered Public Accounting Firm	30
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	31
Item 3. Quantitative and Qualitative Disclosures About Market Risk	91
Item 4. Controls and Procedures	91
Part II. Other Information	91
Item 1. Legal Proceedings	91
Item 1A. Risk Factors	91
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	92
Item 4. Mine Safety Disclosure	92
Item 6. Exhibits	92
Signature	93
Exhibit Index	E-1

2

Part I. FINANCIAL INFORMATION

Item 1. Financial Statements.

FREEPORT-McMoRan INC.

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)

	June 30, 2015			December 31, 2014
	(In millions)
ASSETS
Current assets:
Cash and cash equivalents	$	466		$	464
Trade accounts receivable	949			953
Other accounts receivable	1,323			1,610
Inventories:
Materials and supplies, net	2,014			1,886
Mill and leach stockpiles	1,933			1,914
Product	1,484			1,561
Other current assets	528			657
Total current assets	8,697			9,045
Property, plant, equipment and mining development costs, net	27,095			26,220
Oil and gas properties, net - full cost method
Subject to amortization, less accumulated amortization	4,649			9,187
Not subject to amortization	9,312			10,087
Long-term mill and leach stockpiles	2,277			2,179
Other assets	1,978			1,956
Total assets	$	54,008		$	58,674
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$	3,376		$	3,653
Current portion of debt	791			478
Current portion of environmental and asset retirement obligations	330			296
Dividends payable	175			335
Accrued income taxes	67			410
Total current liabilities	4,739			5,172
Long-term debt, less current portion	20,111			18,371
Deferred income taxes	4,870			6,398
Environmental and asset retirement obligations, less current portion	3,716			3,647
Other liabilities	1,760			1,861
Total liabilities	35,196			35,449
Redeemable noncontrolling interest	757			751
Equity:
Stockholders’ equity:
Common stock	117			117
Capital in excess of par value	22,330			22,281
(Accumulated deficit) retained earnings	(4,417		)	128
Accumulated other comprehensive loss	(523		)	(544		)
Common stock held in treasury	(3,702		)	(3,695		)
Total stockholders’ equity	13,805			18,287
Noncontrolling interests	4,250			4,187
Total equity	18,055			22,474
Total liabilities and equity	$	54,008		$	58,674

The accompanying notes are an integral part of these consolidated financial statements.

3

FREEPORT-McMoRan INC.

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
	(In millions, except per share amounts)
Revenues	$	4,248		$	5,522		$	8,401		$	10,507
Cost of sales:
Production and delivery	2,848			3,082			5,760			5,819
Depreciation, depletion and amortization	890			1,013			1,829			1,979
Impairment of oil and gas properties	2,686			—			5,790			—
Total cost of sales	6,424			4,095			13,379			7,798
Selling, general and administrative expenses	151			164			305			299
Mining exploration and research expenses	36			34			69			64
Environmental obligations and shutdown costs	11			76			24			82
Net gain on sale of assets	—			—			(39		)	—
Total costs and expenses	6,622			4,369			13,738			8,243
Operating (loss) income	(2,374		)	1,153			(5,337		)	2,264
Interest expense, net	(149		)	(164		)	(295		)	(325		)
Insurance and other third-party recoveries	92			—			92			—
Net gain on early extinguishment of debt	—			5			—			5
Other (expense) income, net	(55		)	(8		)	(48		)	25
(Loss) income before income taxes and equity in affiliated companies' net earnings	(2,486		)	986			(5,588		)	1,969
Benefit from (provision for) income taxes	687			(328		)	1,382			(685		)
Equity in affiliated companies’ net earnings	—			2			1			2
Net (loss) income	(1,799		)	660			(4,205		)	1,286
Net income attributable to noncontrolling interests	(42		)	(168		)	(100		)	(274		)
Preferred dividends attributable to redeemable noncontrolling interest	(10		)	(10		)	(20		)	(20		)
Net (loss) income attributable to common stockholders	$	(1,851	)	$	482		$	(4,325	)	$	992
Net (loss) income per share attributable to common stockholders:
Basic	$	(1.78	)	$	0.46		$	(4.16	)	$	0.95
Diluted	$	(1.78	)	$	0.46		$	(4.16	)	$	0.95
Weighted-average common shares outstanding:
Basic	1,040			1,039			1,040			1,039
Diluted	1,040			1,045			1,040			1,045
Dividends declared per share of common stock	$	0.1605		$	0.3125		$	0.2105		$	0.6250

The accompanying notes are an integral part of these consolidated financial statements.

4

FREEPORT-McMoRan INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME (Unaudited)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
	(In millions)
Net (loss) income	$	(1,799	)	$	660		$	(4,205	)	$	1,286
Other comprehensive income, net of taxes:
Defined benefit plans:
Amortization of unrecognized amounts included in net periodic benefit costs	8			4			16			7
Foreign exchange gains (losses)	1			(3		)	5			(3		)
Other comprehensive income	9			1			21			4
Total comprehensive (loss) income	(1,790		)	661			(4,184		)	1,290
Total comprehensive income attributable to noncontrolling interests	(42		)	(168		)	(100		)	(274		)
Preferred dividends attributable to redeemable noncontrolling interest	(10		)	(10		)	(20		)	(20		)
Total comprehensive (loss) income attributable to common stockholders	$	(1,842	)	$	483		$	(4,304	)	$	996

The accompanying notes are an integral part of these consolidated financial statements.

5

FREEPORT-McMoRan INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

	Six Months Ended
	June 30,
	2015			2014
	(In millions)
Cash flow from operating activities:
Net (loss) income	$	(4,205	)	$	1,286
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation, depletion and amortization	1,829			1,979
Impairment of oil and gas properties	5,790			—
Lower of cost or market inventory adjustments	63			—
Net gain on sale of assets	(39		)	—
Net (gains) losses on crude oil and natural gas derivative contracts	(58		)	120
Net charges for environmental and asset retirement obligations, including accretion	109			97
Payments for environmental and asset retirement obligations	(81		)	(96		)
Net gain on early extinguishment of debt	—			(5		)
Deferred income taxes	(1,432		)	37
Increase in long-term mill and leach stockpiles	(104		)	(131		)
Other, net	104			77
Changes in working capital and other tax payments, excluding amounts from acquisitions and disposition:
Accounts receivable	493			(243		)
Inventories	8			(230		)
Other current assets	(1		)	35
Accounts payable and accrued liabilities	(205		)	(186		)
Accrued income taxes and changes in other tax payments	(485		)	(153		)
Net cash provided by operating activities	1,786			2,587
Cash flow from investing activities:
Capital expenditures:
North America copper mines	(214		)	(627		)
South America	(902		)	(839		)
Indonesia	(438		)	(479		)
Africa	(97		)	(60		)
Molybdenum mines	(7		)	(33		)
United States oil and gas operations	(1,795		)	(1,484		)
Other	(75		)	(40		)
Acquisition of Deepwater Gulf of Mexico interests	—			(925		)
Net proceeds from sale of Eagle Ford shale assets	—			3,009
Other, net	136			(363		)
Net cash used in investing activities	(3,392		)	(1,841		)
Cash flow from financing activities:
Proceeds from debt	4,422			1,248
Repayments of debt	(2,360		)	(1,611		)
Cash dividends and distributions paid:
Common stock	(380		)	(653		)
Noncontrolling interests	(60		)	(250		)
Stock-based awards net (payments) proceeds, including excess tax benefit	(7		)	3
Debt financing costs and other, net	(7		)	(10		)
Net cash provided by (used in) financing activities	1,608			(1,273		)
Net increase (decrease) in cash and cash equivalents	2			(527		)
Cash and cash equivalents at beginning of year	464			1,985
Cash and cash equivalents at end of period	$	466		$	1,458

The accompanying notes are an integral part of these consolidated financial statements.

6

FREEPORT-McMoRan INC.

CONSOLIDATED STATEMENT OF EQUITY (Unaudited)

	Stockholders’ Equity
	Common Stock						Retained Earnings(Accum-ulated Deficit)			Accumu- lated Other Compre- hensive Loss			Common Stock Held in Treasury				Total Stock-holders' Equity
	Number of Shares	At Par Value		Capital in Excess of Par Value									Number of Shares	At Cost						Non- controlling Interests			Total Equity
	(In millions)
Balance at December 31, 2014	1,167	$	117	$	22,281		$	128		$	(544	)	128	$	(3,695	)	$	18,287		$	4,187		$	22,474
Exercised and issued stock-based awards	1	—		3			—			—			—	—			3			—			3
Stock-based compensation	—	—		50			—			—			—	—			50			7			57
Reserve of tax benefit for stock-based awards	—	—		(2		)	—			—			—	—			(2		)	—			(2		)
Tender of shares for stock-based awards	—	—		—			—			—			—	(7		)	(7		)	—			(7		)
Dividends on common stock	—	—		—			(220		)	—			—	—			(220		)	—			(220		)
Dividends to noncontrolling interests	—	—		—			—			—			—	—			—			(46		)	(46		)
Noncontrolling interests' share of contributed capital in subsidiary	—	—		(2		)	—			—			—	—			(2		)	2			—
Net loss attributable to common stockholders	—	—		—			(4,325		)	—			—	—			(4,325		)	—			(4,325		)
Net income attributable to noncontrolling interests	—	—		—			—			—			—	—			—			100			100
Other comprehensive income	—	—		—			—			21			—	—			21			—			21
Balance at June 30, 2015	1,168	$	117	$	22,330		$	(4,417	)	$	(523	)	128	$	(3,702	)	$	13,805		$	4,250		$	18,055

The accompanying notes are an integral part of these consolidated financial statements.

7

FREEPORT-McMoRan INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

NOTE 1. GENERAL INFORMATION

The accompanying unaudited consolidated financial statements have been prepared in accordance with the instructions to Form 10-Q and do not include all information and disclosures required by generally accepted accounting principles (GAAP) in the United States (U.S.). Therefore, this information should be read in conjunction with Freeport-McMoRan Inc.'s (FCX) consolidated financial statements and notes contained in its annual report on Form 10-K for the year ended December 31, 2014. The information furnished herein reflects all adjustments that are, in the opinion of management, necessary for a fair statement of the results for the interim periods reported. With the exception of the oil and gas properties impairment discussed below and the related tax charge to establish a deferred tax valuation allowance, all such adjustments are, in the opinion of management, of a normal recurring nature. Operating results for the quarter and six months ended June 30, 2015, are not necessarily indicative of the results that may be expected for the year ending December 31, 2015.

Oil and Gas Properties. Under the U.S. Securities and Exchange Commission's (SEC) full cost accounting rules, FCX reviews the carrying value of its oil and gas properties each quarter on a country-by-country basis. Under these rules, capitalized costs of oil and gas properties (net of accumulated depreciation, depletion, amortization and impairment, and related deferred income taxes) for each cost center may not exceed a “ceiling” equal to:

• the present value, discounted at 10 percent, of estimated future net cash flows from the related proved oil and natural gas reserves, net of estimated future income taxes; plus

• the cost of the related unproved properties not being amortized; plus

• the lower of cost or estimated fair value of the related unproved properties included in the costs being amortized (net of related tax effects).

These rules require that FCX price its future oil and gas production at the twelve-month average of the first-day-of-the-month historical reference prices as adjusted for location and quality differentials. FCX's reference prices are West Texas Intermediate (WTI) for oil and the Henry Hub spot price for natural gas. Such prices are utilized except where different prices are fixed and determinable from applicable contracts for the remaining term of those contracts. The reserve estimates exclude the effect of any crude oil derivatives FCX has in place. The estimated future net cash flows also exclude future cash outflows associated with settling asset retirement obligations included in the net book value of the oil and gas properties. The rules require an impairment if the capitalized costs exceed this “ceiling.”

At June 30, 2015, and March 31, 2015, net capitalized costs with respect to FCX's proved U.S. oil and gas properties exceeded the related ceiling test limitation; therefore, impairment charges of $2.7 billion were recorded in second-quarter 2015 and $5.8 billion for the first six months of 2015, primarily because of the lower twelve-month average of the first-day-of-the-month historical reference oil price and higher capitalized costs at such dates. The SEC requires that the twelve-month average of the first-day-of-the-month historical reference oil price be used in determining the ceiling amount under its full cost accounting rules. This price (using WTI as the reference oil price) was $71.68 per barrel at June 30, 2015 (the twelve-month average was $82.72 per barrel at March 31, 2015).

NOTE 2. ACQUISITIONS AND DISPOSITIONS

Eagle Ford Disposition. On June 20, 2014, FCX completed the sale of its Eagle Ford shale assets to a subsidiary of Encana Corporation for cash consideration of $3.1 billion, before closing adjustments from the April 1, 2014, effective date. Under full cost accounting rules, the proceeds were recorded as a reduction of capitalized oil and gas properties, with no gain or loss recognition, except for $58 million of deferred tax expense recorded in connection with the allocation of $221 million of goodwill (for which deferred taxes were not previously provided) to the Eagle Ford shale assets. Approximately $1.3 billion of proceeds from this transaction was placed in a like-kind exchange escrow and was used to reinvest in additional Deepwater Gulf of Mexico (GOM) oil and gas interests, as discussed below and in Note 2 of FCX's annual report on Form 10-K for the year ended December 31, 2014. The remaining proceeds were used to repay debt.

Deepwater GOM Acquisition. On June 30, 2014, FCX completed the acquisition of interests in the Deepwater GOM from a subsidiary of Apache Corporation, including interests in the Lucius and Heidelberg oil fields and several exploration leases, for $918 million ($451 million for oil and gas properties subject to amortization and $477 million for costs not subject to amortization, including transaction costs and $10 million of asset retirement costs). The Deepwater GOM acquisition was funded by the like-kind exchange escrow.

8

NOTE 3. EARNINGS PER SHARE

FCX’s basic net (loss) income per share of common stock was computed by dividing net (loss) income attributable to common stockholders by the weighted-average shares of common stock outstanding during the period. Diluted net income per share of common stock was computed using the most dilutive of (a) the two-class method or (b) the treasury stock method. Under the two-class method, net income is allocated to each class of common stock and participating securities as if all of the earnings for the period had been distributed. FCX’s participating securities consist of vested restricted stock units (RSUs) for which the underlying common shares are not yet issued and entitle holders to non-forfeitable dividends.

A reconciliation of net (loss) income and weighted-average shares of common stock outstanding for purposes of calculating basic and diluted net (loss) income per share follows (in millions, except per share amounts):

	Three Months Ended								Six Months Ended
	June 30,								June 30,
	2015				2014				2015				2014
Net (loss) income	$	(1,799	)		$	660			$	(4,205	)		$	1,286
Net income attributable to noncontrolling interests	(42		)		(168		)		(100		)		(274		)
Preferred dividends on redeemable noncontrolling interest	(10		)		(10		)		(20		)		(20		)
Undistributed earnings allocable to participating securities	(3		)		(2		)		(3		)		(3		)
Net (loss) income allocable to common stockholders	$	(1,854	)		$	480			$	(4,328	)		$	989
Basic weighted-average shares of common stock outstanding	1,040				1,039				1,040				1,039
Add shares issuable upon exercise or vesting of dilutive stock options and RSUs	—			a	6			a	—			a	6			a
Diluted weighted-average shares of common stock outstanding	1,040				1,045				1,040				1,045
Basic net (loss) income per share attributable to common stockholders	$	(1.78	)		$	0.46			$	(4.16	)		$	0.95
Diluted net (loss) income per share attributable to common stockholders	$	(1.78	)		$	0.46			$	(4.16	)		$	0.95

a. Excludes approximately four million shares of common stock for both the quarter and six months ended June 30, 2015, and three million shares of common stock for both the quarter and six months ended June 30, 2014, associated with outstanding stock options with exercise prices less than the average market price of FCX's common stock and RSUs that were anti-dilutive.

Outstanding stock options with exercise prices greater than the average market price of FCX’s common stock during the period are excluded from the computation of diluted net income per share of common stock. Excluded stock options totaled 40 million for both the quarter and six months ended June 30, 2015, and 30 million for both the quarter andsix months ended June 30, 2014.

9

NOTE 4. INVENTORIES, INCLUDING LONG-TERM MILL AND LEACH STOCKPILES

The components of inventories follow (in millions):

	June 30, 2015		December 31, 2014
Current inventories:
Mill stockpiles	$	130	$	86
Leach stockpiles	1,803		1,828
Total current mill and leach stockpiles	$	1,933	$	1,914
Total materials and supplies, neta	$	2,014	$	1,886
Raw materials (primarily concentrates)	$	306	$	288
Work-in-process	155		174
Finished goods	1,023		1,099
Total product inventories	$	1,484	$	1,561
Long-term inventories:
Mill stockpiles	$	361	$	360
Leach stockpiles	1,916		1,819
Total long-term mill and leach stockpilesb	$	2,277	$	2,179

a. Materials and supplies inventory was net of obsolescence reserves totaling $25 million at June 30, 2015, and $20 million at December 31, 2014.

b. Estimated metals in stockpiles not expected to be recovered within the next 12 months.

FCX recorded charges for lower of cost or market (LCM) inventory adjustments of $59 million ($48 million for molybdenum inventories and $11 million for copper inventories) for second-quarter 2015 and $63 million ($52 million for molybdenum inventories and $11 million for copper inventories) for the first six months of 2015, primarily because of lower molybdenum and copper prices.

NOTE 5. INCOME TAXES

Variations in the relative proportions of jurisdictional income result in fluctuations to FCX's consolidated effective income tax rate. FCX’s consolidated effective income tax rate was 25 percent for the first six months of 2015 and 35 percent for the first six monthsof 2014. Geographic sources of FCX's (benefit from) provision for income taxes follow (in millions):

	Three Months Ended							Six Months Ended
	June 30,							June 30,
	2015				2014			2015				2014
U.S. operations	$	(829	)	a	$	149	b	$	(1,664	)	a	$	285	b
International operations	142				179			282				400
Total	$	(687	)		$	328		$	(1,382	)		$	685

a. As a result of the impairment to oil and gas properties, FCX recorded tax charges of $305 million for second-quarter2015 and $763 million for the first six months of 2015 to establish a valuation allowance primarily against U.S. federal alternative minimum tax credits. Excluding this charge, FCX's consolidated effective income tax rate was 38 percent for the first six months of 2015.

b. FCX recognized a $58 million charge for deferred taxes recorded in connection with the allocation of goodwill to the sale of Eagle Ford shale assets.

10

NOTE 6. DEBT AND EQUITY TRANSACTIONS

Debt Transactions. At June 30, 2015, FCX had $20.9 billion in debt, which included additions for unamortized fair value adjustments of $225 million (primarily from the oil and gas acquisitions in 2013), and is net of reductions attributable to unamortized net discounts of $21 million and unamortized debt issuance costs of $116 million. Refer to Note 12 for discussion of a change in the presentation of debt issuance costs.

In February 2015, FCX's unsecured revolving credit facility and $4.0 billion bank term loan (Term Loan) were modified to amend the maximum total leverage ratio. In addition, the Term Loan amortization schedule was extended such that, as amended, the Term Loan’s scheduled payments total $205 million in 2016, $272 million in 2017, $1.0 billion in 2018, $313 million in 2019 and $1.3 billion in 2020, compared with the previous amortization schedule of $650 million in 2016, $200 million in 2017 and $2.2 billion in 2018.

At June 30, 2015, $985 million was outstanding and $42 million of letters of credit were issued under FCX's revolving credit facility, resulting in availability of approximately $3.0 billion, of which approximately $1.5 billion could be used for additional letters of credit.

At June 30, 2015, $1.3 billion was outstanding and no letters of credit were issued under Sociedad Minera Cerro Verde S.A.A.'s (Cerro Verde, FCX's mining subsidiary in Peru) credit facility, resulting in availability of $531 million. Cerro Verde's five-year, $1.8 billion senior unsecured credit facility is nonrecourse to FCX and the other shareholders of Cerro Verde.

In April 2014, FCX redeemed $210 million of the aggregate principal amount of FCX Oil & Gas Inc.'s (FM O&G, FCX's oil and gas subsidiary) outstanding 6.625% Senior Notes due 2021. In accordance with the terms of the senior notes, the redemption was funded with cash contributions to FM O&G by FCX in exchange for additional equity, which is eliminated in the consolidated financial statements. Holders of these senior notes received the principal amount together with the redemption premium and accrued and unpaid interest to the redemption date. As a result of the redemption, FCX recorded a gain on early extinguishment of debt of $6 million in second-quarter 2014.

Consolidated interest expense (excluding capitalized interest) totaled $215 million in second-quarter2015, $225 million in second-quarter2014, $425 million for the first six months of 2015 and $449 million for the first six months of 2014. Capitalized interest added to property, plant, equipment and mining development costs, net, totaled $47 million in second-quarter2015, $39 million in second-quarter2014, $92 million for the first six months of 2015 and $79 million for the first six months of 2014. Capitalized interest added to oil and gas properties not subject to amortization totaled $19 million in second-quarter2015, $22 million in second-quarter2014, $38 million for the first six months of 2015 and $45 million for the first six months of 2014.

Equity Transactions. On June 24, 2015, FCX's Board of Directors (the Board) declared a dividend of $0.1605 per share, which was paid on August 3, 2015, to common shareholders of record at the close of business on July 15, 2015. This common stock dividend consisted of $0.05 per share for FCX's regular quarterly dividend and $0.1105 per share as a one-time special dividend related to the settlement of the shareholder derivative litigation (refer to Note 9 for further discussion).

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NOTE 7. FINANCIAL INSTRUMENTS

FCX does not purchase, hold or sell derivative financial instruments unless there is an existing asset or obligation, or it anticipates a future activity that is likely to occur and will result in exposure to market risks, which FCX intends to offset or mitigate. FCX does not enter into any derivative financial instruments for speculative purposes, but has entered into derivative financial instruments in limited instances to achieve specific objectives. These objectives principally relate to managing risks associated with commodity price changes, foreign currency exchange rates and interest rates.

Commodity Contracts.  From time to time, FCX has entered into derivative contracts to hedge the market risk associated with fluctuations in the prices of commodities it purchases and sells. As a result of the acquisition of the oil and gas business in 2013, FCX assumed a variety of crude oil and natural gas commodity derivatives to hedge the exposure to the volatility of crude oil and natural gas commodity prices. Derivative financial instruments used by FCX to manage its risks do not contain credit risk-related contingent provisions. As of June 30, 2015, and December 31, 2014, FCX had no price protection contracts relating to its mine production. A discussion of FCX’s derivative contracts and programs follows.

Derivatives Designated as Hedging Instruments – Fair Value Hedges

Copper Futures and Swap Contracts. Some of FCX’s U.S. copper rod customers request a fixed market price instead of the Commodity Exchange Inc. (COMEX), a division of the New York Mercantile Exchange, average copper price in the month of shipment. FCX hedges this price exposure in a manner that allows it to receive the COMEX average price in the month of shipment while the customers pay the fixed price they requested. FCX accomplishes this by entering into copper futures or swap contracts. Hedging gains or losses from these copper futures and swap contracts are recorded in revenues. FCX did not have any significant gains or losses during the three-month or six-month periods ended June 30, 2015 and 2014, resulting from hedge ineffectiveness. At June 30, 2015, FCX held copper futures and swap contracts that qualified for hedge accounting for 51 million pounds at an average contract price of $2.71 per pound, with maturities through May 2017.

A summary of gains (losses) recognized in revenues for derivative financial instruments related to commodity contracts that are designated and qualify as fair value hedge transactions, along with the unrealized gains (losses) on the related hedged item follows (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
Copper futures and swap contracts:
Unrealized gains (losses):
Derivative financial instruments	$	(4	)	$	12		$	2		$	—
Hedged item – firm sales commitments	4			(12		)	(2		)	—
Realized (losses) gains:
Matured derivative financial instruments	(1		)	(2		)	(11		)	(4		)

Derivatives Not Designated as Hedging Instruments

Embedded Derivatives. As described in Note 1 to FCX's annual report on Form 10-K for the year ended December 31, 2014, under “Revenue Recognition,” certain FCX copper concentrate, copper cathode and gold sales contracts provide for provisional pricing primarily based on the London Metal Exchange (LME) copper price or the COMEX copper price and the London Bullion Market Association (London) gold price at the time of shipment as specified in the contract. Similarly, FCX purchases copper under contracts that provide for provisional pricing. FCX applies the normal purchases and normal sales scope exception in accordance with derivatives and hedge accounting guidance to the host sales agreements since the contracts do not allow for net settlement and always result in physical delivery. Sales and purchases with a provisional sales price contain an embedded derivative (i.e., the price settlement mechanism is settled after the time of delivery) that is required to be bifurcated from the host contract. The host contract is the sale or purchase of the metals contained in the concentrates or cathodes at the then-current LME or COMEX copper price or the London gold price as defined in the contract. Mark-to-market price fluctuations from these embedded derivatives are recorded through the settlement date and are reflected in revenues for sales contracts and in cost of sales as production and delivery costs for purchase contracts.

12

A summary of FCX’s embedded commodity derivatives at June 30, 2015, follows:

	Open Positions	Average Price Per Unit				Maturities Through
		Contract		Market
Embedded derivatives in provisional sales contracts:
Copper (millions of pounds)	572	$	2.68	$	2.58	November 2015
Gold (thousands of ounces)	229	1,189		1,174		September 2015
Embedded derivatives in provisional purchase contracts:
Copper (millions of pounds)	134	2.75		2.61		October 2015

Crude Oil Contracts. As a result of the acquisition of the oil and gas business, FCX has derivative contracts extending through 2015 that consist of crude oil options. These crude oil derivatives are not designated as hedging instruments and are recorded at fair value with the mark-to-market gains and losses recorded in revenues.

The crude oil options were entered into by the oil and gas business to protect the realized price of a portion of expected future sales in order to limit the effects of crude oil price decreases. At June 30, 2015, these contracts are composed of crude oil put spreads consisting of put options with a floor limit. The premiums associated with put options are deferred until the settlement period. At June 30, 2015, the deferred option premiums and accrued interest associated with the crude oil option contracts totaled $106 million, which was included as a component of the fair value of the crude oil options contracts. At June 30, 2015, the outstanding 2015 crude oil option contracts, which settle monthly and cover approximately 15.5 million barrels over the remainder of 2015, follow:

		Daily Volumes (thousand barrels)	Average Strike Price (per barrel)a				Weighted-Average Deferred Premium  (per barrel)
2015 Period	Instrument Type		Floor		Floor Limit				Index
July - December	Put optionsb	84	$	90	$	70	$	6.89	Brent

a. The average strike prices do not reflect any premiums to purchase the put options.

b. If the index price is less than the per barrel floor, FCX receives the difference between the per barrel floor and the index price up to a maximum of $20 per barrel less the option premium. If the index price is at or above the per barrel floor, FCX pays the option premium and no cash settlement is received.

Copper Forward Contracts. Atlantic Copper, FCX's wholly owned smelting and refining unit in Spain, enters into copper forward contracts designed to hedge its copper price risk whenever its physical purchases and sales pricing periods do not match. These economic hedge transactions are intended to hedge against changes in copper prices, with the mark-to-market hedging gains or losses recorded in cost of sales. At June 30, 2015, Atlantic Copper held net copper forward purchase contracts for 31 million pounds at an average contract price of $2.65 per pound, with maturities through August 2015.

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Summary of (Losses) Gains. A summary of the realized and unrealized (losses) gains recognized in (loss) income before income taxes and equity in affiliated companies’ net earnings for commodity contracts that do not qualify as hedge transactions, including embedded derivatives, follows (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
Embedded derivatives in provisional copper and gold
sales contractsa	$	(78	)	$	84		$	(150	)	$	(85	)
Crude oil optionsa	6			(68		)	58			(104		)
Natural gas swapsa	—			(2		)	—			(16		)
Copper forward contractsb	(6		)	4			(7		)	5

a. Amounts recorded in revenues. 

b. Amounts recorded in cost of sales as production and delivery costs.

Unsettled Derivative Financial Instruments

A summary of the fair values of unsettled commodity derivative financial instruments follows (in millions):

	June 30, 2015		December 31, 2014
Commodity Derivative Assets:
Derivatives not designated as hedging instruments:
Embedded derivatives in provisional copper and gold
sales/purchase contracts	$	21	$	15
Crude oil optionsa	174		316
Total derivative assets	$	195	$	331
Commodity Derivative Liabilities:
Derivatives designated as hedging instruments:
Copper futures and swap contractsb	$	5	$	7
Derivatives not designated as hedging instruments:
Embedded derivatives in provisional copper and gold
sales/purchase contracts	65		93
Copper forward contracts	1		—
Total derivative liabilities	$	71	$	100

a. Amounts are net of $106 million at June 30, 2015, and $210 million at December 31, 2014, for deferred premiums and accrued interest.

b. FCX paid $9 million to brokers at June 30, 2015, and $10 million at December 31, 2014, for margin requirements (recorded in other current assets).

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FCX's commodity contracts have netting arrangements with counterparties with which the right of offset exists, and it is FCX's policy to offset balances by counterparty on the balance sheet. FCX's embedded derivatives on provisional sales/purchases are netted with the corresponding outstanding receivable/payable balances. A summary of these unsettled commodity contracts that are offset in the balance sheet follows (in millions):

	Assets				Liabilities
	June 30, 2015		December 31, 2014		June 30,  2015		December 31, 2014
Gross amounts recognized:
Commodity contracts:
Embedded derivatives in provisional
sales/purchase contracts	$	21	$	15	$	65	$	93
Crude oil derivatives	174		316		—		—
Copper derivatives	—		—		6		7
	195		331		71		100
Less gross amounts of offset:
Commodity contracts:
Embedded derivatives in provisional
sales/purchase contracts	1		1		1		1
Copper derivatives	—		—		—		—
	1		1		1		1
Net amounts presented in balance sheet:
Commodity contracts:
Embedded derivatives in provisional
sales/purchase contracts	20		14		64		92
Crude oil derivatives	174		316		—		—
Copper derivatives	—		—		6		7
	$	194	$	330	$	70	$	99
Balance sheet classification:
Trade accounts receivable	$	3	$	5	$	53	$	56
Other current assets	174		316		—		—
Accounts payable and accrued liabilities	17		9		17		43
	$	194	$	330	$	70	$	99

Credit Risk.  FCX is exposed to credit loss when financial institutions with which FCX has entered into derivative transactions (commodity, foreign exchange and interest rate swaps) are unable to pay. To minimize the risk of such losses, FCX uses counterparties that meet certain credit requirements and periodically reviews the creditworthiness of these counterparties. FCX does not anticipate that any of the counterparties it deals with will default on their obligations. As of June 30, 2015, the maximum amount of credit exposure associated with derivative transactions was $226 million.

Other Financial Instruments.  Other financial instruments include cash and cash equivalents, accounts receivable, restricted cash, investment securities, legally restricted funds, accounts payable and accrued liabilities, dividends payable and long-term debt. The carrying value for cash and cash equivalents (which included time deposits of $27 million at June 30, 2015, and $48 million at December 31, 2014), accounts receivable, restricted cash, accounts payable and accrued liabilities, and dividends payable approximates fair value because of their short-term nature and generally negligible credit losses (refer to Note 8 for the fair values of investment securities, legally restricted funds and long-term debt).

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NOTE 8. FAIR VALUE MEASUREMENT

Fair value accounting guidance includes a hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 inputs) and the lowest priority to unobservable inputs (Level 3 inputs).

FCX recognizes transfers between levels at the end of the reporting period. FCX did not have any significant transfers in or out of Level 1, 2 or 3 for second-quarter 2015. A summary of the carrying amount and fair value of FCX’s financial instruments, other than cash and cash equivalents, accounts receivable, restricted cash, accounts payable and accrued liabilities, and dividends payable (refer to Note 7), follows (in millions):

	At June 30, 2015
	Carrying		Fair Value
	Amount		Total		Level 1		Level 2		Level 3
Assets
Investment securities:a,b
U.S. core fixed income fund	$	23	$	23	$	—	$	23	$	—
Money market funds	22		22		22		—		—
Equity securities	3		3		3		—		—
Total	48		48		25		23		—
Legally restricted funds:a,b,c,d
U.S. core fixed income fund	51		51		—		51		—
Government bonds and notes	35		35		—		35		—
Corporate bonds	28		28		—		28		—
Government mortgage-backed securities	24		24		—		24		—
Asset-backed securities	14		14		—		14		—
Money market funds	9		9		9		—		—
Collateralized mortgage-backed securities	8		8		—		8		—
Municipal bonds	1		1		—		1		—
Total	170		170		9		161		—
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross asset position	21		21		—		21		—
Crude oil options	174		174		—		—		174
Total	195		195		—		21		174
Total assets			$	413	$	34	$	205	$	174
Liabilities
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross liability position	$	65	$	65	$	—	$	65	$	—
Copper futures and swap contracts	5		5		5		—		—
Copper forward contracts	1		1		—		1		—
Total	71		71		5		66		—
Long-term debt, including current portionf	20,902		20,191		—		20,191		—
Total liabilities			$	20,262	$	5	$	20,257	$	—

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	At December 31, 2014
	Carrying		Fair Value
	Amount		Total		Level 1		Level 2		Level 3
Assets
Investment securities:a,b
U.S. core fixed income fund	$	23	$	23	$	—	$	23	$	—
Money market funds	20		20		20		—		—
Equity securities	3		3		3		—		—
Total	46		46		23		23		—
Legally restricted funds:a,b,c,d
U.S. core fixed income fund	52		52		—		52		—
Government bonds and notes	39		39		—		39		—
Corporate bonds	27		27		—		27		—
Government mortgage-backed securities	19		19		—		19		—
Asset-backed securities	17		17		—		17		—
Money market funds	11		11		11		—		—
Collateralized mortgage-backed securities	6		6		—		6		—
Municipal bonds	1		1		—		1		—
Total	172		172		11		161		—
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross asset position	15		15		—		15		—
Crude oil options	316		316		—		—		316
Total	331		331		—		15		316
Total assets			$	549	$	34	$	199	$	316
Liabilities
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross liability position	$	93	$	93	$	—	$	93	$	—
Copper futures and swap contracts	7		7		6		1		—
Total	100		100		6		94		—
Long-term debt, including current portionf	18,849		18,735		—		18,735		—
Total liabilities			$	18,835	$	6	$	18,829	$	—

a. Recorded at fair value. 

b. Current portion included in other current assets and long-term portion included in other assets.

c. Excludes time deposits (which approximated fair value) included in other assets of $117 million at June 30, 2015, and $115 million at December 31, 2014, associated with an assurance bond to support PT Freeport Indonesia's (PT-FI) commitment for smelter development in Indonesia.

d. Excludes time deposits (which approximated fair value) included in other current assets of $10 million at June 30, 2015, and $8 million at December 31, 2014, associated with a reclamation guarantee at PT-FI. Also, excludes a time deposit of $9 million at December 31, 2014, associated with a customs audit assessment.

e. Refer to Note 7 for further discussion and balance sheet classifications. Crude oil options are net of $106 million at June 30, 2015, and $210 million at December 31, 2014, for deferred premiums and accrued interest.

f. Recorded at cost except for debt assumed in acquisitions, which were recorded at fair value at the respective acquisition dates.

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Valuation Techniques

Money market funds are classified within Level 1 of the fair value hierarchy because they are valued using quoted market prices in active markets.

The U.S. core fixed income fund is valued at net asset value. The fund strategy seeks total return consisting of income and capital appreciation primarily by investing in a broad range of investment-grade debt securities, including U.S. government obligations, corporate bonds, mortgage-backed securities, asset-backed securities and money market instruments. There are no restrictions on redemptions (usually within one business day of notice) and, as such, this fund is classified within Level 2 of the fair value hierarchy.

Fixed income securities (government securities, corporate bonds, asset-backed securities, collateralized mortgage-backed securities and municipal bonds) are valued using a bid evaluation price or a mid-evaluation price. A bid evaluation price is an estimated price at which a dealer would pay for a security. A mid-evaluation price is the average of the estimated price at which a dealer would sell a security and the estimated price at which a dealer would pay for a security. These evaluations are based on quoted prices, if available, or models that use observable inputs and, as such, are classified within Level 2 of the fair value hierarchy.

Equity securities are valued at the closing price reported on the active market on which the individual securities are traded and, as such, are classified within Level 1 of the fair value hierarchy.

FCX’s embedded derivatives on provisional copper concentrate, copper cathode and gold purchases and sales are valued using quoted monthly LME or COMEX copper forward prices and the London gold forward price at each reporting date based on the month of maturity (refer to Note 7 for further discussion); however, FCX's contracts themselves are not traded on an exchange. As a result, these derivatives are classified within Level 2 of the fair value hierarchy.

FCX's derivative financial instruments for crude oil options are valued using an option pricing model, which uses various inputs including Intercontinental Exchange Holdings, Inc. crude oil prices, volatilities, interest rates and contract terms. Valuations are adjusted for credit quality, using the counterparties' credit quality for asset balances and FCX's credit quality for liability balances (which considers the impact of netting agreements on counterparty credit risk, including whether the position with the counterparty is a net asset or net liability). For asset balances, FCX uses the credit default swap value for counterparties when available or the spread between the risk-free interest rate and the yield rate on the counterparties' publicly traded debt for similar instruments. The crude oil options are classified within Level 3 of the fair value hierarchy because the inputs used in the valuation models are not observable for the full term of the instruments. The significant unobservable inputs used in the fair value measurement of the crude oil options are implied volatilities and deferred premiums. Significant increases (decreases) in implied volatilities in isolation would result in a significantly higher (lower) fair value measurement. The implied volatilities ranged from 28 percent to 41 percent, with a weighted average of 32 percent. The weighted-average cost of deferred premiums totals $6.89 per barrel at June 30, 2015. Refer to Note 7 for further discussion of these derivative financial instruments.

FCX’s derivative financial instruments for copper futures and swap contracts and copper forward contracts that are traded on the respective exchanges are classified within Level 1 of the fair value hierarchy because they are valued using quoted monthly COMEX or LME prices at each reporting date based on the month of maturity (refer to Note 7 for further discussion). Certain of these contracts are traded on the over-the-counter market and are classified within Level 2 of the fair value hierarchy based on COMEX and LME forward prices.

Long-term debt, including the current portion, is not actively traded and is valued using prices obtained from a readily available pricing source and, as such, is classified within Level 2 of the fair value hierarchy.

The techniques described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. Furthermore, while FCX believes its valuation techniques are appropriate and consistent with other market participants, the use of different techniques or assumptions to determine fair value of certain financial instruments could result in a different fair value measurement at the reporting date. There have been no changes in the techniques used at June 30, 2015.

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A summary of the changes in the fair value of FCX's most significant Level 3 instruments, crude oil options, follows (in millions):

	Crude Oil
	Options
Fair value at December 31, 2014	$	316
Net realized gains	21
Net unrealized gains included in earnings related to assets and liabilities   still held at the end of the period	36			a
Net settlement receipts	(199		)	b
Fair value at June 30, 2015	$	174

a. Includes net unrealized gains of $37 million, partially offset by $1 million of interest expense associated with the deferred premiums.

b. Includes interest payments of $2 million.

NOTE 9. CONTINGENCIES AND COMMITMENTS

Litigation. The following information includes a discussion of updates to previously reported legal proceedings included in Note 12 of FCX's annual report on Form 10-K for the year ended December 31, 2014, as updated in Note 8 of FCX's quarterly report on Form 10-Q for the quarterly period ended March 31, 2015.

Shareholder Litigation. On April 7, 2015, the Delaware Court of Chancery approved the settlement of FCX’s consolidated stockholder derivative litigation captioned In Re Freeport-McMoRan Copper & Gold Inc. Derivative Litigation, No. 8145-VCN, and awarded the plaintiffs legal fees and expenses. This settlement resolved all pending derivative claims against directors and officers of FCX challenging FCX's 2013 acquisitions of Plains Exploration & Production Company and McMoRan Exploration Co. During first-quarter 2015, insurers under FCX’s directors and officers liability insurance policies and other third parties funded an escrow account with the $125 million settlement amount, from which the proceeds, net of plaintiffs’ legal fees and expenses totaling $33 million, were released to FCX in May 2015. Upon the release of funds, FCX recognized a gain of $92 million in second-quarter 2015. As a result and in accordance with the approved settlement terms, FCX's Board declared a special dividend that was paid on August 3, 2015, together with the regular quarterly dividend paid on the same day (refer to Note 6 for further discussion).

Tax and Other Matters. There were no significant changes to the Cerro Verde royalty dispute or other Peruvian tax matters during the second quarter of 2015 (refer to Note 12 of FCX’s annual report on Form 10-K for the year ended December 31, 2014, for further discussion of these matters).

Indonesia Tax Matters. The following information includes a discussion of updates to previously reported Indonesia tax matters included in Note 12 of FCX’s annual report on Form 10-K for the year ended December 31, 2014, as updated in Note 8 of FCX's quarterly report on Form 10-Q for the quarterly period ended March 31, 2015.

PT-FI received assessments from the local regional tax authority in Papua, Indonesia, for additional taxes and penalties related to water rights tax payments for the period from January 2011 through June 2015. PT-FI has filed or will file objections to these assessments. In March 2015, the local government of Papua rejected PT-FI’s objections to the assessments related to the period from January 2011 through December 2014, and in April 2015, PT-FI filed appeals with the Indonesian tax court. The aggregate amount of all assessments received through August 3, 2015, including penalties, was 2.5 trillion Indonesian rupiah ($190 million based on exchange rates at June 30, 2015). Additional penalties, which could be significant, may be assessed depending on the outcome of the appeals process. No amounts have been accrued for these assessments as of June 30, 2015, because PT-FI believes its Contract of Work (COW) exempts it from these payments and that it has the right to contest these assessments in the tax court and ultimately the Indonesian Supreme Court.

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NOTE 10. BUSINESS SEGMENTS

FCX has organized its mining operations into five primary divisions – North America copper mines, South America mining, Indonesia mining, Africa mining and Molybdenum mines. Notwithstanding this structure, FCX internally reports information on a mine-by-mine basis for its mining operations. Therefore, FCX concluded that its operating segments include individual mines or operations relative to its mining operations. For oil and gas operations, FCX determines its operating segments on a country-by-country basis. Operating segments that meet certain thresholds are reportable segments, which are separately disclosed in the following table.

Intersegment Sales. Intersegment sales between FCX’s mining operations are based on similar arms-length transactions with third parties at the time of the sale. Intersegment sales may not be reflective of the actual prices ultimately realized because of a variety of factors, including additional processing, timing of sales to unaffiliated customers and transportation premiums.

FCX defers recognizing profits on sales from its mines to other divisions, including Atlantic Copper (FCX's wholly owned smelter and refinery in Spain) and on 25 percent of PT-FI's sales to PT Smelting (FCX's 25 percent-owned smelter and refinery in Indonesia), until final sales to third parties occur. Quarterly variations in ore grades, the timing of intercompany shipments and changes in product prices result in variability in FCX's net deferred profits and quarterly earnings.

Allocations. FCX allocates certain operating costs, expenses and capital expenditures to its operating divisions and individual segments. However, not all costs and expenses applicable to an operation are allocated. U.S. federal and state income taxes are recorded and managed at the corporate level (included in corporate, other & eliminations), whereas foreign income taxes are recorded and managed at the applicable country level. In addition, most mining exploration and research activities are managed on a consolidated basis, and those costs along with some selling, general and administrative costs are not allocated to the operating divisions or individual segments. Accordingly, the following segment information reflects management determinations that may not be indicative of what the actual financial performance of each operating division or segment would be if it was an independent entity.

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Financial Information by Business Segments

(In millions)	Mining Operations
	North America Copper Mines							South America							Indonesia				Africa
																											Atlantic			Other										Corporate,
																					Molyb-						Copper			Mining						U.S.				Other
			Other					Cerro			Other										denum				Rod &		Smelting			& Elimi-				Total		Oil & Gas				& Elimi-			FCX
	Morenci		Mines			Total		Verde			Minesa		Total		Grasberg				Tenke		Mines				Refining		& Refining			nations				Mining		Operationsb				nations			Total
Three Months Ended June 30, 2015
Revenues:
Unaffiliated customers	$	180	$	92		$	272	$	195		$	221	$	416	$	792		c	$	310	$	—			$	1,089	$	495		$	305		d	$	3,679	$	569		e	$	—		$	4,248
Intersegment	427		706			1,133		37			—		37		(2		)	f	41		102				8		5			(1,324		)		—		—				—			—
Production and delivery	386		576		g	962		165			150		315		455				190		84			g	1,088		468			(997		)	g	2,565		281				2			2,848
Depreciation, depletion and amortization	55		84			139		40			32		72		78				57		25				3		9			19				402		485				3			890
Impairment of oil and gas properties	—		—			—		—			—		—		—				—		—				—		—			—				—		2,686				—			2,686
Selling, general and administrative expenses	—		2			2		—			1		1		25				3		—				—		4			5				40		49				62			151
Mining exploration and research expenses	—		2			2		—			—		—		—				—		—				—		—			34				36		—				—			36
Environmental obligations and shutdown costs	—		—			—		—			—		—		—				—		—				—		—			11				11		—				—			11
Operating income (loss)	166		134			300		27			38		65		232				101		(7		)		6		19			(91		)		625		(2,932		)		(67		)	(2,374		)
Interest expense, net	—		1			1		—			—		—		—				—		—				—		2			39				42		41				66			149
Provision for (benefit from) income taxes	—		—			—		(5		)	11		6		95				27		—				—		—			—				128		—				(815		)	(687		)
Total assets at June 30, 2015	3,806		5,582			9,388		8,567			1,935		10,502		8,959				5,125		2,052				286		786			1,336				38,434		15,393				181			54,008
Capital expenditures	79		28			107		444			13		457		213				58		4				—		4			11				854		777				30			1,661
Three Months Ended June 30, 2014
Revenues:
Unaffiliated customers	$	52	$	55		$	107	$	421		$	524	$	945	$	523		c	$	386	$	—			$	1,234	$	623		$	468		d	$	4,286	$	1,236		e	$	—		$	5,522
Intersegment	474		888			1,362		23			63		86		—				32		170				8		6			(1,664		)		—		—				—			—
Production and delivery	312		558			870		195			335		530		511				198		81				1,233		618			(1,287		)		2,754		329				(1		)	3,082
Depreciation, depletion and amortization	43		85			128		43			52		95		54				63		24				3		10			17				394		616				3			1,013
Selling, general and administrative expenses	1		—			1		1			1		2		25				3		—				—		5			6				42		59				63			164
Mining exploration and research expenses	—		2			2		—			—		—		—				—		—				—		—			32				34		—				—			34
Environmental obligations and shutdown costs	—		—			—		—			—		—		—				—		—				—		—			76				76		—				—			76
Operating income (loss)	170		298			468		205			199		404		(67		)		154		65				6		(4		)	(40		)		986		232				(65		)	1,153
Interest expense, net	—		1			1		—			—		—		—				—		—				—		3			18				22		74				68			164
Provision for (benefit from) income taxes	—		—			—		73			67		140		(33		)		33		—				—		—			—				140		—				188			328
Total assets at June 30, 2014	3,675		5,822			9,497		6,876			3,791		10,667		7,972				4,952		2,095				299		882			1,127				37,491		25,293				1,119			63,903
Capital expenditures	289		35			324		391			25		416		243				29		14				1		5			17				1,049		903				(2		)	1,950

a. Second-quarter 2014 includes the results of the Candelaria and Ojos del Salado mining operations, which were sold in November 2014.

b. Second-quarter 2014 includes the results from Eagle Ford, which was sold in June 2014.

c. Includes PT-FI’s sales to PT Smelting totaling $293 million in second-quarter2015 and $540 million in second-quarter2014.

d. Includes revenues from FCX's molybdenum sales company, which includes sales of molybdenum produced by the Molybdenum mines and by certain of the North and South America copper mines.

e. Includes net mark-to-market gains (losses) associated with crude oil and natural gas derivative contracts totaling $6 million in second-quarter2015 and $(70) million in second-quarter2014.

f. Amounts include net reductions for provisional pricing adjustments to prior period open sales. There were no intersegment sales from Grasberg in second-quarter 2015.

g. Includes LCM inventory adjustments totaling $11 million at other North America copper mines, $3 million at Molybdenum mines and $45 million at other mining & eliminations (see Note 4).

21

(In millions)	Mining Operations
	North America Copper Mines									South America								Indonesia				Africa
																														Atlantic			Other											Corporate,
																								Molyb-						Copper			Mining							U.S.				Other
			Other							Cerro		Other												denum				Rod &		Smelting			& Elimi-				Total			Oil & Gas				& Elimi-			FCX
	Morenci		Mines				Total			Verde		Minesa				Total		Grasberg				Tenke		Mines				Refining		& Refining			nations				Mining			Operationsb				nations			Total
Six Months Ended June 30, 2015
Revenues:
Unaffiliated customers	$	286	$	207			$	493		$	443	$	452			$	895	$	1,413		c	$	692	$	—			$	2,151	$	1,035		$	653		d	$	7,332		$	1,069		e	$	—		$	8,401
Intersegment	877		1,370				2,247			51		(7		)	f	44		(16		)	f	69		215				15		11			(2,585		)		—			—				—			—
Production and delivery	760		1,145			g	1,905			363		297				660		894				425		167			g	2,151		987			(1,998		)	g	5,191			564				5			5,760
Depreciation, depletion and amortization	106		166				272			77		70				147		148				130		51				5		19			35				807			1,015				7			1,829
Impairment of oil and gas properties	—		—				—			—		—				—		—				—		—				—		—			—				—			5,790				—			5,790
Selling, general and administrative expenses	1		2				3			1		1				2		50				6		—				—		9			11				81			103				121			305
Mining exploration and research expenses	—		5				5			—		—				—		—				—		—				—		—			64				69			—				—			69
Environmental obligations and shutdown costs	—		—				—			—		—				—		—				—		—				—		—			24				24			—				—			24
Net gain on sales of assets	—		(39		)		(39		)	—		—				—		—				—		—				—		—			—				(39		)	—				—			(39		)
Operating income (loss)	296		298				594			53		77				130		305				200		(3		)		10		31			(68		)		1,199			(6,403		)		(133		)	(5,337		)
Interest expense, net	1		1				2			1		—				1		—				—		—				—		5			79				87			78				130			295
Provision for (benefit from) income taxes	—		—				—			—		30				30		124				53		—				—		—			—				207			—				(1,589		)	(1,382		)
Capital expenditures	163		51				214			875		27				902		438				97		7				1		8			27				1,694			1,795				39			3,528
Six Months Ended June 30, 2014
Revenues:
Unaffiliated customers	$	75	$	116			$	191		$	701	$	946			$	1,647	$	985		c	$	692	$	—			$	2,380	$	1,211		$	904		d	$	8,010		$	2,497		e	$	—		$	10,507
Intersegment	918		1,646				2,564			87		195				282		8				53		296				16		11			(3,230		)		—			—				—			—
Production and delivery	595		1,061				1,656			360		646				1,006		894				350		157				2,381		1,206			(2,470		)		5,180			640				(1		)	5,819
Depreciation, depletion and amortization	77		158				235			79		103				182		102				114		46				5		20			36				740			1,232				7			1,979
Selling, general and administrative expenses	1		1				2			2		2				4		46				6		—				—		9			13				80			116				103			299
Mining exploration and research expenses	—		4				4			—		—				—		—				—		—				—		—			60				64			—				—			64
Environmental obligations and shutdown costs	—		—				—			—		—				—		—				—		—				—		—			82				82			—				—			82
Operating income (loss)	320		538				858			347		390				737		(49		)		275		93				10		(13		)	(47		)		1,864			509				(109		)	2,264
Interest expense, net	1		1				2			—		—				—		—				—		—				—		7			36				45			150				130			325
Provision for (benefit from) income taxes	—		—				—			130		137				267		(15		)		57		—				—		—			—				309			—				376			685
Capital expenditures	533		94				627			791		48				839		479				60		33				2		6			27				2,073			1,484				5			3,562

a. The first six months of 2014 include the results of the Candelaria and Ojos del Salado mining operations, which were sold in November 2014.

b. The first six months of 2014 include the results from Eagle Ford, which was sold in June 2014.

c. Includes PT-FI’s sales to PT Smelting totaling $643 million for the first six months of 2015 and $913 million for the first six months of 2014.

d. Includes revenues from FCX's molybdenum sales company, which includes sales of molybdenum produced by the Molybdenum mines and by certain of the North and South America copper mines.

e. Includes net mark-to-market gains (losses) associated with crude oil and natural gas derivative contracts totaling $58 million for the first six months2015 and $(120) million for the first six months of 2014.

f. Amounts include net reductions for provisional pricing adjustments to prior period open sales. There were no intersegment sales from El Abra or Grasberg for the first six months of 2015.

g. Includes LCM inventory adjustments totaling $11 million at other North America copper mines, $3 million at Molybdenum mines and $49 million at other mining & eliminations (see Note 4).

22

NOTE 11. GUARANTOR FINANCIAL STATEMENTS

All of the senior notes issued by FCX are fully and unconditionally guaranteed on a senior basis jointly and severally by Freeport-McMoRan Oil & Gas LLC (FM O&G LLC), as guarantor, which is a 100 percent owned subsidiary of FM O&G and FCX. The guarantee is an unsecured obligation of the guarantor and ranks equal in right of payment with all existing and future indebtedness of FM O&G LLC, including indebtedness under the revolving credit facility. The guarantee ranks senior in right of payment with all of FM O&G LLC's future subordinated obligations and is effectively subordinated in right of payment to any debt of FM O&G LLC's subsidiaries. The indentures provide that FM O&G LLC's guarantee may be released or terminated for certain obligations under the following circumstances: (i) all or substantially all of the equity interests or assets of FM O&G LLC are sold to a third party; or (ii) FM O&G LLC no longer has any obligations under any FM O&G senior notes or any refinancing thereof and no longer guarantees any obligations of FCX under the revolver, the Term Loan or any other senior debt.

The following condensed consolidating financial information includes information regarding FCX, as issuer, FM O&G LLC, as guarantor, and all other non-guarantor subsidiaries of FCX. Included are the condensed consolidating balance sheets at June 30, 2015, and December 31, 2014, and the related condensed consolidating statements of comprehensive (loss) income for the three and six months ended June 30, 2015 and 2014, and condensed consolidating statements of cash flows for the six months ended June 30, 2015 and 2014 (in millions), which should be read in conjunction with FCX's notes to the consolidated financial statements.

CONDENSED CONSOLIDATING BALANCE SHEET

June 30, 2015

	FCX			FM O&G LLC		Non-guarantor					Consolidated
	Issuer			Guarantor		Subsidiaries		Eliminations			FCX
ASSETS
Current assets	$	257		$	2,900	$	9,665	$	(4,125	)	$	8,697
Property, plant, equipment and mining development costs, net	20			51		27,024		—			27,095
Oil and gas properties, net - full cost method:
Subject to amortization, less accumulated amortization	—			1,507		3,142		—			4,649
Not subject to amortization	—			2,649		6,659		4			9,312
Investments in consolidated subsidiaries	24,153			2,216		4,019		(30,388		)	—
Other assets	9,991			4,703		4,179		(14,618		)	4,255
Total assets	$	34,421		$	14,026	$	54,688	$	(49,127	)	$	54,008
LIABILITIES AND EQUITY
Current liabilities	$	3,106		$	433	$	5,325	$	(4,125	)	$	4,739
Long-term debt, less current portion	15,841			5,181		10,221		(11,132		)	20,111
Deferred income taxes	1,613		a	—		3,257		—			4,870
Environmental and asset retirement obligations, less current portion	—			307		3,409		—			3,716
Other liabilities	56			3,361		1,829		(3,486		)	1,760
Total liabilities	20,616			9,282		24,041		(18,743		)	35,196
Redeemable noncontrolling interest	—			—		757		—			757
Equity:
Stockholders' equity	13,805			4,744		26,173		(30,917		)	13,805
Noncontrolling interests	—			—		3,717		533			4,250
Total equity	13,805			4,744		29,890		(30,384		)	18,055
Total liabilities and equity	$	34,421		$	14,026	$	54,688	$	(49,127	)	$	54,008

a. All U.S. related deferred income taxes are recorded at the parent company.

23

CONDENSED CONSOLIDATING BALANCE SHEET

December 31, 2014

	FCX			FM O&G LLC		Non-guarantor					Consolidated
	Issuer			Guarantor		Subsidiaries		Eliminations			FCX
ASSETS
Current assets	$	323		$	2,635	$	8,659	$	(2,572	)	$	9,045
Property, plant, equipment and mining development costs, net	22			46		26,152		—			26,220
Oil and gas properties, net - full cost method:
Subject to amortization, less accumulated amortization	—			3,296		5,907		(16		)	9,187
Not subject to amortization	—			2,447		7,640		—			10,087
Investments in consolidated subsidiaries	28,765			6,460		10,246		(45,471		)	—
Other assets	8,914			3,947		4,061		(12,787		)	4,135
Total assets	$	38,024		$	18,831	$	62,665	$	(60,846	)	$	58,674
LIABILITIES AND EQUITY
Current liabilities	$	1,592		$	560	$	5,592	$	(2,572	)	$	5,172
Long-term debt, less current portion	14,930			3,874		8,879		(9,312		)	18,371
Deferred income taxes	3,161		a	—		3,237		—			6,398
Environmental and asset retirement obligations, less current portion	—			302		3,345		—			3,647
Other liabilities	54			3,372		1,910		(3,475		)	1,861
Total liabilities	19,737			8,108		22,963		(15,359		)	35,449
Redeemable noncontrolling interest	—			—		751		—			751
Equity:
Stockholders' equity	18,287			10,723		35,268		(45,991		)	18,287
Noncontrolling interests	—			—		3,683		504			4,187
Total equity	18,287			10,723		38,951		(45,487		)	22,474
Total liabilities and equity	$	38,024		$	18,831	$	62,665	$	(60,846	)	$	58,674

a. All U.S. related deferred income taxes are recorded at the parent company.

24

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE (LOSS) INCOME

Three Months Ended June 30, 2015
	FCX			FM O&G LLC				Non-guarantor							Consolidated
	Issuer			Guarantor				Subsidiaries				Eliminations			FCX
Revenues	$	—		$	169			$	4,079			$	—		$	4,248
Total costs and expenses	19			1,217			a	5,383			a	3			6,622
Operating (loss) income	(19		)	(1,048		)		(1,304		)		(3		)	(2,374		)
Interest expense, net	(121		)	(2		)		(67		)		41			(149		)
Other income (expense), net	127			—				(56		)		(34		)	37
(Loss) income before income taxes and equity in affiliated companies' net (losses) earnings	(13		)	(1,050		)		(1,427		)		4			(2,486		)
(Provision for) benefit from income taxes	(265		)	374				580				(2		)	687
Equity in affiliated companies' net (losses) earnings	(1,573		)	(1,920		)		(2,972		)		6,465			—
Net (loss) income	(1,851		)	(2,596		)		(3,819		)		6,467			(1,799		)
Net income and preferred dividends attributable to noncontrolling interests	—			—				(38		)		(14		)	(52		)
Net (loss) income attributable to common stockholders	$	(1,851	)	$	(2,596	)		$	(3,857	)		$	6,453		$	(1,851	)
Other comprehensive income (loss)	9			—				9				(9		)	9
Total comprehensive (loss) income	$	(1,842	)	$	(2,596	)		$	(3,848	)		$	6,444		$	(1,842	)

a. Includes charges totaling $1.0 billion at the FM O&G LLC guarantor and $1.7 billion at the non-guarantor subsidiaries related to ceiling test impairment of FCX's oil and gas properties pursuant to full cost accounting rules.

Six Months Ended June 30, 2015
	FCX			FM O&G LLC				Non-guarantor							Consolidated
	Issuer			Guarantor				Subsidiaries				Eliminations			FCX
Revenues	$	—		$	350			$	8,051			$	—		$	8,401
Total costs and expenses	35			2,535			a	11,181			a	(13		)	13,738
Operating (loss) income	(35		)	(2,185		)		(3,130		)		13			(5,337		)
Interest expense, net	(236		)	(6		)		(124		)		71			(295		)
Other income (expense), net	156			—				(48		)		(64		)	44
(Loss) income before income taxes and equity in affiliated companies' net (losses) earnings	(115		)	(2,191		)		(3,302		)		20			(5,588		)
(Provision for) benefit from income taxes	(686		)	790				1,286				(8		)	1,382
Equity in affiliated companies' net (losses) earnings	(3,524		)	(4,279		)		(6,502		)		14,306			1
Net (loss) income	(4,325		)	(5,680		)		(8,518		)		14,318			(4,205		)
Net income and preferred dividends attributable to noncontrolling interests	—			—				(94		)		(26		)	(120		)
Net (loss) income attributable to common stockholders	$	(4,325	)	$	(5,680	)		$	(8,612	)		$	14,292		$	(4,325	)
Other comprehensive income (loss)	21			—				21				(21		)	21
Total comprehensive (loss) income	$	(4,304	)	$	(5,680	)		$	(8,591	)		$	14,271		$	(4,304	)

a. Includes charges totaling $2.1 billion at the FM O&G LLC guarantor and $3.7 billion at the non-guarantor subsidiaries related to ceiling test impairment of FCX's oil and gas properties pursuant to full cost accounting rules.

25

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

Three Months Ended June 30, 2014
	FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Revenues	$	—		$	570		$	4,952		$	—		$	5,522
Total costs and expenses	21			489			3,865			(6		)	4,369
Operating (loss) income	(21		)	81			1,087			6			1,153
Interest expense, net	(87		)	(44		)	(51		)	18			(164		)
Net (loss) gain on early extinguishment of debt	(1		)	6			—			—			5
Other income (expense), net	17			1			(8		)	(18		)	(8		)
(Loss) income before income taxes and equity in affiliated companies' net earnings (losses)	(92		)	44			1,028			6			986
Benefit from (provision for) income taxes	26			26			(378		)	(2		)	(328		)
Equity in affiliated companies' net earnings (losses)	548			126			154			(826		)	2
Net income (loss)	482			196			804			(822		)	660
Net income and preferred dividends attributable to noncontrolling interests	—			—			(180		)	2			(178		)
Net income (loss) attributable to common stockholders	$	482		$	196		$	624		$	(820	)	$	482
Other comprehensive income (loss)	1			—			1			(1		)	1
Total comprehensive income (loss)	$	483		$	196		$	625		$	(821	)	$	483

Six Months Ended June 30, 2014
	FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Revenues	$	—		$	1,214		$	9,293		$	—		$	10,507
Total costs and expenses	32			1,015			7,204			(8		)	8,243
Operating (loss) income	(32		)	199			2,089			8			2,264
Interest expense, net	(169		)	(85		)	(109		)	38			(325		)
Net (loss) gain on early extinguishment of debt	(1		)	6			—			—			5
Other income (expense), net	37			1			25			(38		)	25
(Loss) income before income taxes and equity in affiliated companies' net earnings (losses)	(165		)	121			2,005			8			1,969
Benefit from (provision for) income taxes	5			(17		)	(670		)	(3		)	(685		)
Equity in affiliated companies' net earnings (losses)	1,152			256			339			(1,745		)	2
Net income (loss)	992			360			1,674			(1,740		)	1,286
Net income and preferred dividends attributable to noncontrolling interests	—			—			(291		)	(3		)	(294		)
Net income (loss) attributable to common stockholders	$	992		$	360		$	1,383		$	(1,743	)	$	992
Other comprehensive income (loss)	4			—			4			(4		)	4
Total comprehensive income (loss)	$	996		$	360		$	1,387		$	(1,747	)	$	996

26

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Six Months Ended June 30, 2015

	FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Cash flow from operating activities:
Net (loss) income	$	(4,325	)	$	(5,680	)	$	(8,518	)	$	14,318		$	(4,205	)
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	2			223			1,638			(34		)	1,829
Impairment of oil and gas properties	—			2,052			3,717			21			5,790
Net gains on crude oil derivative contracts	—			(58		)	—			—			(58		)
Equity in losses (earnings) of consolidated subsidiaries	3,524			4,279			6,502			(14,306		)	(1		)
Other, net	(1,431		)	9			43			—			(1,379		)
Changes in working capital and other tax payments	2,222			(550		)	(1,870		)	8			(190		)
Net cash (used in) provided by operating activities	(8		)	275			1,512			7			1,786
Cash flow from investing activities:
Capital expenditures	—			(734		)	(2,787		)	(7		)	(3,528		)
Intercompany loans	(1,073		)	(794		)	—			1,867			—
Dividends from (investments in) consolidated subsidiaries	438			(31		)	74			(481		)	—
Other, net	(10		)	(1		)	137			10			136
Net cash (used in) provided by investing activities	(645		)	(1,560		)	(2,576		)	1,389			(3,392		)
Cash flow from financing activities:
Proceeds from debt	2,735			—			1,687			—			4,422
Repayments of debt	(1,690		)	—			(670		)	—			(2,360		)
Intercompany loans	—			1,321			546			(1,867		)	—
Cash dividends and distributions paid, and contributions received	(380		)	—			(481		)	421			(440		)
Other, net	(12		)	(37		)	(15		)	50			(14		)
Net cash provided by (used in) financing activities	653			1,284			1,067			(1,396		)	1,608
Net (decrease) increase in cash and cash equivalents	—			(1		)	3			—			2
Cash and cash equivalents at beginning of period	—			1			463			—			464
Cash and cash equivalents at end of period	$	—		$	—		$	466		$	—		$	466

27

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Six Months Ended June 30, 2014

	FCX			FM O&G LLC			Non-guarantor							Consolidated
	Issuer			Guarantor			Subsidiaries				Eliminations			FCX
Cash flow from operating activities:
Net income (loss)	$	992		$	360		$	1,674			$	(1,740	)	$	1,286
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	2			545			1,440				(8		)	1,979
Net losses on crude oil and natural gas derivative contracts	—			120			—				—			120
Net gain (loss) on early extinguishment of debt	1			(6		)	—				—			(5		)
Equity in (earnings) losses of consolidated subsidiaries	(1,152		)	(256		)	39				1,367			(2		)
Other, net	121			(12		)	(123		)		—			(14		)
Changes in working capital and other tax payments	(164		)	(2,165		)	1,552				—			(777		)
Net cash (used in) provided by operating activities	(200		)	(1,414		)	4,582				(381		)	2,587
Cash flow from investing activities:
Capital expenditures	—			(897		)	(2,665		)		—			(3,562		)
Acquisition of Deepwater GOM interests	—			—			(925		)		—			(925		)
Intercompany loans	1,318			1,629			—			—	(2,947		)	—
(Investments in) dividends from consolidated subsidiaries	(364		)	(96		)	1,079				(619		)	—
Net proceeds from sale of Eagle Ford shale assets	—			3,009			—				—			3,009
Other, net	—			(381		)	18				—			(363		)
Net cash provided by (used in) investing activities	954			3,264			(2,493		)		(3,566		)	(1,841		)
Cash flow from financing activities:
Proceeds from debt	890			—			358				—			1,248
Repayments of debt	(990		)	(224		)	(397		)		—			(1,611		)
Intercompany loans	—			(170		)	(2,777		)		2,947			—
Cash dividends and distributions paid, and contributions received	(653		)	(1,453		)	203				1,000			(903		)
Other, net	(1		)	(2		)	(4		)		—			(7		)
Net cash (used in) provided by financing activities	(754		)	(1,849		)	(2,617		)		3,947			(1,273		)
Net increase (decrease) in cash and cash equivalents	—			1			(528		)		—			(527		)
Cash and cash equivalents at beginning of period	—			—			1,985				—			1,985
Cash and cash equivalents at end of period	$	—		$	1		$	1,457			$	—		$	1,458

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NOTE 12. NEW ACCOUNTING STANDARDS

In April 2015, the Financial Accounting Standards Board issued an Accounting Standards Update (ASU) to simplify the presentation of debt issuance costs. This ASU requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. For public entities, this ASU is effective for annual periods beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption is permitted for financial statements that have not been previously issued. FCX adopted this ASU in first-quarter 2015 and retrospectively adjusted its previously issued financial statements. Upon adoption, FCX adjusted its December 31, 2014, balance sheet by decreasing other assets and long-term debt by $121 million for debt issuance costs related to corresponding debt balances. FCX elected to continue presenting debt issuance costs for its revolving credit facility as a deferred charge (asset) because of the volatility of its borrowings and repayments under the facility.

NOTE 13. SUBSEQUENT EVENTS

As reported in Note 13 of FCX's annual report on Form 10-K for the year ended December 31, 2014, PT-FI entered into a Memorandum of Understanding (MOU) with the Indonesian government in July 2014. Under the MOU, PT-FI provided a $115 million assurance bond to support its commitment for smelter development, agreed to increased royalty rates and agreed to pay export duties (which were set at 7.5 percent, declining to 5.0 percent when smelter development progress exceeds 7.5 percent and are eliminated when development progress exceeds 30 percent). The MOU also anticipated an amendment of the COW within six months to address other matters; however, no terms of the COW other than those relating to the smelter bond, increased royalties and export duties were changed. In January 2015, the MOU was extended to July 25, 2015, and it expired on that date. The increased royalty rates, export duties and smelter assurance bond remain in effect.

PT-FI is also required to apply for renewal of export permits at six-month intervals. On July 29, 2015, PT-FI's export permit was renewed through January 28, 2016. In connection with the renewal, export duties were reduced to 5.0 percent, as a result of smelter development progress.

FCX evaluated events after June 30, 2015, and through the date the consolidated financial statements were issued, and determined any events or transactions occurring during this period that would require recognition or disclosure are appropriately addressed in these consolidated financial statements.

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REVIEW REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

TO THE BOARD OF DIRECTORS AND STOCKHOLDERS OF

FREEPORT-McMoRan INC.

We have reviewed the condensed consolidated balance sheet of Freeport-McMoRan Inc. (formerly Freeport-McMoRan Copper & Gold Inc.) as of June 30, 2015, and the related consolidated statements of operations and comprehensive (loss) income for the three- and six-month periods ended June 30, 2015 and 2014, the consolidated statements of cash flows for the six-month periods ended June 30, 2015 and 2014, and the consolidated statement of equity for the six-month period ended June 30, 2015. These financial statements are the responsibility of the Company’s management.

We conducted our review in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our review, we are not aware of any material modifications that should be made to the condensed consolidated financial statements referred to above for them to be in conformity with U.S. generally accepted accounting principles.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of Freeport-McMoRan Inc. as of December 31, 2014, and the related consolidated statements of operations, comprehensive (loss) income, cash flows and equity for the year then ended (not presented herein) and we expressed an unqualified audit opinion on those consolidated financial statements in our report dated February 27, 2015. In our opinion, the accompanying condensed consolidated balance sheet of Freeport-McMoRan Inc. as of December 31, 2014, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

/s/ ERNST & YOUNG LLP

Phoenix, Arizona

August 10, 2015

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Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

In Management’s Discussion and Analysis of Financial Condition and Results of Operations, "we," "us" and "our" refer to Freeport-McMoRan Inc. (FCX) and its consolidated subsidiaries. You should read this discussion in conjunction with our financial statements, the related Management’s Discussion and Analysis of Financial Condition and Results of Operations and the discussion of our Business and Properties in our annual report on Form 10-K for the year ended December 31, 2014, filed with the United States (U.S.) Securities and Exchange Commission (SEC). The results of operations reported and summarized below are not necessarily indicative of future operating results (refer to "Cautionary Statement" for further discussion). References to "Notes" are Notes included in our Notes to Consolidated Financial Statements. Throughout Management's Discussion and Analysis of Financial Condition and Results of Operations, all references to earnings or losses per share are on a diluted basis.

OVERVIEW

We are a premier U.S.-based natural resources company with an industry-leading global portfolio of mineral assets, significant oil and gas resources and a growing production profile. We are the world's largest publicly traded copper producer. Our portfolio of assets includes the Grasberg minerals district in Indonesia, one of the world's largest copper and gold deposits; significant mining operations in North and South America; the Tenke Fungurume (Tenke) minerals district in the Democratic Republic of Congo (DRC) in Africa; and significant U.S. oil and natural gas assets, including reserves in the Deepwater Gulf of Mexico (GOM), onshore and offshore California, the Haynesville shale play in Louisiana, the Madden area in Central Wyoming and a position in the Inboard Lower Tertiary/Cretaceous natural gas trend onshore in South Louisiana.

Our results for the second quarter and first six months of 2015, compared with 2014 periods, reflect lower commodity price realizations and lower oil sales volumes, partly offset by higher gold sales volumes. The first six months of 2015 also reflects higher copper sales volumes, compared with the first six months of 2014. Results for the 2015 periods were impacted by net charges of $2.7 billion ($2.0 billion to net loss attributable to common stockholders) in second-quarter 2015 and $5.8 billion ($4.4 billion to net loss attributable to common stockholders) for the first six months of 2015, for the impairment of our oil and gas properties pursuant to full cost accounting rules and the related tax charges to establish a deferred tax valuation allowance. Refer to “Consolidated Results” for further discussion of our consolidated financial results for the three- and six-month periods ended June 30, 2015 and 2014.

At June 30, 2015, we had $466 million in consolidated cash and cash equivalents and $20.9 billion in total debt. We have made substantial progress toward the completion of our major mining development projects, which are expected to result in increased near-term production, lower unit costs, declining capital expenditures and to contribute to cash flow from operations after capital expenditures in future years. In addition, positive oil and gas drilling and development activities are expected to result in a growing oil production profile. We remain focused on maintaining a strong balance sheet and on continuing to manage costs, capital spending plans and other actions as required to maintain financial strength.

Subsequent to June 30, 2015, copper and molybdenum prices have fallen and at July 31, 2015, prices we would expect to record additional charges for LCM inventory adjustments in third-quarter 2015. Additionally, as further discussed in “Critical Accounting Estimates” in Part II, Items 7. And 7A. of our annual report on Form 10-K for the year ended December 31, 2014, we regularly assess the carrying values of our long-lived mining assets, and decreases in metal prices or other factors may result in impairment of our long-lived mining assets. Also, refer to "Operations - Oil and Gas" for further discussion of potentially significant additional ceiling test impairments of our oil and gas properties.

In July 2015, we announced that we are undertaking a comprehensive review of operating plans in our mining and oil and gas businesses to target significant additional reductions in capital spending and operating and administrative costs in response to weak market conditions for our major products. On August 5, 2015, we provided an update on our progress and announced the deferral of investments in several long-term projects in our oil and gas business, which will result in a reduction of $0.9 billion in projected capital expenditures for each of the years 2016 and 2017. We have also revised our estimate of the start-up of initial production from its recent drilling success in the Horn Mountain area to 2016 from the previously estimated start-up in 2017. The revised plans, together with the previously announced potential initial public offering (IPO) of a minority interest in our wholly owned subsidiary, Freeport-McMoRan Oil & Gas Inc., and potential other actions, will be pursued as required to

31

fund oil and gas capital spending with cash flow for 2016 and subsequent years. Refer to “Operations - Oil and Gas” for further discussion of the potential IPO.

We are completing the review of operating plans at each of our copper and molybdenum mining operations and will revise operating and capital plans to strengthen our financial position in a weak copper price environment. The revised plans will target lower operating and capital costs to achieve maximum cash flow under the current market conditions. Production at certain operations challenged by low commodity prices will be curtailed. We expect to complete this review promptly and will report our revised plans during third-quarter 2015. We will also continue to assess opportunities to partner with strategic investors potentially interested in investing capital with FCX in the development of our oil and gas and mining properties. We have a broad set of assets with valuable infrastructure and associated resources with attractive long-term production and development potential.

OUTLOOK

We view the long-term outlook for our business positively, supported by limitations on supplies of copper and by the requirements for copper and oil in the world’s economy. Our financial results vary as a result of fluctuations in market prices primarily for copper, gold, molybdenum and oil, as well as other factors. World market prices for these commodities have fluctuated historically and are affected by numerous factors beyond our control. Because we cannot control the price of our products, the key measures that management focuses on in operating our business are sales volumes, unit net cash costs for our mining operations, cash production costs per barrel of oil equivalent (BOE) for our oil and gas operations and operating cash flow. As discussed above in "Overview," we are undertaking a comprehensive review of operating plans in our mining business to target significant additional reductions in capital spending, and operating and administrative costs, which we expect to report during third-quarter 2015. Accordingly, the following outlook is subject to change as a result of the review and other factors.

Sales Volumes.  Following are our projected consolidated sales volumes for the year 2015:

Copper (millions of recoverable pounds):
North America copper mines	1,960
South America mining	900
Indonesia mining	860
Africa mining	460
	4,180
Gold (thousands of recoverable ounces)	1,300
Molybdenum (millions of recoverable pounds)	93	a
Oil Equivalents (million BOE or MMBOE)	52.9

a. Projected molybdenum sales include 44 million pounds produced by our Molybdenum mines and 49 million pounds produced by our North and South America copper mines.

Consolidated sales for third-quarter2015 are expected to approximate 1.0 billion pounds of copper, 315 thousand ounces of gold, 24 million pounds of molybdenum and 13.6 MMBOE. Projected sales volumes are dependent on a number of factors, including operational performance and other factors. For other important factors that could cause results to differ materially from projections, refer to "Cautionary Statement."

Mining Unit Net Cash Costs. Assuming average prices of $1,150 per ounce of gold and $6 per pound of molybdenum for the second half of2015, and achievement of current sales volume and cost estimates, consolidated unit net cash costs (net of by-product credits) for our copper mines are expected to average $1.53 per pound of copper for the year 2015. Quarterly unit net cash costs vary with fluctuations in sales volumes and average realized prices (primarily gold and molybdenum prices). The impact of price changes for the second half of 2015 on consolidated unit net cash costs would approximate $0.01 per pound for each $50 per ounce change in the average price of gold and $0.01 per pound for each $2 per pound change in the average price of molybdenum. Refer to “Consolidated Results – Production and Delivery Costs” for further discussion of consolidated production and delivery costs for our mining operations.

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Oil and Gas Cash Production Costs per BOE. Based on current sales volume and cost estimates for the second half of2015, oil and gas cash production costs are expected to approximate $20 per BOE for the year 2015. Refer to “Operations – Oil and Gas” for further discussion of oil and gas production costs.

Consolidated Operating Cash Flow. Our consolidated operating cash flows vary with prices realized from copper, gold, molybdenum and oil sales, sales volumes, production costs, income taxes (refer to “Consolidated Results – Income Taxes” for further discussion of projected income taxes), other working capital changes and other factors. Based on current sales volume and cost estimates, and assuming average prices of $2.50 per pound of copper, $1,150 per ounce of gold, $6 per pound of molybdenum and $56 per barrel of Brent crude oil for the second half of2015, consolidated operating cash flows are estimated to approximate $3.6 billion for the year 2015. The impact of price changes during the second half of2015 on operating cash flows would approximate $190 million for each $0.10 per pound change in the average price of copper, $25 million for each $50 per ounce change in the average price of gold, $60 million for each $2 per pound change in the average price of molybdenum and $55 million for each $5 per barrel change in the average Brent crude oil price.

MARKETS

Metals.World prices for copper, gold and molybdenum can fluctuate significantly. During the period from January 2005 through July 2015, the London Metal Exchange (LME) spot copper price varied from a low of $1.26 per pound in 2008 to a record high of $4.60 per pound in 2011; the London Bullion Market Association (London) PM gold price fluctuated from a low of $411 per ounce in 2005 to a record high of $1,895 per ounce in 2011; and the Metals Week Molybdenum Dealer Oxide weekly average price ranged from a low of $5.87 per pound in 2015 to a record high of $39.25 per pound in 2005. Copper, gold and molybdenum prices are affected by numerous factors beyond our control as described further in our “Risk Factors” contained in Part I, Item 1A of our annual report on Form 10-K for the year ended December 31, 2014.

This graph presents LME spot copper prices and the combined reported stocks of copper at the LME, Commodity Exchange Inc., a division of the New York Mercantile Exchange (NYMEX), and the Shanghai Futures Exchange from January 2005 through July 2015. From 2006 through most of 2008, limited supplies, combined with growing demand from China and other emerging economies, resulted in high copper prices and low levels of inventories. We believe current copper prices are supported by a combination of demand from developing economies and pro-growth monetary fiscal policy decisions in Europe, China and the U.S. Since mid-2014, copper prices have declined because of concerns about slowing growth rates in China, a stronger U.S. dollar and a broad-based decline in commodity prices. Renewed concerns about Chinese economic growth rates, concerns about Europe, continued U.S. dollar strength and broad-based weakness in commodity prices in general put downward pressure on copper prices during second-quarter 2015. LME spot copper prices ranged from a low of $2.56 per pound to a high of

33

$2.92 per pound during second-quarter2015, averaged $2.74 per pound and closed at $2.60 per pound on June 30, 2015. LME spot copper prices have declined further during July 2015, closing at $2.37 per pound on July 31, 2015.

We believe the underlying long-term fundamentals of the copper business remain positive, supported by the significant role of copper in the global economy and a challenging long-term supply environment attributable to difficulty in replacing existing large mines' output with new production sources. Future copper prices are expected to be volatile and are likely to be influenced by demand from China and emerging markets, as well as economic activity in the U.S. and other industrialized countries, the timing of the development of new supplies of copper, and production levels of mines and copper smelters.

This graph presents London PM gold prices from January 2005 through July 2015. An improving economic outlook and positive equity performance contributed to lower demand for gold in 2014 and early 2015, resulting in generally lower prices. During second-quarter2015, London PM gold prices ranged from a low of $1,165 per ounce to a high of $1,225 per ounce, averaged $1,192 per ounce and closed at $1,171 per ounce on June 30, 2015. Gold prices have declined further during 2015 and closed at $1,098 per ounce on July 31, 2015.

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This graph presents the Metals Week Molybdenum Dealer Oxide weekly average prices from January 2005 through July 2015. Molybdenum prices have declined since mid-2014 because of weaker demand from European and U.S. steel and stainless steel producers. During second-quarter2015, the weekly average price of molybdenum ranged from a low of $6.38 per pound to a high of $8.24 per pound, averaged $7.57 per pound and was $6.38 on June 30, 2015. The Metals Week Molybdenum Dealer Oxide weekly average price has declined further during July 2015 and was $5.87 per pound on July 31, 2015.

Oil and Gas.Market prices for crude oil and natural gas can fluctuate significantly. During the period from January 2005 through July 2015, the Brent crude oil price ranged from a low of $36.61 per barrel to a high of $146.08 per barrel in 2008 and the NYMEX natural gas price fluctuated from a low of $2.04 per million British thermal units (MMBtu) in 2012 to a high of $13.91 per MMBtu in 2005. Crude oil and natural gas prices are affected by numerous factors beyond our control as described further in our “Risk Factors” contained in Part I, Item 1A. of our annual report on Form 10-K for the year ended December 31, 2014.

This graph presents Brent crude oil prices and NYMEX natural gas contract prices from January 2005 through July 2015. Crude oil prices reached a record high in July 2008 as economic growth in emerging economies and the U.S. created high global demand for oil and lower inventories. By the end of 2008, financial turmoil in the U.S. contributed to a global economic slowdown and a decline in many commodity prices. Crude oil prices rebounded

after 2008, supported by a gradually improving global economy and demand outlook. Since mid-2014, oil prices have significantly declined associated with global oversupply primarily attributable to continued strong production from U.S. shale plays, the Organization of Petroleum Exporting Countries and Russia, coupled with weak economic data in Europe and slowing Chinese demand. During second-quarter2015, Brent crude oil prices ranged from a low of $54.95 per barrel to a high of $67.77 per barrel, averaged $63.57 per barrel and were $63.59 per barrel on June 30, 2015. The Brent crude oil price has declined further during July 2015 and was $52.21 per barrel on July 31, 2015.

35

CONSOLIDATED RESULTS

	Three Months Ended							Six Months Ended
	June 30,							June 30,
	2015				2014a			2015				2014a
SUMMARY FINANCIAL DATA	(in millions, except per share amounts)
Revenuesb,c,d	$	4,248			$	5,522		$	8,401			$	10,507
Operating (loss) incomeb,c,d	$	(2,374	)	e,f,g	$	1,153	h,i	$	(5,337	)	e,f,g,j	$	2,264	h,i
Net (loss) income attributable to common stockc,d,k	$	(1,851	)	e,f,g,l,m	$	482	h,i,n	$	(4,325	)	e,f,g,j,l,m	$	992	h,i,n
Diluted net (loss) income per share attributable to common stock	$	(1.78	)	e,f,g,l,m	$	0.46	h,i,n	$	(4.16	)	e,f,g,j,l,m	$	0.95	h,i,n
Diluted weighted-average common shares outstanding	1,040				1,045			1,040				1,045
Operating cash flowso	$	1,069			$	1,386		$	1,786			$	2,587
Capital expenditures	$	1,661			$	1,950		$	3,528			$	3,562
At June 30:
Cash and cash equivalents	$	466			$	1,458		$	466			$	1,458
Total debt, including current portion	$	20,902			$	20,190		$	20,902			$	20,190

a. Includes the results of the Candelaria and Ojos del Salado mines that were sold in November 2014, and the Eagle Ford properties that were sold in June 2014.

b.As further detailed in Note 10, following is a summary of revenues and operating income (loss) by operating division (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
Revenues	2015			2014			2015			2014
North America copper mines	$	1,405		$	1,469		$	2,740		$	2,755
South America mining	453			1,031			939			1,929
Indonesia mining	790			523			1,397			993
Africa mining	351			418			761			745
Molybdenum mines	102			170			215			296
Rod & Refining	1,097			1,242			2,166			2,396
Atlantic Copper Smelting & Refining	500			629			1,046			1,222
U.S. oil & gas operations	569			1,236			1,069			2,497
Other mining, corporate, other & eliminations	(1,019		)	(1,196		)	(1,932		)	(2,326		)
Total revenues	$	4,248		$	5,522		$	8,401		$	10,507
Operating income (loss)
North America copper mines	$	300		$	468		$	594		$	858
South America mining	65			404			130			737
Indonesia mining	232			(67		)	305			(49		)
Africa mining	101			154			200			275
Molybdenum mines	(7		)	65			(3		)	93
Rod & Refining	6			6			10			10
Atlantic Copper Smelting & Refining	19			(4		)	31			(13		)
U.S. oil & gas operations	(2,932		)	232			(6,403		)	509
Other mining, corporate, other & eliminations	(158		)	(105		)	(201		)	(156		)
Total operating (loss) income	$	(2,374	)	$	1,153		$	(5,337	)	$	2,264

c. Includes (unfavorable) favorable adjustments to provisionally priced concentrate and cathode copper sales recognized in prior periods totaling $(20) million ($(10) million to net loss attributable to common stock or $(0.01) per share) for second-quarter2015, $35 million ($16 million to net income attributable to common stock or $0.01 per share) for second-quarter2014, $(106) million ($(50) million to net loss attributable to common stock or $(0.05) per share) for the first six months of 2015 and $(118) million ($(65) million to net income attributable to common stock or $(0.06) per share) for the first six months of 2014. Refer to “Revenues” for further discussion. 

d. Includes net noncash mark-to-market (losses) gains associated with crude oil and natural gas derivative contracts totaling $(95) million ($(59) million to net loss attributable to common stock or $(0.06) per share) for second-quarter2015, $(7) million ($(4) million to net income attributable to common stock or less than $(0.01) per share) for second-quarter2014, $(143) million ($(89) million to net loss attributable to common stock or $(0.09) per share) for the first six months of 2015

36

and $8 million ($5 million to net income attributable to common stock or less than $0.01 per share) for the first six months of 2014. Refer to "Revenues" for further discussion.

e. Includes charges to reduce the carrying value of oil and gas properties pursuant to full cost accounting rules of $2.7 billion ($1.7 billion to net loss attributable to common stock or $1.61 per share) for second-quarter2015 and $5.8 billion ($3.6 billion to net loss attributable to common stock or $3.47 per share) for the first six months of 2015. See Note 1 and "Operations - Oil & Gas" for further discussion.

f. Includes charges for lower of cost or market (LCM) adjustments primarily attributable to molybdenum inventories totaling $59 million ($38 million to net loss attributable to common stock or $0.04 per share) for second-quarter2015 and $63 million ($41 million to net loss attributable to common stock or $0.04 per share) for the first six months of 2015. See Note 4 for further discussion.

g. Includes net charges for idle/terminated rig costs and inventory write-downs at oil and gas operations of $22 million ($14 million to net loss attributable to common stock or $0.01 per share) for second-quarter2015 and $39 million ($24 million to net loss attributable to common stock or $0.02 per share) for the first six months of 2015.

h. Includes net charges for adjustments to environmental obligations and related litigation reserves of $69 million ($68 million to net income attributable to common stock or $0.06 per share) for the second quarter and first six months of 2014.

i. Includes charges for fixed costs charged directly to cost of sales as a result of the impact of export restrictions on PT Freeport Indonesia's (PT-FI) operating rates of $56 million ($30 million to net income attributable to common stock or $0.03 per share) for second-quarter2014 and $109 million ($58 million to net income attributable to common stock or $0.06 per share) for the first six months of 2014.

j. The first six months of 2015 includes a net gain of $39 million ($25 million to net loss attributable to common stock or $0.02 per share) associated with the sale of FCX's one-third interest in the Luna Energy power facility in New Mexico.

k. We defer recognizing profits on intercompany sales until final sales to third parties occur. For a summary of net impacts from changes in these deferrals, refer to "Operations - Smelting & Refining."

l. The second quarter and first six months of 2015 include a gain of $92 million ($0.09 per share) related to net proceeds received from insurance carriers and other third parties related to the shareholder derivative litigation settlement.

m. As a result of the impairment to oil and gas properties, we recorded tax charges to establish a valuation allowance primarily against U.S. federal alternative minimum tax credits of $305 million ($0.29 per share) for second-quarter2015 and $763 million ($0.73 per share) for the first six months of 2015.

n. The second quarter and first six months of 2014 included a tax charge of $58 million ($0.06 per share) associated with deferred taxes recorded in connection with the allocation of goodwill to the sale of Eagle Ford.

o. Includes net working capital uses and changes in other tax payments of $104 million for second-quarter2015, $364 million for second-quarter2014, $190 million for the first six months of 2015, and $777 million for the first six months of 2014.

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	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2015		2014a		2015		2014a
SUMMARY OPERATING DATA
Copper
Production (millions of recoverable pounds)	977		931		1,892		1,879
Sales, excluding purchases (millions of recoverable pounds)	964		968		1,924		1,839
Average realized price per pound	$	2.71	$	3.16	$	2.70	$	3.17
Site production and delivery costs per poundb	$	1.85	$	1.99	$	1.89	$	1.94
Unit net cash costs per poundb	$	1.50	$	1.72	$	1.57	$	1.64
Gold
Production (thousands of recoverable ounces)	367		166		626		397
Sales, excluding purchases (thousands of recoverable ounces)	352		159		615		346
Average realized price per ounce	$	1,174	$	1,296	$	1,183	$	1,299
Molybdenum
Production (millions of recoverable pounds)	25		25		49		49
Sales, excluding purchases (millions of recoverable pounds)	23		25		46		52
Average realized price per pound	$	9.51	$	13.43	$	9.84	$	12.27
Oil Equivalents
Sales volumes
MMBOE	13.1		16.0		25.6		32.2
Thousand BOE (MBOE) per day	144		176		142		178
Cash operating margin per BOEc
Realized revenues	$	50.04	$	77.53	$	46.95	$	77.37
Cash production costs	19.04		19.57		19.62		19.03
Cash operating margin	$	31.00	$	57.96	$	27.33	$	58.34

a. The 2014 periods include the results of the Candelaria and Ojos del Salado mines that were sold in November 2014, and the Eagle Ford properties that were sold in June 2014. Sales volumes from Candelaria and Ojos del Salado totaled 80 million pounds of copper and 20 thousand ounces of gold for second-quarter2014 and 174 million pounds of copper and 43 thousand ounces of gold for the first six months of 2014; sales volumes from Eagle Ford totaled 4.0 MMBOE (44 MBOE per day) for second-quarter2014 and 8.7 MMBOE (48 MBOE per day) for the first six months of 2014.

b. Reflects per pound weighted-average production and delivery costs and unit net cash costs (net of by-product credits) for all copper mines. For reconciliations of per pound unit costs by operating division to production and delivery costs applicable to sales reported in our consolidated financial statements, refer to "Product Revenues and Production Costs."

c. Cash operating margin for oil and gas operations reflects realized revenues less cash production costs. Realized revenues exclude noncash mark-to-market adjustments on derivative contracts. For reconciliations of realized revenues and cash production costs per BOE to revenues and production and delivery costs reported in our consolidated financial statements, refer to "Product Revenues and Production Costs."

Revenues

Consolidated revenues totaled $4.2 billion in second-quarter2015 and $8.4 billion for the first six months of 2015, compared with $5.5 billion in second-quarter2014 and $10.5 billion for the first six months of 2014. Revenues include the sale of copper concentrates, copper cathodes, copper rod, gold, molybdenum, silver and cobalt by our mining operations, and the sale of oil, natural gas and natural gas liquids (NGLs) by our oil and gas operations.

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Following is a summary of changes in our consolidated revenues between periods (in millions):

	Three Months Ended June 30,			Six Months Ended June 30,
Consolidated revenues - 2014 periods	$	5,522		$	10,507
Mining operations:
Higher (lower) sales volumes from mining operations:
Copper	(14		)	268
Gold	248			349
Molybdenum	(26		)	(65		)
Lower average realized prices from mining operations:
Copper	(434		)	(904		)
Gold	(43		)	(72		)
Molybdenum	(89		)	(112		)
Net adjustments for prior period provisionally priced copper sales	(55		)	12
Lower revenues from purchased copper	(44		)	(52		)
Lower Atlantic Copper revenues	(129		)	(176		)
Oil and gas operations:
Lower oil sales volumes	(293		)	(613		)
Lower oil average realized prices, including cash gains (losses) on derivative contacts	(240		)	(552		)
Net noncash mark-to-market adjustments on derivative contracts	(88		)	(151		)
Other, including intercompany eliminations	(67		)	(38		)
Consolidated revenues - 2015 periods	$	4,248		$	8,401

Mining Operations

Sales Volumes. Consolidated copper sales volumes were 964 million pounds of copper in second-quarter2015 and 1.9 billion pounds for the first six months of 2015, compared with 968 million pounds in second-quarter2014 and 1.8 billion pounds for the first six months of 2014. The 2015 periods primarily reflect higher copper sales volumes from North America and Indonesia, offset by lower sales volumes from South America, resulting from the sale of Candelaria and Ojos del Salado in fourth-quarter 2014 and lower production from Cerro Verde and El Abra.

Consolidated gold sales increased to 352 thousand ounces of gold in second-quarter2015 and 615 thousand ounces for the first six months of 2015, compared with 159 thousand ounces in second-quarter2014 and 346 thousand ounces for the first six months of 2014, primarily reflecting higher ore grades and operating rates at PT-FI. Consolidated molybdenum sales volumes decreased to 23 million pounds in second-quarter2015 and 46 million pounds for the first six months of 2015, compared with 25 million pounds of molybdenum in second-quarter2014 and 52 million pounds for the first six months of 2014, primarily reflecting slowing demand in the metallurgic market for molybdenum. Refer to “Operations” for further discussion of sales volumes at our mining operations.

Metals Realized Prices.Our consolidated revenues can vary significantly as a result of fluctuations in the market prices of copper, gold, molybdenum, silver and cobalt. As presented above in the summary operating data table, metals price realizations were lower for the second quarter and first six months of 2015, compared with the 2014 periods. Refer to "Markets" for further discussion.

Provisionally Priced Copper Sales.During the first six months of 2015, 41 percent of our mined copper was sold in concentrate, 33 percent as cathode and 26 percent as rod from North America operations. Impacts of net adjustments for prior period provisionally priced sales primarily relate to copper sales. Substantially all of our copper concentrate and cathode sales contracts provide final copper pricing in a specified future month (generally one to four months from the shipment date) based primarily on quoted LME monthly average spot copper prices. We receive market prices based on prices in the specified future period, which results in price fluctuations recorded through revenues until the date of settlement. We record revenues and invoice customers at the time of shipment based on then-current LME prices, which results in an embedded derivative on our provisionally priced concentrate and cathode sales that is adjusted to fair value through earnings each period, using the period-end forward prices, until final pricing on the date of settlement. To the extent final prices are higher or lower than what was recorded on a provisional basis, an increase or decrease to revenues is recorded each reporting period until the date of final pricing. Accordingly, in times of rising copper prices, our revenues benefit from adjustments to the final pricing of provisionally priced sales pursuant to contracts entered into in prior periods; in times of falling copper prices, the

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opposite occurs. The (unfavorable) favorable impacts of net adjustments to the prior periods' provisionally priced copper sales totaled $(20) million for second-quarter2015 and $(106) million for the first six months of 2015, compared with $35 million for second-quarter2014 and $(118) million for the first six months of 2014.

At June 30, 2015, we had provisionally priced copper sales at our copper mining operations, primarily South America and Indonesia, totaling 433 million pounds of copper (net of intercompany sales and noncontrolling interests) recorded at an average of $2.61 per pound, subject to final pricing over the next several months. We estimate that each $0.05 change in the price realized from the June 30, 2015, provisional price recorded would have an approximate $14 million effect on 2015 net income attributable to common stock. The LME spot copper price was $2.37 per pound on July 31, 2015.

Purchased Copper.We purchased copper cathode for processing by our Rod & Refining segment totaling 24 million pounds in second-quarter2015 and 64 million for the first six months of 2015, compared with 34 million pounds in second-quarter2014 and 66 million pounds for the first six months of 2014. Lower purchased copper revenues primarily reflect lower market prices for copper and lower sales volumes.

Oil and Gas Operations

Sales Volumes.Oil sales volumes of 8.6 million barrels (MMBbls) in second-quarter2015 and 17.0 MMBbls for the first six months of 2015, were lower than sales volumes of 11.7 MMBbls in second-quarter2014 and 23.5 MMBbls for the first six months of 2014, primarily reflecting the sale of the Eagle Ford properties in June 2014.

Realized Oil Prices and Derivative Contracts. Lower average realized prices for oil, excluding cash gains on derivative contracts, of $55.82 per barrel in second-quarter2015 and $50.25 for the first six months of 2015, compared with $100.46 per barrel in second-quarter2014 and $99.54 for the first six months of 2014, primarily reflected lower oil prices. Refer to “Operations” for further discussion of average realized prices and sales volumes at our oil and gas operations.

In connection with the acquisition of our oil and gas business, we have derivative contracts for 2015 consisting of crude oil options, and for 2014, had derivative contracts that consisted of crude oil options and natural gas swaps. These crude oil and natural gas derivative contracts are not designated as hedging instruments; accordingly, they are recorded at fair value with the mark-to-market gains and losses recorded in revenues each period. Cash gains (losses) on crude oil and natural gas derivative contracts totaled $101 million for second-quarter2015 and $201 million for the first six months of 2015, compared with $(63) million for second-quarter2014 and $(128) million for the first six months of 2014. Net noncash mark-to-market (losses) gains on crude oil and natural gas derivative contracts totaled $(95) million for second-quarter2015 and $(143) million for the first six months of 2015, compared with $(7) million for second-quarter2014 and $8 million for the first six months of 2014.

Following presents the estimated (decrease) increase in the net asset on our balance sheet of a 10 percent change in Brent crude oil prices on the fair values of outstanding crude oil derivative contracts, compared with forward prices used to determine the June 30, 2015, fair values (in millions):

	10% Increase			10% Decrease
Crude oil options	$	(37	)	$	18

Refer to Note 7 for further discussion of oil and natural gas derivative contracts.

Production and Delivery Costs

Consolidated production and delivery costs totaled $2.8 billion in second-quarter2015 and $5.8 billion for the first six months of 2015, compared with $3.1 billion in second-quarter2014 and $5.8 billion for the first six months of 2014. Production and delivery costs for the 2015 periods, compared with the 2014 periods, primarily reflect lower costs at our South America mining operations as a result of the sale of the Candelaria and Ojos del Salado mines in fourth-quarter 2014, partly offset by higher costs at our North America mines related to higher production volumes. 

Consolidated production and delivery costs included LCM adjustments primarily attributable to molybdenum inventories totaling $59 million for second-quarter 2015 and $63 million for the first six months of 2015. Refer to "Overview" for further discussion of potential additional LCM inventory adjustments and impairments for third-quarter 2015.

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Mining Unit Site Production and Delivery Costs

Site production and delivery costs for our copper mining operations primarily include labor, energy and commodity-based inputs, such as sulphuric acid, reagents, liners, tires and explosives. Consolidated unit site production and delivery costs (before net noncash and other costs) for our copper mines totaled $1.85 per pound of copper in second-quarter2015 and $1.89 for the first six months of 2015, compared with $1.99 per pound in second-quarter2014 and $1.94 for the first six months of 2014. Lower consolidated average site production and delivery costs for the 2015 periods, compared with the 2014 periods, primarily reflected higher copper sales volumes in North America and Indonesia, partly offset by lower sales volumes in South America. Refer to “Operations – Unit Net Cash Costs” for further discussion of unit net cash costs associated with our operating divisions and to “Product Revenues and Production Costs” for reconciliations of per pound costs by operating division to production and delivery costs applicable to sales reported in our consolidated financial statements.

Assuming achievement of current volume and cost estimates, consolidated unit site production and delivery costs are expected to be lower in the second half of 2015 and average $1.81 per pound of copper for the year 2015, which is subject to change as a result of the comprehensive review of operating plans as further discussed in “Overview.”

Oil and Gas Cash Production Costs per BOE

Production costs for our oil and gas operations primarily include costs incurred to operate and maintain wells and related equipment and facilities, such as lease operating expenses, steam gas costs, electricity, production and ad valorem taxes, and gathering and transportation expenses. Cash production costs for our oil and gas operations of $19.04 per BOE in second-quarter2015 were lower than cash production costs of $19.57 per BOE in second-quarter2014, primarily reflecting lower cash production costs in California related to reductions in repair and maintenance costs and well workover expense, partly offset by higher average costs per BOE resulting from the sale of lower-cost Eagle Ford properties. Cash production costs of $19.62 per BOE for the first six months of 2015, were higher than $19.03 for the first six months of 2014, primarily reflecting the sale of lower-cost Eagle Ford properties, partly offset by lower cash production costs in California. Refer to “Operations” for further discussion of cash production costs at our oil and gas operations.

Assuming achievement of current volume and cost estimates for the remainder of 2015, cash production costs are expected to approximate $20 per BOE for the year 2015.

Depreciation, Depletion and Amortization

Depreciation will vary under the unit-of-production (UOP) method as a result of changes in sales volumes and the related UOP rates at our mining and oil and gas operations. Consolidated depreciation, depletion and amortization (DD&A) totaled $890 million in second-quarter2015 and $1.8 billion for first six months of 2015, compared with $1.0 billion in second-quarter2014 and $2.0 billion for the first six months of 2014. DD&A in the 2015 periods, compared with the 2014 periods, reflected lower expense from our oil and gas operations associated with decreased production as a result of the sale of the Eagle Ford properties. Lower DD&A from our oil and gas operations for the first six months of 2015, compared with the first six months of 2014, was partly offset by higher DD&A from our mining operations mostly associated with higher sales volumes in North America and Indonesia.

Impairment of Oil and Gas Properties

Under full cost accounting rules, a "ceiling test" is conducted each quarter to review the carrying value of our oil and gas properties for impairment. At June 30, 2015, and March 31, 2015, net capitalized costs with respect to FCX's proved U.S. oil and gas properties exceeded the related ceiling test limitation, which resulted in the recognition of impairment charges of $2.7 billion in second-quarter2015 and $5.8 billion for the first six months of 2015, reflecting the lower twelve-month average of the first-day-of-the-month historical reference oil price and higher capitalized costs at such dates. Refer to Note 1 and "Operations - Oil and Gas" for further discussion, including discussion of potentially significant additional ceiling test impairments.

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Selling, General and Administrative Expenses

Consolidated selling, general and administrative expenses totaled $151 million in second-quarter2015 and $305 million for the first six months of 2015, compared with $164 million in second-quarter2014 and $299 million for the first six months of 2014. Consolidated selling, general and administrative expenses were net of capitalized general and administrative expense at our oil and gas operations, which totaled $38 million in second-quarter2015 and $71 million for the first six months of 2015, compared with $40 million in second-quarter2014 and $74 million for the first six months of 2014.

Mining Exploration and Research Expenses

Consolidated exploration and research expenses for our mining operations totaled $36 million in second-quarter2015 and $69 millionfor the first six months of 2015, compared with $34 million in second-quarter2014 and $64 million for the first six months of 2014. Our exploration activities are generally near our existing mines with a focus on opportunities to expand reserves and resources to support development of additional future production capacity in the large mineral districts where we currently operate. Exploration results continue to indicate opportunities for what we believe could be significant future potential reserve additions in North and South America, and in the Tenke minerals district. The drilling data in North America also indicates the potential for significantly expanded sulfide production. Drilling results and exploration modeling in North America have identified large-scale potential sulfide resources in the Morenci and Safford/Lone Star districts, providing a long-term pipeline for future growth in reserves and production capacity in an established minerals district.

For the year 2015, mining exploration expenditures are expected to total approximately $110 million, which is subject to change as a result of the comprehensive review of operating plans as further discussed in “Overview.”

As further discussed in Note 1 of our annual report on Form 10-K for the year ended December 31, 2014, under the full cost method of accounting, exploration costs for our oil and gas operations are capitalized to oil and gas properties.

Environmental Obligations and Shutdown Costs

Environmental obligation costs reflect net revisions to our long-term environmental obligations, which vary from period to period because of changes to environmental laws and regulations, the settlement of environmental matters and/or circumstances affecting our operations that could result in significant changes in our estimates. Shutdown costs include care and maintenance costs and any litigation, remediation or related expenditures associated with closed facilities or operations. Net charges for environmental obligations and shutdown costs totaled $11 million in second-quarter2015 and $24 million for the first six months of 2015, compared with $76 million in second-quarter2014 and $82 million for the first six months of 2014. Refer to "Contingencies" for further discussion of environmental obligations and litigation matters associated with closed facilities or operations.

Net Gain on Sale of Assets

Net gain on sale of assets totaled $39 million for the first six months of 2015, primarily related to the January 2015 $140 million sale of our one-third interest in the Luna Energy power facility in New Mexico.

Interest Expense, Net

Consolidated interest expense (excluding capitalized interest) totaled $215 million in second-quarter2015 and $425 million for the first six months of 2015, compared with$225 million in second-quarter2014 and $449 million for the first six months of 2014. Capitalized interest varies with the level of expenditures for our development projects and average interest rates on our borrowings, and totaled $66 million in second-quarter2015 and $130 millionfor the first six months of 2015, compared with $61 million in second-quarter2014 and $124 million for the first six months of 2014. Refer to "Operations" and “Capital Resources and Liquidity - Investing Activities” for further discussion of current development projects.

Insurance and Other Third-party Recoveries

As further discussed in Note 9, in second-quarter 2015, we recognized a gain of $92 million associated with net proceeds received from insurers under FCX’s directors and officers liability insurance policies and other third parties in accordance with the settlement terms of shareholder derivative litigation.

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Income Taxes

Following is a summary of the approximate amounts used in the calculation of our consolidated income tax benefit (provision) for the 2015 and 2014 periods (in millions, except percentages):

	Six Months Ended										Six Months Ended
	June 30, 2015										June 30, 2014
	Income(Loss)a				Effective Tax Rate		Income Tax (Provision) Benefit				Income (Loss)a			Effective Tax Rate	Income Tax (Provision) Benefit
U.S.	$	(469	)	b	61%		$	288			$	936		31%	$	(291	)	c
South America	81				37%		(30		)		747			36%	(267		)
Indonesia	289				43%		(124		)		(39		)	38%	15
Africa	114				46%		(53		)		187			30%	(57		)
Impairment of oil and gas properties	(5,790		)		38%		2,179				—			N/A	—
Valuation allowance	—				N/A		(763		)	d	—			N/A	—
Eliminations and other	187				N/A		(28		)		138			N/A	(37		)
Annualized rate adjustmente	—				N/A		(87		)		—			N/A	(48		)
Consolidated FCX	$	(5,588	)		25%	f	$	1,382			$	1,969		35%	$	(685	)

a. Represents income (loss) by geographic location before income taxes and equity in affiliated companies’ net earnings.

b. Includes a gain of $92 million related to net proceeds received from insurance carriers and other third parties related to a shareholder derivative litigation settlement for which there is no related tax provision.

c. Includes a $58 million charge for deferred taxes recorded in connection with the allocation of goodwill to the sale of Eagle Ford.

d. As a result of the impairment to oil and gas properties, we recorded a tax charge to establish a valuation allowance primarily against U.S. federal alternative minimum tax credits.

e. In accordance with applicable accounting rules, we adjust our interim provision for income taxes equal to our estimated annualized tax rate.

f. Our consolidated effective income tax rate is a function of the combined effective tax rates for the jurisdictions in which we operate. Accordingly, variations in the relative proportions of jurisdictional income result in fluctuations to our consolidated effective income tax rate. Assuming achievement of current sales volume and cost estimates and average prices of $2.50 per pound for copper, $1,150 per ounce for gold, $6 per pound for molybdenum and $56 per barrel of Brent crude oil for the second half of 2015, we estimated a tax benefit of $1.4 billion for 2015, substantially all of which relates to the impairment of oil and gas properties and resulting tax charge to establish a valuation allowance in the first half of 2015. See "Operations - Oil and Gas" for discussion regarding the likelihood of potentially significant ceiling charges during the remainder of 2015, which would give rise to additional tax benefits.

OPERATIONS

North America Copper Mines

We operate seven open-pit copper mines in North America – Morenci, Bagdad, Safford, Sierrita and Miami in Arizona, and Chino and Tyrone in New Mexico. All of the North America mining operations are wholly owned, except for Morenci. We record our 85 percent joint venture interest in Morenci using the proportionate consolidation method.

The North America copper mines include open-pit mining, sulfide ore concentrating, leaching and solution extraction/electrowinning (SX/EW) operations. A majority of the copper produced at our North America copper mines is cast into copper rod by our Rod & Refining segment. The remainder of our North America copper sales is in the form of copper cathode or copper concentrate, a portion of which is shipped to Atlantic Copper (our wholly owned smelter). Molybdenum concentrates and silver are also produced by certain of our North America copper mines.

As further discussed in “Overview,” we are currently reviewing operating plans at each of our copper and molybdenum mining operations and will revise operating and capital plans to strengthen our financial position in a weak copper price environment. The revised plans will target lower operating and capital costs to achieve maximum cash flow under the current market conditions. Production at certain operations challenged by low commodity prices will be curtailed. We expect to complete this review promptly and will report our revised plans during third-quarter

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2015. Accordingly, our sales volume and unit costs estimates discussed below are subject to change as a result of this review and other factors.

Operating and Development Activities. We have increased production from our North America copper mines by approximately 50 percent over the past five years and continue to evaluate a number of opportunities to add production capacity following positive exploration results. Future investments will be undertaken based on the results of economic and technical feasibility studies and market conditions.

Morenci Mill Expansion. The Morenci mill expansion project commenced operations in May 2014 and successfully achieved full rates in second-quarter 2015. The project expanded mill capacity from 50,000 metric tons of ore per day to approximately 115,000 metric tons of ore per day, which results in incremental annual production of approximately 225 million pounds of copper. Morenci's copper production is expected to average over 900 million pounds per year over the next five years. Additionally, the molybdenum circuit began production in first-quarter 2015. Remaining items associated with the project include construction of the expanded tailings storage facility, which is expected to be completed in the second half of 2015.

Operating Data. Following is summary operating data for the North America copper mines for the second quarters and first six months of 2015 and 2014:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2015		2014		2015		2014
Operating Data, Net of Joint Venture Interest
Copper (recoverable)
Production (millions of pounds)	469		395		921		780
Sales (millions of pounds)	486		423		958		794
Average realized price per pound	$	2.77	$	3.16	$	2.73	$	3.21
Molybdenum (recoverable)
Production(millions of pounds)a	10		9		19		17
100% Operating Data
SX/EW operations
Leach ore placed in stockpiles (metric tons per day)	890,000		1,044,500		902,500		1,014,000
Average copper ore grade (percent)	0.26		0.25		0.25		0.25
Copper production (millions of recoverable pounds)	261		234		508		463
Mill operations
Ore milled (metric tons per day)	316,000		260,100		308,800		257,700
Average ore grade (percent):
Copper	0.47		0.44		0.48		0.43
Molybdenum	0.03		0.03		0.03		0.03
Copper recovery rate (percent)	85.8		82.8		85.6		84.4
Copper production (millions of recoverable pounds)	247		188		488		370

a. Refer to "Consolidated Results" for our consolidated molybdenum sales volumes, which includes sales of molybdenum produced at the North America copper mines.

Copper sales volumes from our North America copper mines increased to 486 million pounds in second-quarter2015 and 958 million pounds for the first six months of 2015, compared with 423 million pounds in second-quarter2014 and 794 million pounds for the first six months of 2014, primarily reflecting higher milling rates at Morenci and Chino.

Copper sales from North America are expected to approximate 1.96 billion pounds for the year 2015, compared with 1.66 billion pounds in 2014.

Unit Net Cash Costs. Unit net cash costs per pound of copper is a measure intended to provide investors with information about the cash-generating capacity of our mining operations expressed on a basis relating to the primary metal product for our respective operations. We use this measure for the same purpose and for monitoring

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operating performance by our mining operations. This information differs from measures of performance determined in accordance with U.S. GAAP and should not be considered in isolation or as a substitute for measures of performance determined in accordance with U.S. GAAP. This measure is presented by other metals mining companies, although our measure may not be comparable to similarly titled measures reported by other companies.

Gross Profit per Pound of Copper and Molybdenum

The following table summarizes unit net cash costs and gross profit per pound at our North America copper mines for the second quarters and first six months of 2015 and 2014. Refer to “Product Revenues and Production Costs” for an explanation of the “by-product” and “co-product” methods and a reconciliation of unit net cash costs per pound to production and delivery costs applicable to sales reported in our consolidated financial statements.

	Three Months Ended									Three Months Ended
	June 30, 2015									June 30, 2014
	By- Product Method				Co-Product Method					By- Product Method			Co-Product Method
					Copper			Molyb- denuma					Copper		Molyb- denuma
Revenues, excluding adjustments	$	2.77			$	2.77		$	7.80	$	3.16		$	3.16	$	12.49
Site production and delivery, before net noncash and other costs shown below	1.78				1.66			6.24		1.87			1.74		6.73
By-product credits	(0.16		)		—			—		(0.28		)	—		—
Treatment charges	0.12				0.12			—		0.11			0.11		—
Unit net cash costs	1.74				1.78			6.24		1.70			1.85		6.73
Depreciation, depletion and amortization	0.28				0.27			0.53		0.30			0.28		0.64
Noncash and other costs, net	0.10			b	0.09			0.06		0.07			0.06		0.05
Total unit costs	2.12				2.14			6.83		2.07			2.19		7.42
Revenue adjustments, primarily for pricing on prior period open sales	(0.03		)		(0.03		)	—		0.02			0.02		—
Gross profit per pound	$	0.62			$	0.60		$	0.97	$	1.11		$	0.99	$	5.07
Copper sales (millions of recoverable pounds)	485				485					421			421
Molybdenum sales (millions of recoverable pounds)a								10							9

	Six Months Ended									Six Months Ended
	June 30, 2015									June 30, 2014
	By- Product Method				Co-Product Method					By- Product Method			Co-Product Method
					Copper			Molyb- denuma					Copper			Molyb- denuma
Revenues, excluding adjustments	$	2.73			$	2.73		$	8.28	$	3.21		$	3.21		$	11.39
Site production and delivery, before net noncash and other costs shown below	1.79				1.68			6.24		1.87			1.76			6.45
By-product credits	(0.17		)		—			—		(0.25		)	—			—
Treatment charges	0.13				0.12			—		0.12			0.12			—
Unit net cash costs	1.75				1.80			6.24		1.74			1.88			6.45
Depreciation, depletion and amortization	0.28				0.27			0.58		0.29			0.27			0.58
Noncash and other costs, net	0.08			b	0.08			0.06		0.08			0.07			0.04
Total unit costs	2.11				2.15			6.88		2.11			2.22			7.07
Revenue adjustments, primarily for pricing on prior period open sales	(0.03		)		(0.03		)	—		(0.01		)	(0.01		)	—
Gross profit per pound	$	0.59			$	0.55		$	1.40	$	1.09		$	0.98		$	4.32
Copper sales (millions of recoverable pounds)	956				956					790			790
Molybdenum sales (millions of recoverable pounds)a								19								17

a. Reflects sales of molybdenum produced by certain of the North America copper mines to our molybdenum sales company at market-based pricing.

b. Includes charges for LCM inventory adjustments totaling $0.02 per pound for second-quarter 2015 and $0.01 per pound for the first six months of 2015.

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Our North America copper mines have varying cost structures because of differences in ore grades and characteristics, processing costs, by-product credits and other factors. Average unit net cash costs (net of by-product credits) of $1.74 per pound of copper in second-quarter2015 and $1.75 per pound for the first six months of 2015, were higher than unit net cash costs of $1.70 per pound in second-quarter2014 and $1.74 per pound for the first six months of 2014, primarily reflecting lower by-product credits, partly offset by higher copper sales volumes.

Because certain assets are depreciated on a straight-line basis, North America's average unit depreciation rate may vary with asset additions and the level of copper production and sales.

Assuming achievement of current sales volume and cost estimates, and an average price of $6 per pound of molybdenum for the second half of 2015, average unit net cash costs (net of by-product credits) for our North America copper mines are expected to approximate $1.72 per pound of copper for the year 2015, compared with $1.73 per pound in 2014. North America's unit net cash costs would change by approximately $0.02 per pound for each $2 per pound change in the average price of molybdenum for the second half of 2015.

South America Mining

We operate two copper mines in South America – Cerro Verde in Peru (in which we own a 53.56 percent interest) and El Abra in Chile (in which we own a 51 percent interest). These operations in South America are consolidated in our financial statements.

On November 3, 2014, FCX completed the sale of its ownership interests in the Candelaria and Ojos del Salado mines in Chile.

South America mining includes open-pit mining, sulfide ore concentrating, leaching and SX/EW operations. Production from our South America mines is sold as copper concentrate or copper cathode under long-term contracts. Our South America mines also ship a portion of their copper concentrate inventories to Atlantic Copper. In addition to copper, the Cerro Verde mine produces molybdenum concentrates and silver.

As further discussed in “Overview,” we are currently reviewing operating plans at each of our copper and molybdenum mining operations and will revise operating and capital plans to strengthen our financial position in a weak copper price environment. The revised plans will target lower operating and capital costs to achieve maximum cash flow under the current market conditions. Production at certain operations challenged by low commodity prices will be curtailed. We expect to complete this review promptly and will report our revised plans during third-quarter 2015. Accordingly, our sales volume and unit costs estimates discussed below are subject to change as a result of this review and other factors.

Development Activities.

Cerro Verde Expansion. Construction activities associated with a large-scale expansion at Cerro Verde are advancing on schedule toward completion in late 2015. Detailed engineering and major procurement activities are complete and construction is more than 87 percent complete. The project will expand the concentrator facilities from 120,000 metric tons of ore per day to 360,000 metric tons of ore per day and provide incremental annual production of approximately 600 million pounds of copper and 15 million pounds of molybdenum beginning in 2016. As of June 30, 2015, $3.9 billion had been incurred for this project ($0.8 billion during the first six months of 2015), with approximately $0.7 billion remaining to be incurred.

El Abra Sulfide. We continue to evaluate a potential large-scale milling operation at El Abra to process additional sulfide material and to achieve higher recoveries. Exploration results in recent years at El Abra indicate a significant sulfide resource, which could potentially support a major mill project. Future investments will depend on technical studies, economic factors and global copper market conditions.

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Operating Data. Following is summary operating data for our South America mining operations for the second quarters and first six months of 2015 and 2014:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2015		2014a		2015		2014a
Copper (recoverable)
Production (millions of pounds)	188		300		381		614
Sales (millions of pounds)	178		310		378		617
Average realized price per pound	$	2.69	$	3.17	$	2.68	$	3.16
Gold (recoverable)
Production (thousands of ounces)	—		21		—		42
Sales (thousands of ounces)	—		20		—		43
Average realized price per ounce	$	—	$	1,302	$	—	$	1,302
Molybdenum (millions of recoverable pounds)
Productionb	2		2		4		5
SX/EW operations
Leach ore placed in stockpiles (metric tons per day)	237,000		281,700		235,300		284,200
Average copper ore grade (percent)	0.41		0.52		0.41		0.51
Copper production (millions of recoverable pounds)	109		125		223		248
Mill operations
Ore milled (metric tons per day)	116,500		182,200		117,900		185,500
Average ore grade:
Copper (percent)	0.46		0.56		0.45		0.58
Molybdenum (percent)	0.01		0.02		0.02		0.02
Gold (grams per metric ton)	—		0.11		—		0.11
Copper recovery rate (percent)	78.2		88.7		78.9		89.4
Copper production (millions of recoverable pounds)	79		175		158		366

a. The 2014 periods include the results of the Candelaria and Ojos del Salado mines, which were sold in November 2014 and had sales volumes totaling 80 million pounds of copper and 20 thousand ounces of gold in second-quarter2015 and 174 million pounds of copper and 43 thousand ounces of gold for the first six months of 2014.

b. Refer to "Consolidated Results" for our consolidated molybdenum sales volumes, which include sales of molybdenum produced at Cerro Verde.

Consolidated copper sales volumes from South America of 178 million pounds in second-quarter2015 and 378 million pounds for the first six months of 2015 were lower than sales of 310 million pounds in second-quarter2014 and 617 million pounds for the first six months of 2014, reflecting the sale of the Candelaria and Ojos del Salado mines and lower production from Cerro Verde and El Abra primarily associated with lower ore grades and recovery rates.

For the year 2015, consolidated sales volumes from South America mines are expected to approximate 900 million pounds of copper, compared with 1.14 billion pounds in 2014, which included copper sales volumes of 268 million pounds from the Candelaria and Ojos del Salado mines.

Unit Net Cash Costs. Unit net cash costs per pound of copper is a measure intended to provide investors with information about the cash-generating capacity of our mining operations expressed on a basis relating to the primary metal product for our respective operations. We use this measure for the same purpose and for monitoring operating performance by our mining operations. This information differs from measures of performance determined in accordance with U.S. GAAP and should not be considered in isolation or as a substitute for measures of performance determined in accordance with U.S. GAAP. This measure is presented by other metals mining companies, although our measure may not be comparable to similarly titled measures reported by other companies.

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Gross Profit per Pound of Copper

The following table summarizes unit net cash costs and gross profit per pound of copper at the South America mining operations for the second quarters and first six months of 2015 and 2014. Unit net cash costs per pound of copper are reflected under the by-product and co-product methods as the South America mining operations also had small amounts of molybdenum, gold and silver sales. Refer to “Product Revenues and Production Costs” for an explanation of the “by-product” and “co-product” methods and a reconciliation of unit net cash costs per pound to production and delivery costs applicable to sales reported in our consolidated financial statements.

	Three Months Ended						Three Months Ended
	June 30, 2015						June 30, 2014
	By-Product Method			Co-Product Method			By-Product Method				Co-Product Method
Revenues, excluding adjustments	$	2.69		$	2.69		$	3.17			$	3.17
Site production and delivery, before net noncash     and other costs shown below	1.77			1.72			1.64				1.52
By-product credits	(0.04		)	—			(0.23		)		—
Treatment charges	0.17			0.17			0.18				0.18
Royalty on metals	—			—			0.01				0.01
Unit net cash costs	1.90			1.89			1.60			a	1.71
Depreciation, depletion and amortization	0.40			0.39			0.30				0.29
Noncash and other (credits) costs, net	(0.02		)	(0.03		)	0.08				0.06
Total unit costs	2.28			2.25			1.98				2.06
Revenue adjustments, primarily for pricing     on prior period open sales	(0.05		)	(0.05		)	0.10				0.10
Gross profit per pound	$	0.36		$	0.39		$	1.29			$	1.21
Copper sales (millions of recoverable pounds)	178			178			310				310

	Six Months Ended						Six Months Ended
	June 30, 2015						June 30, 2014
	By-Product Method			Co-Product Method			By-Product Method				Co-Product Method
Revenues, excluding adjustments	$	2.68		$	2.68		$	3.16			$	3.16
Site production and delivery, before net noncash and other costs shown below	1.76			1.70			1.57				1.46
By-product credits	(0.06		)	—			(0.24		)		—
Treatment charges	0.17			0.17			0.18				0.18
Royalty on metals	—			—			—				—
Unit net cash costs	1.87			1.87			1.51			a	1.64
Depreciation, depletion and amortization	0.39			0.38			0.29				0.27
Noncash and other costs, net	—			—			0.07				0.06
Total unit costs	2.26			2.25			1.87				1.97
Revenue adjustments, primarily for pricing on prior period open sales	(0.08		)	(0.08		)	(0.11		)		(0.11		)
Gross profit per pound	$	0.34		$	0.35		$	1.18			$	1.08
Copper sales (millions of recoverable pounds)	378			378			617				617

a. Excluding the results of Candelaria and Ojos del Salado, South America mining's unit net cash costs for second-quarter 2014 averaged $1.55 per pound and $1.51 for the first six months of 2014.

Our South America mines have varying cost structures because of differences in ore grades and characteristics, processing costs, by-product credits and other factors. Average unit net cash costs (net of by-product credits) of $1.90 per pound of copper in second-quarter2015 and $1.87 per pound for the first six months of 2015 were higher than unit net cash costs of $1.60 per pound in second-quarter2014 and $1.51 per pound for the first six months of 2014, primarily reflecting lower sales volumes and lower by-product credits. Lower by-product credits were mostly because of the sale of Candelaria and Ojos del Salado in fourth-quarter 2014.

Because certain assets are depreciated on a straight-line basis, South America's unit depreciation rate may vary with asset additions and the level of copper production and sales.

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Revenue adjustments primarily result from changes in prices on provisionally priced copper sales recognized in prior periods. Refer to “Consolidated Results - Revenues” for further discussion of adjustments to prior period provisionally priced copper sales.

Assuming achievement of current sales volume and cost estimates, and average prices of $6 per pound of molybdenum for the second half of 2015, we estimate that average unit net cash costs (net of by-product credits) for our South America mining operations would approximate $1.75 per pound of copper for the year 2015, compared with $1.58 per pound in 2014.

Indonesia Mining

Indonesia mining includes PT-FI’s Grasberg minerals district, one of the world's largest copper and gold deposits, in Papua, Indonesia. We own 90.64 percent of PT-FI, including 9.36 percent owned through our wholly owned subsidiary, PT Indocopper Investama.

PT-FI proportionately consolidates an unincorporated joint venture with Rio Tinto plc (Rio Tinto), under which Rio Tinto has a 40 percent interest in certain assets and a 40 percent interest through 2021 in production exceeding specified annual amounts of copper, gold and silver. After 2021, all production and related revenues and costs are shared 60 percent PT-FI and 40 percent Rio Tinto. Refer to Note 3 in our annual report on Form 10-K for the year ended December 31, 2014, for discussion of our joint venture with Rio Tinto.

PT-FI produces copper concentrates that contain significant quantities of gold and silver. Substantially all of PT-FI’s copper concentrates are sold under long-term contracts, and during the first six months of 2015, approximately one-half of PT-FI's copper concentrates was sold to PT Smelting, our 25 percent owned smelter and refinery in Gresik. In July 2015, PT Smelting's operations were temporarily suspended pending completion of required repairs, which are expected to be completed in September 2015.

PT-FI has commenced discussions with union officials regarding its bi-annual labor agreement, which is scheduled for renewal in September 2015.

As further discussed in “Overview,” we are currently reviewing operating plans at each of our copper and molybdenum mining operations and will revise operating and capital plans to strengthen our financial position in a weak copper price environment. The revised plans will target lower operating and capital costs to achieve maximum cash flow under the current market conditions. Production at certain operations challenged by low commodity prices will be curtailed. We expect to complete this review promptly and will report our revised plans during third-quarter 2015. Accordingly, our sales volume and unit costs estimates discussed below are subject to change as a result of this review and other factors.

Regulatory Matters. In January 2014, the Indonesian government published regulations that among other things imposed a progressive export duty on copper concentrates. Despite PT-FI’s rights under its Contract of Work (COW) to export concentrates without the payment of duties, PT-FI was unable to obtain administrative approval for exports and operated at approximately half of its capacity from mid-January 2014 through July 2014.

In July 2014, PT-FI entered into a Memorandum of Understanding (MOU) with the Indonesian government. Under the MOU, PT-FI provided a $115 million assurance bond to support its commitment for smelter development, agreed to increased royalty rates and agreed to pay export duties (which were set at 7.5 percent, declining to 5.0 percent when smelter development progress exceeds 7.5 percent and are eliminated when development progress exceeds 30 percent). The MOU also anticipated an amendment of the COW within six months to address other matters; however, no terms of the COW other than those relating to the smelter bond, increased royalties and export duties were changed. In January 2015, the MOU was extended to July 25, 2015, and it expired on that date. The increased royalty rates, export duties and smelter assurance bond remain in effect.

PT-FI is also required to apply for renewal of export permits at six-month intervals. On July 29, 2015, PT-FI's export permit was renewed through January 28, 2016. In connection with the renewal, export duties were reduced to 5.0 percent, as a result of smelter development progress.

In April 2015, the Indonesian government instituted a requirement that all export sales of concentrates must be arranged through letters of credit with payments received through a foreign exchange bank located in Indonesia. Under the COW, PT-FI is not required to obtain letters of credit in connection with its sales, and PT-FI requested an

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exemption from the new requirement. The Minister of Trade granted an initial exemption through July 25, 2015.  If this exemption is not renewed, shipments could be delayed for a short period of time and additional costs could be incurred.

PT-FI continues to engage in active discussions with the Indonesian government regarding its COW and long-term operating rights. Negotiations are taking into consideration PT-FI's requirement for assurance of legal and fiscal terms post-2021 for PT-FI to continue with its large-scale investment program in Papua, Indonesia.

PT-FI is advancing plans for the construction of new smelter capacity in parallel with completing negotiations on its COW and long-term operating rights. PT-FI has identified potential sites for the construction of additional smelter capacity and is in discussions with potential partners for the project.

We expect, but cannot provide any assurance, that PT-FI will be successful in reaching a satisfactory agreement on the terms of its long-term mining rights. If PT-FI is unable to reach agreement with the Indonesian government on its long-term rights, we may be required to reduce or defer investments in underground development projects, which could have a material adverse effect on PT-FI’s future production and reserves. In addition, PT-FI would intend to pursue any and all claims against the Indonesian government for breach of contract through international arbitration.

Refer to Note 13 in our annual report on Form 10-K for the year ended December 31, 2014, for further discussion of our Indonesia mining contract. For additional discussion of risks associated with our operations in Indonesia, including labor matters and the COW, refer to "Risk Factors" contained in Part I, Item 1A. of our annual report on Form 10-K for the year ended December 31, 2014.

Operating and Development Activities. We have several projects in progress in the Grasberg minerals district related to the development of large-scale, long-lived, high-grade underground ore bodies. In aggregate, these underground ore bodies are expected to ramp up over several years to process approximately 240,000 metric tons of ore per day following the transition from the Grasberg open pit, currently anticipated to occur in late 2017. Development of the Grasberg Block Cave and Deep Mill Level Zone (DMLZ) underground mines is advancing to enable DMLZ to commence production in late 2015 and the Grasberg Block Cave mine to commence production in 2018. Over the next five years, estimated aggregate capital spending on these projects is expected to average $0.8 billion per year ($0.7 billion per year net to PT-FI). Additionally, over the next five years, estimated aggregate capital spending for processing and power facilities to optimize the handling of underground ore is expected to average $0.3 billion per year. Considering the long-term nature and size of these projects, actual costs could vary from these estimates. PT-FI may reduce or defer these activities pending resolution of negotiations regarding the COW.

The following provides additional information on the continued development of the Common Infrastructure project, the Grasberg Block Cave underground mine and the DMLZ ore body that lies below the Deep Ore Zone (DOZ) underground mine.

Common Infrastructure and Grasberg Block Cave Mine. In 2004, PT-FI commenced its Common Infrastructure project to provide access to its large undeveloped underground ore bodies located in the Grasberg minerals district through a tunnel system located approximately 400 meters deeper than its existing underground tunnel system. In addition to providing access to our underground ore bodies, the tunnel system will enable PT-FI to conduct future exploration in prospective areas associated with currently identified ore bodies. The tunnel system was completed to the Big Gossan terminal, and the Big Gossan mine was brought into production in 2010. Production from the Big Gossan mine is currently suspended and expected to restart production in the second half of 2016. Development of the DMLZ and Grasberg Block Cave underground mines is advancing using the Common Infrastructure project tunnels as access.

The Grasberg Block Cave underground mine accounts for more than 40 percent of our recoverable proven and probable reserves in Indonesia. Production at the Grasberg Block Cave mine is expected to commence in early 2018, at the end of mining the Grasberg open pit. Targeted production rates once the Grasberg Block Cave mining operation reaches full capacity are expected to approximate 160,000 metric tons of ore per day.

Aggregate mine development capital for the Grasberg Block Cave mine and associated Common Infrastructure is expected to approximate $5.7 billion (incurred between 2008 and 2021), with PT-FI’s share totaling approximately $5.1 billion. Aggregate project costs totaling $2.0 billion have been incurred through June 30, 2015 ($0.2 billion during the first six months of 2015).

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DMLZ. The DMLZ ore body lies below the DOZ mine at the 2,590-meter elevation and represents the downward continuation of mineralization in the Ertsberg East Skarn system and neighboring Ertsberg porphyry. We plan to mine the ore body using a block-cave method with production beginning in late 2015. Targeted production rates once the DMLZ mining operation reaches full capacity are expected to approximate 80,000 metric tons of ore per day. Drilling efforts continue to determine the extent of this ore body. Aggregate mine development capital costs for the DMLZ mine are expected to approximate $2.7 billion (incurred between 2009 and 2020), with PT-FI’s share totaling approximately $1.6 billion. Aggregate project costs totaling $1.3 billion have been incurred through June 30, 2015 ($0.2 billion during the first six months of 2015).

Operating Data. Following is summary operating data for our Indonesia mining operations for the second quarters and first six months of 2015 and 2014:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2015		2014		2015		2014
Operating Data, Net of Joint Venture Interest
Copper (recoverable)
Production (millions of pounds)	205		122		359		262
Sales (millions of pounds)	196		117		351		226
Average realized price per pound	$	2.61	$	3.19	$	2.66	$	3.15
Gold (thousands of recoverable ounces)
Production (thousands of ounces)	360		142		615		350
Sales (thousands of ounces)	346		135		606		297
Average realized price per ounce	$	1,173	$	1,294	$	1,183	$	1,299
100% Operating Data
Ore milled (metric tons per day):a
Grasberg open pit	134,200		50,700		121,200		58,200
DOZ underground mineb	42,700		50,500		45,800		50,400
Big Gossan underground minec	—		1,700		—		1,800
Total	176,900		102,900		167,000		110,400
Average ore grades:
Copper (percent)	0.67		0.73		0.63		0.72
Gold (grams per metric ton)	0.86		0.65		0.78		0.72
Recovery rates (percent):
Copper	90.6		89.0		90.6		88.7
Gold	83.5		76.3		83.9		78.1
Production (recoverable):
Copper (millions of pounds)	205		125		359		269
Gold (thousands of ounces)	360		142		615		351

a. Amounts represent the approximate average daily throughput processed at PT-FI’s mill facilities from each producing mine.

b. Ore milled from the DOZ underground mine is expected to ramp up to 70,000 metric tons of ore per day in the second half of 2015.

c. Production from the Big Gossan underground mine is expected to restart in the second half of 2016 and ramp up to 7,000 metric tons of ore per day in 2018.

Indonesia's sales volumes increased to 196 million pounds of copper and 346 thousand ounces of gold in second-quarter2015 and 351 million pounds of copper and 606 thousand ounces of gold for the first six months of 2015, compared with 117 million pounds of copper and 135 thousand ounces of gold in second-quarter2014 and 226 million pounds of copper and 297 thousand ounces of gold for the first six months of 2014, primarily reflecting higher operating rates and higher ore grades for gold.

At the Grasberg mine, the sequencing of mining areas with varying ore grades causes fluctuations in quarterly and annual production of copper and gold. PT-FI expects ore grades to increase beginning in fourth-quarter 2015 through 2017 as high-grade sections of the Grasberg open pit are mined. Consolidated sales volumes from our Indonesia mining operations are expected to approximate 860 million pounds of copper and 1.3 million ounces of

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gold for the year 2015, compared with 664 million pounds of copper and 1.2 million ounces of gold for the year 2014.

Unit Net Cash Costs. Unit net cash costs per pound of copper is a measure intended to provide investors with information about the cash-generating capacity of our mining operations expressed on a basis relating to the primary metal product for our respective operations. We use this measure for the same purpose and for monitoring operating performance by our mining operations. This information differs from measures of performance determined in accordance with U.S. GAAP and should not be considered in isolation or as a substitute for measures of performance determined in accordance with U.S. GAAP. This measure is presented by other metals mining companies, although our measure may not be comparable to similarly titled measures reported by other companies.

Gross Profit (Loss) per Pound of Copper and per Ounce of Gold

The following table summarizes the unit net cash costs and gross profit (loss) per pound of copper and per ounce of gold at our Indonesia mining operations for the second quarters and first six months of 2015 and 2014. Refer to “Production Revenues and Production Costs” for an explanation of “by-product” and “co-product” methods and a reconciliation of unit net cash costs per pound to production and delivery costs applicable to sales reported in our consolidated financial statements.

	Three Months Ended										Three Months Ended
	June 30, 2015										June 30, 2014
	By-Product Method				Co-Product Method						By-Product Method				Co-Product Method
					Copper			Gold							Copper			Gold
Revenues, excluding adjustments	$	2.61			$	2.61		$	1,173		$	3.19			$	3.19		$	1,294
Site production and delivery, before net noncash and other costs shown below	2.26				1.25			560			3.86			a	2.59			1,050
Gold and silver credits	(2.13		)		—			—			(1.57		)		—			—
Treatment charges	0.32				0.18			79			0.26				0.17			70
Export duties	0.18				0.10			45			—				—			—
Royalty on metals	0.18			b	0.10			45			0.11				0.08			31
Unit net cash costs	0.81				1.63			729			2.66				2.84			1,151
Depreciation and amortization	0.40				0.22			100			0.47				0.31			127
Noncash and other costs, net	0.04				0.02			10			0.55			a	0.37			151
Total unit costs	1.25				1.87			839			3.68				3.52			1,429
Revenue adjustments, primarily for pricing on prior period open sales	(0.02		)		(0.02		)	7			0.09				0.09			5
PT Smelting intercompany (loss) profit	(0.02		)		(0.01		)	(5		)	0.03				0.02			9
Gross profit (loss) per pound/ounce	$	1.32			$	0.71		$	336		$	(0.37	)		$	(0.22	)	$	(121	)
Copper sales (millions of recoverable pounds)	196				196						117				117
Gold sales (thousands of recoverable ounces)								346										135

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	Six Months Ended									Six Months Ended
	June 30, 2015									June 30, 2014
	By-Product Method				Co-Product Method					By-Product Method				Co-Product Method
					Copper			Gold						Copper			Gold
Revenues, excluding adjustments	$	2.66			$	2.66		$	1,183	$	3.15			$	3.15		$	1,299
Site production and delivery, before net noncash and other costs shown below	2.51				1.41			626		3.60			a	2.31			950
Gold and silver credits	(2.11		)		—			—		(1.85		)		—			—
Treatment charges	0.31				0.17			77		0.25				0.16			65
Export duties	0.16				0.09			41		—				—			—
Royalty on metals	0.17			b	0.10			42		0.12				0.07			31
Unit net cash costs	1.04				1.77			786		2.12				2.54			1,046
Depreciation and amortization	0.42				0.24			106		0.45				0.29			120
Noncash and other costs, net	0.04				0.02			10		0.61			a	0.39			161
Total unit costs	1.50				2.03			902		3.18				3.22			1,327
Revenue adjustments, primarily for pricing on prior period open sales	(0.15		)		(0.15		)	14		(0.24		)		(0.24		)	59
PT Smelting intercompany profit	0.01				0.01			2		0.26				0.16			68
Gross profit (loss) per pound/ounce	$	1.02			$	0.49		$	297	$	(0.01	)		$	(0.15	)	$	99
Copper sales (millions of recoverable pounds)	351				351					226				226
Gold sales (thousands of recoverable ounces)								606									297

a. Fixed costs totaling $0.48 per pound of copper charged directly to cost of sales as a result of the impact of export restrictions on PT-FI's operating rates are excluded from site production and delivery and included in net noncash and other costs for the second quarter and first six months of 2014.

b. Includes $0.07 per pound of copper for the second quarter and first six months of 2015 associated with PT-FI's increased royalty rates.

A significant portion of PT-FI's costs are fixed and unit costs vary depending on sales volumes. Indonesia's unit net cash costs (net of gold and silver credits) totaled $0.81 per pound of copper in second-quarter2015 and $1.04 per pound of copper for the first six months of 2015, compared with $2.66 per pound in second-quarter2014 and $2.12 per pound of copper for the first six months of 2014, primarily reflecting higher gold and silver credits and higher copper sales volumes, partly offset by the impact of export duties and increased royalty rates.

Treatment charges vary with the volume of metals sold and the price of copper, and royalties vary with the volume of metals sold and the prices of copper and gold.

Because certain assets are depreciated on a straight-line basis, PT-FI’s unit depreciation rate varies with the level of copper production and sales.

Revenue adjustments primarily result from changes in prices on provisionally priced copper sales recognized in prior periods. Refer to “Consolidated Results - Revenues” for further discussion of adjustments to prior period provisionally priced copper sales.

PT Smelting intercompany profit represents the change in the deferral of 25 percent of PT-FI's profit on sales to PT Smelting. Refer to "Operations - Smelting & Refining" for further discussion.

Based on current sales volume and cost estimates, and assuming an average gold price of $1,150 per ounce for the second half of 2015, Indonesia's unit net cash costs (net of gold and silver credits) are expected to approximate $1.08 per pound of copper for the year 2015, compared with $1.06 for the year 2014. Indonesia's projected unit net cash costs would change by approximately $0.05 per pound for each $50 per ounce change in the average price of gold for the second half of 2015. Because of the fixed nature of a large portion of Indonesia's costs, unit costs vary from quarter to quarter depending on copper and gold volumes.

Africa Mining

Africa mining includes the Tenke minerals district. We hold an effective 56 percent interest in the Tenke copper and cobalt mining concessions in the Katanga province of the DRC through our consolidated subsidiary Tenke Fungurume Mining S.A. (TFM), and we are the operator of Tenke.

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The Tenke operation includes open-pit mining, leaching and SX/EW operations. Copper production from the Tenke minerals district is sold as copper cathode. In addition to copper, the Tenke minerals district produces cobalt hydroxide.

As further discussed in “Overview,” we are currently reviewing operating plans at each of our copper and molybdenum mining operations and will revise operating and capital plans to strengthen our financial position in a weak copper price environment. The revised plans will target lower operating and capital costs to achieve maximum cash flow under the current market conditions. Production at certain operations challenged by low commodity prices will be curtailed. We expect to complete this review promptly and will report our revised plans during third-quarter 2015. Accordingly, our sales volume and unit costs estimates discussed below are subject to change as a result of this review and other factors.

Operating and Development Activities. TFM completed its second phase expansion project in early 2013, which included increasing mine, mill and processing capacity. Construction of a second sulphuric acid plant is under way, with completion expected in the first half of 2016. We continue to engage in exploration activities and metallurgical testing to evaluate the potential of the highly prospective minerals district at Tenke. These analyses are being incorporated in future plans for potential expansions of production capacity. Future expansions are subject to a number of factors, including power availability, economic and market conditions, and the business and investment climate in the DRC.

Operating Data. Following is summary operating data for our Africa mining operations for the second quarters and first six months of 2015 and 2014:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2015		2014		2015		2014
Copper (recoverable)
Production (millions of pounds)	115		114		231		223
Sales (millions of pounds)	104		118		237		202
Average realized price per pounda	$	2.63	$	3.08	$	2.66	$	3.08
Cobalt (contained)
Production (millions of pounds)	9		7		16		14
Sales (millions of pounds)	8		7		16		15
Average realized price per pound	$	9.27	$	9.58	$	9.23	$	9.29
Ore milled (metric tons per day)	15,300		15,200		14,900		14,800
Average ore grades (percent):
Copper	4.02		4.08		4.18		4.07
Cobalt	0.44		0.34		0.40		0.33
Copper recovery rate (percent)	93.9		92.7		93.9		93.7

a. Includes point-of-sale transportation costs as negotiated in customer contracts.

TFM's copper sales of 104 million pounds in second-quarter2015 were lower than second-quarter 2014 copper sales of 118 million pounds primarily because of timing of shipments. TFM's copper sales for the first six months of 2015 of 237 million were higher than copper sales of 202 million for the first six months of 2014, primarily reflecting higher ore grades and timing of shipments.

For the year 2015, we expect sales volumes from TFM to approximate 460 million pounds of copper and 36 million pounds of cobalt, compared with 425 million pounds of copper and 30 million pounds of cobalt for the year 2014.

Unit Net Cash Costs. Unit net cash costs per pound of copper is a measure intended to provide investors with information about the cash-generating capacity of our mining operations expressed on a basis relating to the primary metal product for our respective operations. We use this measure for the same purpose and for monitoring operating performance by our mining operations. This information differs from measures of performance determined in accordance with U.S. GAAP and should not be considered in isolation or as a substitute for measures of

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performance determined in accordance with U.S. GAAP. This measure is presented by other metals mining companies, although our measure may not be comparable to similarly titled measures reported by other companies.

Gross Profit per Pound of Copper and Cobalt

The following table summarizes the unit net cash costs and gross profit per pound of copper and cobalt at our Africa mining operations for the second quarters and first six months of 2015 and 2014. Refer to “Production Revenues and Production Costs” for an explanation of “by-product” and “co-product” methods and a reconciliation of unit net cash costs per pound to production and delivery costs applicable to sales reported in our consolidated financial statements.

	Three Months Ended							Three Months Ended
	June 30, 2015							June 30, 2014
	By-Product Method			Co-Product Method				By-Product Method			Co-Product Method
				Copper		Cobalt					Copper		Cobalt
Revenues, excluding adjustmentsa	$	2.63		$	2.63	$	9.27	$	3.08		$	3.08	$	9.58
Site production and delivery, before net noncash and other costs shown below	1.54			1.35		5.48		1.46			1.35		5.22
Cobalt creditsb	(0.53		)	—		—		(0.34		)	—		—
Royalty on metals	0.06			0.05		0.16		0.06			0.06		0.15
Unit net cash costs	1.07			1.40		5.64		1.18			1.41		5.37
Depreciation, depletion and amortization	0.55			0.43		1.42		0.54			0.46		1.30
Noncash and other costs, net	0.03			0.03		0.10		0.03			0.03		0.08
Total unit costs	1.65			1.86		7.16		1.75			1.90		6.75
Revenue adjustments, primarily for pricing on prior period open sales	0.02			0.02		0.50		—			—		(0.19		)
Gross profit per pound	$	1.00		$	0.79	$	2.61	$	1.33		$	1.18	$	2.64
Copper sales (millions of recoverable pounds)	104			104				118			118
Cobalt sales (millions of contained pounds)						8							7

	Six Months Ended									Six Months Ended
	June 30, 2015									June 30, 2014
	By-Product Method			Co-Product Method						By-Product Method			Co-Product Method
				Copper			Cobalt						Copper			Cobalt
Revenues, excluding adjustmentsa	$	2.66		$	2.66		$	9.23		$	3.08		$	3.08		$	9.29
Site production and delivery, before net noncash and other costs shown below	1.56			1.37			5.54			1.47			1.30			5.19
Cobalt creditsb	(0.44		)	—			—			(0.48		)	—			—
Royalty on metals	0.06			0.05			0.15			0.07			0.06			0.16
Unit net cash costs	1.18			1.42			5.69			1.06			1.36			5.35
Depreciation, depletion and amortization	0.55			0.46			1.31			0.57			0.49			1.03
Noncash and other costs, net	0.03			0.03			0.08			0.05			0.04			0.09
Total unit costs	1.76			1.91			7.08			1.68			1.89			6.47
Revenue adjustments, primarily for pricing on prior period open sales	(0.03		)	(0.03		)	(0.04		)	(0.01		)	(0.01		)	0.13
Gross profit per pound	$	0.87		$	0.72		$	2.11		$	1.39		$	1.18		$	2.95
Copper sales (millions of recoverable pounds)	237			237						202			202
Cobalt sales (millions of contained pounds)							16									15

a. Includes point-of-sale transportation costs as negotiated in customer contracts. 

b. Net of cobalt downstream processing and freight costs.

Unit net cash costs (net of cobalt credits) for our Africa operations of $1.07 per pound of copper in second-quarter2015 were lower than unit net cash costs of $1.18 per pound in second-quarter2014, primarily reflecting higher cobalt credits, partly offset by lower copper sales volumes. Africa's unit net cash costs of $1.18 per pound of copper

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for the first six months of 2015 were higher than unit net cash costs of $1.06 per pound for the first six months of 2014, primarily reflecting higher site production and delivery costs, partly offset by higher copper sales volumes.

Because certain assets are depreciated on a straight-line basis, Africa's unit depreciation rate may vary with the level of copper production and sales.

Assuming achievement of current sales volume and cost estimates, and an average cobalt market price of $13 per pound for the second half of 2015, average unit net cash costs (net of cobalt credits) are expected to approximate $1.12 per pound of copper for the year 2015, compared with $1.15 per pound in 2014. Africa's projected unit net cash costs would change by $0.05 per pound for each $2 per pound change in the average price of cobalt during the second half of 2015.

Molybdenum Mines

We have two wholly owned molybdenum mines in North America – the Henderson underground mine and the Climax open-pit mine, both in Colorado. The Henderson and Climax mines produce high-purity, chemical-grade molybdenum concentrates, which are typically further processed into value-added molybdenum chemical products. The majority of the molybdenum concentrates produced at the Henderson and Climax mines, as well as from our North and South America copper mines, are processed at our own conversion facilities.

Production from the Molybdenum mines totaled 13 million pounds of molybdenum in second-quarter2015, 26 million pounds of molybdenum for the first six months of 2015, 14 million pounds of molybdenum in second-quarter2014 and 27 million pounds of molybdenum for the first six months of 2014. Refer to "Consolidated Results" for our consolidated molybdenum operating data, which includes sales of molybdenum produced at our Molybdenum mines, and from our North and South America copper mines, and refer to "Outlook" for projected consolidated molybdenum sales volumes.

Unit Net Cash Costs Per Pound of Molybdenum. Unit net cash costs per pound of molybdenum is a measure intended to provide investors with information about the cash-generating capacity of our mining operations expressed on a basis relating to the primary metal product for our respective operations. We use this measure for the same purpose and for monitoring operating performance by our mining operations. This information differs from measures of performance determined in accordance with U.S. GAAP and should not be considered in isolation or as a substitute for measures of performance determined in accordance with U.S. GAAP. This measure is presented by other metals mining companies, although our measure may not be comparable to similarly titled measures reported by other companies.

Average unit net cash costs for our Molybdenum mines of $7.19 per pound of molybdenum in second-quarter2015 and $7.18 per pound of molybdenum for the first six months of 2015 were higher than average unit net cash costs of $6.47 per pound in second-quarter2014 and $6.58 per pound of molybdenum for the first six months of 2014, primarily reflecting lower production volumes from the Henderson mine. Assuming achievement of current sales volume and cost estimates, we estimate unit net cash costs for the Molybdenum mines to average $7.50 per pound of molybdenum for the year 2015, compared with $7.08 per pound in 2014. Refer to “Product Revenues and Production Costs” for a reconciliation of unit net cash costs per pound to production and delivery costs applicable to sales reported in our consolidated financial statements.

As further discussed in “Overview,” we are currently reviewing operating plans at each of our copper and molybdenum mining operations and will revise operating and capital plans to strengthen our financial position in a weak copper price environment. The revised plans will target lower operating and capital costs to achieve maximum cash flow under the current market conditions. Production at certain operations challenged by low commodity prices will be curtailed. We expect to complete this review promptly and will report our revised plans during third-quarter 2015. Accordingly, our molybdenum sales volume and unit costs estimates are subject to change as a result of this review and other factors.

Smelting & Refining

We wholly own and operate a smelter in Arizona (Miami smelter) and a smelter and refinery in Spain (Atlantic Copper). Additionally, PT-FI owns 25 percent of a smelter and refinery in Gresik, Indonesia (PT Smelting). Treatment charges for smelting and refining copper concentrates consist of a base rate and, in certain contracts, price participation based on copper prices. Treatment charges represent a cost to our mining operations and income to Atlantic Copper and PT Smelting. Thus, higher treatment charges benefit our smelter operations and adversely affect our mining operations. Our North America copper mines are less significantly affected by changes

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in treatment charges because these operations are largely integrated with our Miami smelter. Through this form of downstream integration, we are assured placement of a significant portion of our concentrate production.

Atlantic Copper smelts and refines copper concentrates and markets refined copper and precious metals in slimes. During the first six months of 2015, Atlantic Copper purchased 25 percent of its concentrate requirements from our North America mining operations and 5 percent of its concentrate requirements from our South America mining operations, with the remainder purchased from third parties.

PT-FI's contract with PT Smelting provides for PT-FI to supply 100 percent of the copper concentrate requirements (subject to a minimum or maximum rate) necessary for PT Smelting to produce 205,000 metric tons of copper annually on a priority basis. PT-FI also sells copper concentrate to PT Smelting at market rates for quantities in excess of 205,000 metric tons of copper annually. During the first six months of 2015, PT-FI sold approximately half of its copper concentrate production to PT Smelting. In July 2015, PT Smelting's operations were temporarily suspended pending completion of required repairs, which are expected to be completed in September 2015.

We defer recognizing profits on sales from our mining operations to Atlantic Copper and on 25 percent of Indonesia mining's sales to PT Smelting until final sales to third parties occur. Changes in these deferrals attributable to variability in intercompany volumes resulted in net additions to net income attributable to common stockholders of $13 million in second-quarter2015 and $37 million for the first six months of 2015, compared with $41 million in second-quarter2014 and $56 million for the first six months of 2014. Our net deferred profits on inventories at Atlantic Copper and PT Smelting to be recognized in future periods’ net income attributable to common stockholders totaled $28 million at June 30, 2015. Quarterly variations in ore grades, the timing of intercompany shipments and changes in product prices will result in variability in our net deferred profits and quarterly earnings.

Oil and Gas

Through our wholly owned oil and gas subsidiary FCX Oil & Gas Inc. (FM O&G), our portfolio of oil and gas assets includes significant oil production facilities and growth potential in the Deepwater GOM, established oil production facilities onshore and offshore California, large onshore natural gas resources in the Haynesville shale play in Louisiana, natural gas production from the Madden area in Central Wyoming, and a position in the Inboard Lower Tertiary/Cretaceous natural gas trend onshore in South Louisiana. For the first six months of 2015, 88 percent of our oil and gas revenues, excluding the impact of derivative contracts, were from oil and NGLs.

On June 23, 2015, our wholly owned subsidiary, Freeport-McMoRan Oil & Gas Inc., filed a registration statement on Form S-1 with the U.S. SEC related to its potential IPO of Class A common stock, representing a minority interest in the entity. Freeport-McMoRan Oil & Gas Inc. intends to apply to list the common stock on the New York Stock Exchange under the ticker “FMOG.” The registration statement has not yet become effective, and securities may not be sold nor may offers to buy be accepted prior to the time the registration statement becomes effective.

On August 5, 2015, we announced the deferral of investments in several long-term projects in our oil and gas business, which will result in a reduction of $0.9 billion in projected capital expenditures for each of the years 2016 and 2017. We have also revised our estimate of the start-up of initial production from its recent drilling success in the Horn Mountain area to 2016 from the previously estimated start-up in 2017. This revised operating plan will allow FM O&G to continue to grow production and enhance cash flow in a weak oil and gas price environment. The revised plans, together with the potential IPO of a minority interest in Freeport-McMoRan Oil & Gas Inc., and potential other actions, will be pursued as required to fund oil and gas capital spending with cash flow for 2016 and subsequent years.

Impairment of Oil and Gas Properties. We follow the full cost method of accounting for our oil and gas operations, whereby all costs associated with oil and gas property acquisition, exploration and development activities are capitalized and amortized to expense under the UOP method on a country-by-country basis using estimates of proved oil and natural gas reserves relating to each country where such activities are conducted. The costs of unproved oil and gas properties are excluded from amortization until the properties are evaluated. Our DD&A rate is affected by changes to estimates of proved reserves and costs subject to amortization, as further discussed in "Critical Accounting Estimates" in Part II, Items 7. and 7A. of our annual report on Form 10-K for the year ended December 31, 2014.

Under full cost accounting rules, a "ceiling test" is conducted each quarter to review the carrying value of our oil and gas properties for impairment. The SEC requires the twelve-month average of the first-day-of-the-month historical reference oil price be used in determining the ceiling test limitation. Using West Texas Intermediate (WTI) as the

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reference oil price, the average price was $71.68 per barrel at June 30, 2015, compared with $82.72 per barrel at March 31, 2015. As of June 30, 2015, and March 31, 2015, net capitalized costs with respect to FM O&G's proved U.S. oil and gas properties exceeded the ceiling test limitation specified by the SEC's full cost accounting rules, which resulted in the recognition of impairment charges totaling $2.7 billion ($1.7 billion to net loss attributable to common stock) in second-quarter 2015 and $5.8 billion ($3.6 billion to net loss attributable to common stock) for the first six months of 2015.

If the twelve-month historical average price remains below the June 30, 2015, twelve-month average of $71.68 per barrel, the ceiling test limitation will decrease resulting in potentially significant additional ceiling test impairments of our oil and gas properties. The WTI spot oil price was $47.12 per barrel at July 31, 2015.

If the trailing twelve-month average prices for the period ended June 30, 2015, had been $59.35 per barrel of oil and $3.07 per MMBtu for natural gas, while all other inputs and assumptions remained constant, an additional pre-tax impairment charge of $1.8 billion would have been recorded to our oil and gas properties in second-quarter 2015. These oil and natural gas prices were determined using a twelve-month simple average of the first day of the month for the eleven months ended August 2015, and the August 2015, prices were held constant for the remaining one month. The additional pre-tax impairment is partly the result of a 26 percent decrease in proved undeveloped reserves because certain locations would not be economic at these prices. This calculation solely reflects the impact of hypothetical lower oil and natural gas prices on our ceiling test limitation and proved reserves as of June 30, 2015, and does not reflect the reduction in oil and gas capital expenditures that was announced on August 5, 2015. The oil and natural gas price is a single variable in the estimation of our proved reserves and other factors could have a significant impact on future reserves and the present value of future cash flows.

As further discussed in "Critical Accounting Estimates" in Part II, Items 7. and 7A. of our annual report on Form 10-K for the year ended December 31, 2014, in addition to declines in the trailing twelve-month average oil and natural gas prices, other factors that could result in future impairment of our oil and gas properties, include costs transferred from unevaluated properties to the full cost pool without corresponding proved oil and natural gas reserve additions, negative reserve revisions and increased future development or production costs. As FM O&G completes activities to assess its $9.3 billion in unevaluated properties, related costs currently recorded as unevaluated properties not subject to amortization will be transferred to the full cost pool. If these activities do not result in additions to discounted future net cash flows from proved oil and natural gas reserves at least equal to the related costs transferred (net of related tax effects), additional ceiling test impairments may occur.

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U.S. Oil and Gas Operations. Following is summary operating results for the U.S. oil and gas operations for the second quarters and first six months of 2015 and 2014:

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014a			2015			2014a
Sales Volumes
Oil (MMBbls)	8.6			11.7			17.0			23.5
Natural gas (Bcf)	23.5			20.3			45.3			39.8
NGLs (MMBbls)	0.6			1.0			1.1			2.1
MMBOE	13.1			16.0			25.6			32.2
Average Realized Pricesb
Oil (per barrel)	$	67.61		$	95.50		$	62.13		$	94.63
Natural gas(per MMBtu)	$	2.66		$	4.44		$	2.75		$	4.55
NGLs (per barrel)	$	20.50		$	38.79		$	21.71		$	42.35
Gross (Loss) Profit per BOE
Realized revenuesb	$	50.04		$	77.53		$	46.95		$	77.37
Less: cash production costsb	19.04			19.57			19.62			19.03
Cash operating marginb	31.00			57.96			27.33			58.34
Less: depreciation, depletion and amortization	36.99			38.39			39.59			38.30
Less: impairment of oil and gas properties	204.91			—			225.89			—
Less: accretion and other costs	2.46			0.94			2.39			0.87
Plus: net noncash mark-to-market (losses) gains on derivative contracts	(7.26		)	(0.44		)	(5.60		)	0.23
Plus: other net adjustments	0.61			0.04			0.34			0.04
Gross (loss) profit	$	(220.01	)	$	18.23		$	(245.80	)	$	19.44

a. The 2014 periods include results from the Eagle Ford field through June 19, 2014. Eagle Ford had sales volumes totaling 4.0 MMBOE for second-quarter 2014 and 8.7 MMBOE for the first six months of 2014; excluding Eagle Ford, oil and gas cash production costs were $21.66 per BOE for second-quarter 2014 and $21.29 per BOE for the first six months of 2014.

b. Cash operating margin for our oil and gas operations reflects realized revenues less cash production costs. Realized revenues exclude noncash mark-to-market adjustments on derivative contracts. For reconciliations of realized revenues (including average realized prices for oil, natural gas and NGLs) and cash production costs to revenues and production and delivery costs reported in our consolidated financial statements, refer to the supplemental schedule, "Product Revenues and Production Costs."

FM O&G's average realized price for crude oil was $67.61 per barrel, including $11.79 per barrel of cash gains on derivative contracts, in second-quarter2015 and $62.13 per barrel, including $11.88 per barrel of cash gains on derivative contracts, for the first six months of 2015. Excluding the impact of derivative contracts, the second-quarter2015 average realized price for crude oil was $55.82 per barrel (88 percent of the average Brent crude oil price of $63.57 per barrel) and $50.25 per barrel (85 percent of the average Brent crude oil price of $59.41 per barrel) for the first six months of 2015.

FM O&G has derivative contracts that provide price protection averaging between approximately $70 and $90 per barrel of Brent crude oil for more than 80 percent of estimated 2015 oil production. Assuming an average price of $56 per barrel for Brent crude oil, we would receive a benefit of $20 per barrel on remaining 2015 derivative contract volumes of 15.5 MMBbls, before taking into account weighted-average premiums of $6.89 per barrel. See Note 7 for further discussion.

FM O&G's average realized price for natural gas was $2.66 per MMBtu in second-quarter2015, compared to the NYMEX natural gas price average of $2.65 per MMBtu for the April through June 2015 contracts; and $2.75 per MMBtu for the first six months of 2015, compared to the NYMEX natural gas price average of $2.81 per MMBtu for the January through June 2015 contracts.

Realized revenues for oil and gas operations of $50.04 per BOE in second-quarter2015 and $46.95 per BOE for the first six months of 2015 were lower than realized revenues of $77.53 per BOE in second-quarter 2014 and $77.37 per BOE for the first six months of 2014, primarily reflecting lower oil prices, partly offset by the impact of higher realized cash gains on derivative contracts (cash gains were $101 million or $7.73 per BOE in second-

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quarter2015 and $201 million or $7.87 per BOE for the first six months of 2015, compared with losses of $63 million or $3.94 per BOE in second-quarter 2014 and $128 million or $3.97 per BOE for the first six months of 2014).

Cash production costs for oil and gas operations of $19.04 per BOE in second-quarter2015 were lower than cash production costs of $19.57 per BOE in second-quarter 2014, primarily reflecting lower cash production costs in California related to reductions in repair and maintenance costs and well workover expense, partly offset by the impact of the sale of lower-cost Eagle Ford properties in June 2014. Cash production costs for oil and gas properties of $19.62 per BOE for the first six months of 2015 were higher than cash production costs of $19.03 per BOE for the first six months of 2014, primarily reflecting the sale of lower-cost Eagle Ford properties in June 2014, partly offset by lower cash production costs in California related to reductions in repair and maintenance costs and well workover expense.

Following is a summary of average sales volumes per day by region for oil and gas operations for the second quarters and first six months of 2015 and 2014:

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2015	2014	2015	2014a
Sales Volumes (MBOE per day):
GOMa	80	75	77	73
California	38	39	39	39
Haynesville/Madden/Other	26	18	26	18
Eagle Fordb	—	44	—	48
Total oil and gas operations	144	176	142	178

a. Includes sales from properties on the GOM Shelf and in the Deepwater GOM.

b. FM O&G completed the sale of Eagle Ford in June 2014.

Daily sales volumes averaged 144 MBOE in second-quarter2015, including 95 MBbls of crude oil, 259 million cubic feet (MMcf) of natural gas and 5 MBbls of NGLs, and 142 MBOE for the first six months of 2015, including 94 MBbls of crude oil, 250 MMcf of natural gas and 6 MBbls of NGLs. Oil and gas sales volumes are expected to average 145 MBOE per day for the year 2015, comprised of 68 percent oil, 27 percent natural gas and 5 percent NGLs.

Based on current sales volume and cost estimates, cash production costs are expected to approximate $20 per BOE for the year 2015.

Exploration, Operating and Development Activities. Our oil and gas business has significant proved, probable and possible reserves, a broad range of development opportunities and high-potential exploration prospects. The business is managed to reinvest its cash flows in projects with attractive rates of return and risk profiles. Following the sharp decline in oil prices in late 2014, we have taken steps to significantly reduce capital spending plans and are evaluating funding opportunities for capital expenditures for our oil and gas business, including the potential IPO for a minority interest in Freeport-McMoRan Oil & Gas Inc.

FM O&G is focused on growing its strategic position in the Deepwater GOM with significant current oil production, strong cash margins and existing infrastructure and facilities with excess production and handling capacity. These assets, combined with FM O&G’s large leasehold interests in an established geologic basin, provide financially attractive investment opportunities for high-impact growth in oil production and cash margins. FM O&G’s capital allocation strategy is principally focused on development opportunities that can be tied back to existing facilities.

During second-quarter 2015, FM O&G achieved several important accomplishments, principally in its Deepwater GOM focus areas, that are expected to contribute to future growth. Production reached full capacity at the Lucius facility and development advanced at the Heidelberg field. Positive drilling results were achieved at the Holstein Deep and Quebec/Victory (QV), Kilo/Oscar (KO) and Horn Mountain Updip tieback prospects. Since commencing development activities in 2014 at its three 100-percent-owned production platforms in the Deepwater GOM, FM O&G has drilled 10 wells with positive results. Three of these wells have been brought on production, and FM O&G plans to complete and place in production six wells over the next 12 months and the remaining well in 2017. Longer term, FM O&G's production is expected to benefit from the success in the Atwater Valley focus area, where multiple

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discoveries have been drilled to date. During second-quarter 2015, FM O&G commenced drilling at the Deep Sleep exploration well in the Atwater Valley focus area.

U.S. Oil and Gas Capital Expenditures. Capital expenditures for our U.S. oil and gas operations totaled $0.8 billion (including $0.6 billion incurred for the Deepwater GOM and $0.1 billion for the Inboard Lower Tertiary/Cretaceous natural gas trend) for second-quarter 2015 and $1.8 billion (including $1.2 billion incurred for Deepwater GOM and $0.2 billion for the Inboard Lower Tertiary/Cretaceous natural gas trend) for the first six months of 2015.

Capital expenditures for oil and gas operations are estimated to total $2.8 billion for the year 2015, with approximately 85 percent of the 2015 capital budget expected to be directed to the highest potential return focus areas in the GOM.

Deepwater GOM. The drilling and evaluation of multiple development and exploration opportunities in the Deepwater GOM is in progress. These prospects benefit from tieback opportunities to significant available production capacity at the FM O&G operated large-scale Holstein, Marlin and Horn Mountain deepwater production platforms. In addition, FM O&G has interests in the Lucius and Heidelberg oil fields, and in the Atwater Valley focus area.

After successfully commencing first production in January 2015, the Lucius oil facility in Keathley Canyon reached capacity of 80 MBbls of oil per day in second-quarter 2015. FM O&G has a 25.1 percent working interest in Lucius, which consists of six subsea wells located in 7,200 feet of water tied back to a truss spar hull.

Field development continued at Heidelberg in the Green Canyon focus area during second-quarter 2015. Fabrication of the main topsides module is complete, the hull is on location, and mooring lines are completed. The Heidelberg truss spar was designed as a Lucius-look-alike facility with capacity of 80 MBbls of oil per day. Development drilling in the field is ongoing and first production is anticipated in 2016. Completion activities on the three initial wells are in progress. FM O&G has a 12.5 percent working interest in Heidelberg, which is a large, high-quality oil development project located in 5,300 feet of water.

In July 2015, FM O&G logged its third successful subsalt Miocene delineation well at the 100-percent-owned Holstein Deep development project in the Green Canyon focus area since commencing drilling in the area in third-quarter 2014. The third delineation well, which is the most updip in the reservoir, was drilled to 29,440 feet and wireline logs indicated that the well encountered approximately 200 feet of net oil pay. Drilling results from this initial three-well development program successfully established sand continuity across the primary reservoir.

Completion activities for the initial three-well subsea tieback development program are expected to commence in third-quarter 2015 and production is expected to begin in 2016. Successful results from the initial three-well drilling program established opportunities for additional wells. When fully developed, this project will have the potential to produce up to 75 MBOE per day. The Holstein Deep development is located in Green Canyon Block 643, west of the Holstein platform in 3,890 feet of water with production facilities capable of processing 113 MBbls of oil per day.

FM O&G’s 100-percent-owned Marlin Hub is located in the Mississippi Canyon focus area and has production facilities capable of processing 60 MBbls of oil per day. Several tieback opportunities have been identified, including the 100-percent-owned Dorado and King development projects. Future wells can be brought on-line using existing infrastructure with the potential to utilize subsea enhancement technologies that could increase total recovery efficiencies. In second-quarter 2015, FM O&G completed maintenance activities, including the installation of new export flow line flex joints, which will extend the life of the Marlin platform.

The initial FM O&G drilled Dorado well was placed in production in March 2015 after a successful production test with gross volumes in excess of 8 MBOE per day and continues to produce at strong rates. Drilling operations for the second and third wells, which are targeting similar undrained fault blocks and updip resource potential south of the Marlin facility, are expected to begin in 2016. The Dorado development is located on Viosca Knoll Block 915 in 3,860 feet of water.

Initial production from the first exploration well at King is expected to commence in fourth-quarter 2015, and additional drilling is planned in the area starting in the second-half of 2015. King is located in Mississippi Canyon south of the Marlin facility in 5,200 feet of water.

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FM O&G’s 100-percent-owned Horn Mountain field is also located in the Mississippi Canyon focus area and has production facilities capable of processing 75 MBbls of oil per day. To enhance recovery of remaining oil in place, future development plans will target subsea tieback from multiple stacked sands in the area. In second-quarter 2015, the QV well, the first location of this program, was drilled to 14,780 feet and successfully logged 355 net feet of oil and gas pay. In June 2015, drilling operations commenced at the KO and Horn Mountain Updip wells. At KO, the well was drilled to a total depth of 14,250 feet in July 2015 and successfully logged 166 net feet of oil pay. FM O&G plans to complete the KO and QV wells and place them in production in 2016. At Horn Mountain Updip, the well was drilled to a total depth of 14,780 feet in July 2015 and successfully logged 112 net feet of oil and gas pay. These infill wells are targeting undrained fault blocks and updip resource potential east and west of the Horn Mountain facility, which is located in approximately 5,400 feet of water.

FM O&G has an 18.67 percent working interest in the Vito oil discovery and a significant lease position in the Atwater Valley focus area. Vito is a large, deep subsalt Miocene oil discovery made in 2009, located in approximately 4,000 feet of water. Exploration and delineation drilling in recent years confirmed a significant resource in high-quality, subsalt Miocene sands. Development options are under evaluation and FM O&G expects the operator to propose a sanctioning development plan in 2016.

As previously reported, success at the Power Nap exploration well and appraisal sidetracks, which are located in close proximity to Vito, produced positive results and development options are being assessed. The neighboring Deep Sleep exploration well in the greater Mars/Ursa basin commenced drilling in June 2015. Deep Sleep is located in 4,200 feet of water approximately five miles south of Power Nap. FM O&G owns a 50 percent working interest in the Power Nap and Deep Sleep prospects.

Inboard Lower Tertiary/Cretaceous. FM O&G has a position in the Inboard Lower Tertiary/Cretaceous natural gas trend, located onshore in South Louisiana.

In second-quarter 2015, the Highlander well, which has been restricted because of limited processing facilities, averaged a gross rate of 22 MMcf per day (approximately 11 MMcf per day net to FM O&G). As previously reported production testing in February 2015 indicated a flow rate of 75 MMcf per day (approximately 37 MMcf per day net to FM O&G). FM O&G is developing additional processing facilities to accommodate the higher flow rates with installation expected by year-end 2015. In July 2015, the Highlander well was shut in for remedial workover operations to address a mechanical issue encountered in the wellbore. A second well location has been identified, and future plans are being considered. FM O&G is the operator and has a 72 percent working interest and an approximate 49 percent net revenue interest in Highlander. FM O&G has identified multiple additional locations on the Highlander structure, which is located onshore in South Louisiana where FM O&G controls rights to more than 50,000 gross acres.

The Farthest Gate West onshore exploration prospect was drilled to a total depth of approximately 22,000 feet in March 2015. In May 2015, we completed our assessment of the Farthest Gate West well and commenced plug and abandonment activities. No proved reserves were identified.

California. Sales volumes from California averaged 38 MBOE per day for second-quarter 2015, compared with 39 MBOE per day for second-quarter 2014. FM O&G’s position in California is located onshore in the San Joaquin Valley and Los Angeles Basin, and offshore in the Point Arguello and Point Pedernales fields. During second-quarter 2015, production from Point Arguello platforms, which produced approximately 2 MBOE per day in first-quarter 2015, was temporarily shut in following the shutdown of a third-party operated pipeline system that transports oil to various California refineries.

Haynesville. FM O&G has rights to a substantial natural gas resource, located in the Haynesville shale play in North Louisiana. Drilling activities remain constrained in response to low natural gas prices in order to maximize near-term cash flows and to preserve the resource for potentially higher future natural gas prices.

International Exploration (Morocco). FM O&G has a farm-in arrangement to earn interests in exploration blocks located in the Mazagan permit area offshore Morocco. The exploration area covers 2.2 million gross acres in water depths of 4,500 to 9,900 feet. In May 2015, FM O&G commenced drilling the MZ-1 well associated with the Ouanoukrim prospect. In early August 2015, drilling of the well was completed to its targeted depth below 20,000 feet to evaluate the primary objectives, which did not contain hydrocarbons. As of June 30, 2015, capitalized costs for international oil and gas exploration activities in Morocco approximated $111 million and additional costs have

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been incurred subsequent to June 30, 2015, all of which will be transferred to the Moroccan full cost pool in third-quarter 2015. FM O&G currently has no proved reserves or production in Morocco.

CAPITAL RESOURCES AND LIQUIDITY

Our operating cash flows vary with prices realized from copper, gold, molybdenum and oil sales, our sales volumes, production costs, income taxes, other working capital changes and other factors. Since December 31, 2014, our debt has increased primarily reflecting the impact of lower commodity prices and capital expenditures for our oil and gas exploration and development projects and mining expansion projects. Capital expenditures are expected to decline in future years as major mining projects near completion. We remain committed to a strong balance sheet and have sold assets, deferred capital spending and reduced dividends on our common stock.

In July 2015, we announced that we are undertaking a comprehensive review of operating plans in our mining and oil and gas businesses to target significant additional reductions in capital spending and operating and administrative costs in response to weak market conditions for our major products. On August 5, 2015, we provided an update on our progress and announced the deferral of investments in several long-term projects in our oil and gas business, which will result in a reduction of $0.9 billion in projected capital expenditures for each of the years 2016 and 2017. The revised plans, together with the potential IPO of a minority interest in our wholly owned subsidiary, Freeport-McMoRan Oil & Gas Inc., and potential other actions, will be pursued as required to fund oil and gas capital spending with cash flow for 2016 and subsequent years. Refer to “Operations - Oil and Gas” for further discussion of the potential IPO.

We are completing the review of operating plans at each of our copper and molybdenum mining operations and will revise operating and capital plans to strengthen our financial position in a weak copper price environment. The revised plans will target lower operating and capital costs to achieve maximum cash flow under the current market conditions. Production at certain operations challenged by low commodity prices will be curtailed. We expect to complete this review promptly and will report our revised plans during third-quarter 2015. We will also continue to assess opportunities to partner with strategic investors potentially interested in investing capital with FCX in the development of our oil and gas and mining properties. We have a broad set of assets with valuable infrastructure and associated resources with attractive long-term production and development potential.

Cash

Following is a summary of the U.S. and international components of consolidated cash and cash equivalents, including cash available to the parent company, net of noncontrolling interests' share, taxes and other costs (in millions):

	June 30, 2015			December 31, 2014
Cash at domestic companies	$	29		$	78
Cash at international operations	437			386
Total consolidated cash and cash equivalents	466			464
Less: noncontrolling interests’ share	(119		)	(91		)
Cash, net of noncontrolling interests’ share	347			373
Less: withholding taxes and other	(19		)	(16		)
Net cash available	$	328		$	357

Cash held at our international operations is generally used to support our foreign operations' capital expenditures, operating expenses, working capital and other tax payments, or other cash needs. With the exception of TFM, we have not elected to permanently reinvest earnings from our foreign subsidiaries, and we have recorded deferred tax liabilities for foreign earnings that are available to be repatriated to the U.S. From time to time, our foreign subsidiaries distribute earnings to the U.S. through dividends that are subject to applicable withholding taxes and noncontrolling interests' share.

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Debt

Following is a summary of our total debt and the related weighted-average interest rates (in billions, except percentages):

	June 30, 2015				December 31, 2014
				Weighted-			Weighted-
				Average			Average
				Interest Rate			Interest Rate
FCX Senior Notes	$	11.9		3.8%	$	12.0	3.8	%
FCX Term Loan	3.0			1.9%	3.1		1.7	%
FM O&G Senior Notes	2.6			6.6%	2.6		6.6	%
Cerro Verde Term Loan	1.3		a	2.1%	0.4		2.1	%
Other FCX debt	2.1		b	2.7%	0.9		3.9	%
Total debt	$	20.9		3.6%	$	19.0	3.8	%

a. At June 30, 2015, Cerro Verde had $1.3 billion of borrowings outstanding and no letters of credit issued under its $1.8 billion senior unsecured credit facility to fund a portion of its expansion project (see "Operations - South America Mining") and for Cerro Verde's general corporate purposes.

b. At June 30, 2015, we had $985 million of borrowings outstanding and $42 million in letters of credit issued under our $4 billion revolving credit facility. We also have uncommitted and short-term lines of credit with certain financial institutions that are unsecured, which have terms and pricing that are generally more favorable than our revolving credit facility. At June 30, 2015, there was $410 million of borrowings drawn on these lines of credit.

As further discussed in Note 18 in our annual report on Form 10-K for the year ended December 31, 2014, in February 2015, our revolving credit facility and term loan were modified to amend the maximum total leverage ratio.

Our revolving credit facility and term loan contain financial ratio covenants governing maximum total leverage and minimum interest coverage, which limits our ability to incur additional debt. We are taking steps to enhance our financial position in response to recent declines in commodity prices. Further actions are being considered, such as additional equity capital or other transactions, including opportunities to partner with strategic investors potentially interested in investing capital in the development of our oil and gas and mining properties. We may also be required to seek an amendment to the covenants in our revolving credit facility and term loan.

For further discussion of our debt, refer to Note 6 in this report, and Note 8 in our annual report on Form 10-K for the year ended December 31, 2014.

Operating Activities

During the first six months of 2015, we generated consolidated operating cash flows totaling $1.8 billion (net of $190 million for working capital uses and changes in other tax payments), compared with consolidated operating cash flows for the first six months of 2014 of $2.6 billion (net of $777 million for working capital uses and changes in other tax payments). Lower consolidated operating cash flows for the first six months of 2015, compared with the first six months of 2014, primarily reflected the impact of lower commodity price realizations and lower oil volumes, partly offset by a decrease in working capital uses mostly associated with oil and gas derivative contracts and lower commodity prices.

Based on current operating plans and current commodity prices for copper, gold, molybdenum and crude oil, we expect estimated consolidated operating cash flows for the year 2015, plus available cash and availability under our credit facility and uncommitted lines of credit, to be sufficient to fund our budgeted capital expenditures, dividends, noncontrolling interest distributions and other cash requirements for the year. Refer to “Outlook” for further discussion of projected operating cash flows for the year 2015.

Investing Activities

Capital Expenditures. Capital expenditures, including capitalized interest, totaled $3.5 billion for the first six months of2015, including $1.2 billion for major projects at mining operations and $1.8 billion for oil and gas operations, compared with $3.6 billion for the first six months of2014, including $1.4 billion for major projects at mining operations and $1.5 billion for oil and gas operations. Lower capital expenditures for the first six months of2015 were primarily associated with decreased spending for the Morenci mill expansion, partly offset by increased capital expenditures at our oil and gas operations and increased capital expenditures for the Cerro Verde expansion. Refer to “Operations” for further discussion.

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Capital expenditures are currently expected to approximate $6.3 billion for the year 2015, including $2.5 billion for major projects at mining operations (primarily for the Cerro Verde expansion and underground development activities at Grasberg) and $2.8 billion for oil and gas operations, primarily at our highest potential return focus areas in the GOM. Projected 2015 capital expenditures for mining operations are subject to change as a result of the review of operating plans discussed above. We made substantial progress toward the completion of our major mining development projects, which are expected to result in increased near-term production, lower unit costs, declining capital expenditures and to contribute to cash flow from operations after capital expenditures in future years. In addition, positive oil and gas drilling and development activities are expected to result in a growing oil production profile.

Acquisitions and Dispositions. In June 2014, we acquired additional interests in the Deepwater GOM, for $0.9 billion, and also completed the sale of our Eagle Ford shale assets for $3.1 billion (before closing adjustments). The Deepwater GOM acquisition was funded with a portion of the net proceeds from the sale of Eagle Ford. The estimated combined after-tax net proceeds from these transactions approximated $1.8 billion, before purchase price adjustments. Refer to Note 2 for further discussion of our acquisition and disposal transactions.

Financing Activities

Debt Transactions. Net proceeds from debt for the first six months of 2015 primarily included net borrowings of $1.0 billion under our revolving credit facility and borrowings of $0.8 billion under Cerro Verde's senior unsecured credit facility to fund its expansion project.

On April 30, 2014, we redeemed $210 million of the aggregate principal amount of the outstanding 6.625% Senior Notes. Holders received the principal amount together with the redemption premium and accrued and unpaid interest to the redemption date. Refer to Note 6 for further discussion of debt transactions.

Dividends. We paid dividends on our common stock totaling $380 million for the first six months of 2015 and $653 million for the first six months of 2014. In response to the impact of lower commodity prices, in March 2015, the annual dividend rate for our common stock was reduced to $0.20 per share from the previous rate of $1.25 per share. On June 24, 2015, our Board of Directors (the Board) declared a regular quarterly dividend of $0.05 per share and a one-time special dividend of $0.1105 per share in accordance with the approved settlement terms of shareholder derivative litigation (refer to Note 9). Both the regular quarterly dividend and the special dividend were paid on August 3, 2015. The declaration of dividends is at the discretion of the Board and will depend upon our financial results, cash requirements, future prospects and other factors deemed relevant by the Board. Refer to Note 6 for further discussion.

Cash dividends and other distributions paid to noncontrolling interests totaled $60 million for the first six months of 2015 and $250 million for the first six months of 2014. These payments will vary based on the cash requirements of the related consolidated subsidiaries.

CONTRACTUAL OBLIGATIONS

As of June 30, 2015, we have current maturities of debt totaling $791 million, including $658 million for the second half of 2015 and $133 million for the first half of 2016, primarily reflecting bank lines of credit, which are extended to us on a uncommitted basis. As of June 30, 2015, debt maturities total $260 million for the year 2016 and $1.5 billion for the year 2017. With the exception of debt maturities and the related impact on scheduled interest payment obligations, there have been no material changes in our contractual obligations since December 31, 2014. Refer to Part II, Items 7. and 7A. in our annual report on Form 10-K for the year ended December 31, 2014, for further information regarding our contractual obligations.

CONTINGENCIES

Environmental and Asset Retirement Obligations

Our current and historical operating activities are subject to stringent laws and regulations governing the protection of the environment. We perform a comprehensive annual review of our environmental and asset retirement obligations and also review changes in facts and circumstances associated with these obligations at least quarterly. There have been no material changes to our environmental and asset retirement obligations since December 31, 2014. Updated cost assumptions, including increases and decreases to cost estimates, changes in the anticipated

65

scope and timing of remediation activities, and settlement of environmental matters may result in additional revisions to certain of our environmental obligations.

Refer to Note 12 in our annual report on Form 10-K for the year ended December 31, 2014, for further information regarding our environmental and asset retirement obligations.

Litigation and Other Contingencies

Other than as discussed in Note 9, and contained in "Legal Proceedings" in Part II, Item 1. of this quarterly report, there have been no material changes to our contingencies associated with legal proceedings and other matters since December 31, 2014. Refer to Note 12 and "Legal Proceedings" contained in Part I, Item 3. of our annual report on Form 10-K for the year ended December 31, 2014.

NEW ACCOUNTING STANDARDS

We do not expect the impact of recently issued accounting standards to have a significant impact on our future financial statements and disclosures. Refer to Note 12 for discussion of a recently adopted Accounting Standards Update.

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PRODUCT REVENUES AND PRODUCTION COSTS

Mining Product Revenues and Unit Net Cash Cost

Unit net cash costs per pound of copper and molybdenum are measures intended to provide investors with information about the cash-generating capacity of our mining operations expressed on a basis relating to the primary metal product for the respective operations. We use this measure for the same purpose and for monitoring operating performance by our mining operations. This information differs from measures of performance determined in accordance with U.S. generally accepted accounting principles (GAAP) and should not be considered in isolation or as a substitute for measures of performance determined in accordance with U.S. GAAP. This measure is presented by other metals mining companies, although our measures may not be comparable to similarly titled measures reported by other companies.

We present gross profit per pound of copper in the following tables using both a “by-product” method and a “co-product” method. We use the by-product method in our presentation of gross profit per pound of copper because (i) the majority of our revenues are copper revenues, (ii) we mine ore, which contains copper, gold, molybdenum and other metals, (iii) it is not possible to specifically assign all of our costs to revenues from the copper, gold, molybdenum and other metals we produce, (iv) it is the method used to compare mining operations in certain industry publications and (v) it is the method used by our management and the Board to monitor operations. In the co-product method presentations below, shared costs are allocated to the different products based on their relative revenue values, which will vary to the extent our metals sales volumes and realized prices change.

We show revenue adjustments for prior period open sales as a separate line item. Because these adjustments do not result from current period sales, we have reflected these separately from revenues on current period sales. Noncash and other costs consist of items such as stock-based compensation costs, start-up costs, LCM inventory adjustments, write-offs of equipment and/or unusual charges. They are removed from site production and delivery costs in the calculation of unit net cash costs. As discussed above, gold, molybdenum and other metal revenues at copper mines are reflected as credits against site production and delivery costs in the by-product method. The following schedules for our mining operations are presentations under both the by-product and co-product methods together with reconciliations to amounts reported in our consolidated financial statements.

Oil and Gas Product Revenues and Cash Production Costs per Unit

Realized revenues and cash production costs per unit are measures intended to provide investors with information about the cash operating margin of our oil and gas operations. We use this measure for the same purpose and for monitoring operating performance by our oil and gas operations. This information differs from measures of performance determined in accordance with U.S. GAAP and should not be considered in isolation or as a substitute for measures of performance determined in accordance with U.S. GAAP. Our measures may not be comparable to similarly titled measures reported by other companies.

We show revenue adjustments from derivative contracts as separate line items. Because these adjustments do not result from oil and gas sales, these gains and losses have been reflected separately from revenues on current period sales. Additionally, accretion charges for asset retirement obligations and other costs are removed from production and delivery costs in the calculation of cash production costs per BOE. The following schedules include calculations of oil and gas product revenues and cash production costs together with a reconciliation to amounts reported in our consolidated financial statements.

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North America Copper Mines Product Revenues, Production Costs and Unit Net Cash Costs

Three Months Ended June 30, 2015
(In millions)	By-Product				Co-Product Method
	Method				Copper				Molybdenuma			Otherb		Total
Revenues, excluding adjustments	$	1,341			$	1,341			$	80		$	28	$	1,449
Site production and delivery, before net noncash     and other costs shown below	862				804				64			22		890
By-product credits	(80		)		—				—			—		—
Treatment charges	60				58				—			2		60
Net cash costs	842				862				64			24		950
Depreciation, depletion and amortization	137				129				5			3		137
Noncash and other costs, net	46			c	45				1			—		46
Total costs	1,025				1,036				70			27		1,133
Revenue adjustments, primarily for pricing     on prior period open sales	(13		)		(13		)		—			—		(13		)
Gross profit	$	303			$	292			$	10		$	1	$	303
Copper sales (millions of recoverable pounds)	485				485
Molybdenum sales (millions of recoverable pounds)a									10
Gross profit per pound of copper/molybdenum:
Revenues, excluding adjustments	$	2.77			$	2.77			$	7.80
Site production and delivery, before net noncash     and other costs shown below	1.78				1.66				6.24
By-product credits	(0.16		)		—				—
Treatment charges	0.12				0.12				—
Unit net cash costs	1.74				1.78				6.24
Depreciation, depletion and amortization	0.28				0.27				0.53
Noncash and other costs, net	0.10			c	0.09				0.06
Total unit costs	2.12				2.14				6.83
Revenue adjustments, primarily for pricing
on prior period open sales	(0.03		)		(0.03		)		—
Gross profit per pound	$	0.62			$	0.60			$	0.97
Reconciliation to Amounts Reported
(In millions)	Revenues				Production and Delivery				Depreciation, Depletion and Amortization
Totals presented above	$	1,449			$	890			$	137
Treatment charges	—				60			c	—
Noncash and other costs, net	—				46				—
Revenue adjustments, primarily for pricing     on prior period open sales	(13		)		—				—
Eliminations and other	(31		)		(34		)		2
North America copper mines	1,405				962				139
Other mining & eliminationsd	2,274				1,603				263
Total mining	3,679				2,565				402
U.S. oil & gas operations	569				281				3,171		e
Corporate, other & eliminations	—				2				3
As reported in FCX’s consolidated financial statements	$	4,248			$	2,848			$	3,576	e

a. Reflects sales of molybdenum produced by certain of the North America copper mines to our molybdenum sales company at market-based pricing.

b. Includes gold and silver product revenues and production costs.

c. Includes charges totaling $11 million ($0.02 per pound) for LCM inventory adjustments.

d. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

e. Includes impairment of oil and gas properties of $2.7 billion.

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North America Copper Mines Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Three Months Ended June 30, 2014
(In millions)	By-Product			Co-Product Method
	Method			Copper			Molybdenuma		Otherb		Total
Revenues, excluding adjustments	$	1,332		$	1,332		$	112	$	30	$	1,474
Site production and delivery, before net noncash     and other costs shown below	786			733			60		19		812
By-product credits	(116		)	—			—		—		—
Treatment charges	46			45			—		1		46
Net cash costs	716			778			60		20		858
Depreciation, depletion and amortization	125			117			6		2		125
Noncash and other costs, net	29			29			—		—		29
Total costs	870			924			66		22		1,012
Revenue adjustments, primarily for pricing     on prior period open sales	9			9			—		—		9
Gross profit	$	471		$	417		$	46	$	8	$	471
Copper sales (millions of recoverable pounds)	421			421
Molybdenum sales (millions of recoverable pounds)a							9
Gross profit per pound of copper/molybdenum:
Revenues, excluding adjustments	$	3.16		$	3.16		$	12.49
Site production and delivery, before net noncash      and other costs shown below	1.87			1.74			6.73
By-product credits	(0.28		)	—			—
Treatment charges	0.11			0.11			—
Unit net cash costs	1.70			1.85			6.73
Depreciation, depletion and amortization	0.30			0.28			0.64
Noncash and other costs, net	0.07			0.06			0.05
Total unit costs	2.07			2.19			7.42
Revenue adjustments, primarily for pricing
on prior period open sales	0.02			0.02			—
Gross profit per pound	$	1.11		$	0.99		$	5.07
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	1,474		$	812		$	125
Treatment charges	—			46			—
Noncash and other costs, net	—			29			—
Revenue adjustments, primarily for pricing     on prior period open sales	9			—			—
Eliminations and other	(14		)	(17		)	3
North America copper mines	1,469			870			128
Other mining & eliminationsc	2,817			1,884			266
Total mining	4,286			2,754			394
U.S. oil & gas operations	1,236			329			616
Corporate, other & eliminations	—			(1		)	3
As reported in FCX’s consolidated financial statements	$	5,522		$	3,082		$	1,013

a. Reflects sales of molybdenum produced by certain of the North America copper mines to our molybdenum sales company at market-based pricing.

b. Includes gold and silver product revenues and production costs.

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

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North America Copper Mines Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Six Months Ended June 30, 2015
(In millions)	By-Product				Co-Product Method
	Method				Copper				Molybdenuma			Otherb		Total
Revenues, excluding adjustments	$	2,612			$	2,612			$	162		$	54	$	2,828
Site production and delivery, before net noncash     and other costs shown below	1,715				1,605				122			41		1,768
By-product credits	(163		)		—				—			—		—
Treatment charges	121				118				—			3		121
Net cash costs	1,673				1,723				122			44		1,889
Depreciation, depletion and amortization	270				254				11			5		270
Noncash and other costs, net	77			c	76				1			—		77
Total costs	2,020				2,053				134			49		2,236
Revenue adjustments, primarily for pricing     on prior period open sales	(28		)		(28		)		—			—		(28		)
Gross profit	$	564			$	531			$	28		$	5	$	564
Copper sales (millions of recoverable pounds)	956				956
Molybdenum sales (millions of recoverable pounds)a									19
Gross profit per pound of copper/molybdenum:
Revenues, excluding adjustments	$	2.73			$	2.73			$	8.28
Site production and delivery, before net noncash
and other costs shown below	1.79				1.68				6.24
By-product credits	(0.17		)		—				—
Treatment charges	0.13				0.12				—
Unit net cash costs	1.75				1.80				6.24
Depreciation, depletion and amortization	0.28				0.27				0.58
Noncash and other costs, net	0.08			c	0.08				0.06
Total unit costs	2.11				2.15				6.88
Revenue adjustments, primarily for pricing
on prior period open sales	(0.03		)		(0.03		)		—
Gross profit per pound	$	0.59			$	0.55			$	1.40
Reconciliation to Amounts Reported
(In millions)	Revenues				Production and Delivery				Depreciation, Depletion and Amortization
Totals presented above	$	2,828			$	1,768			$	270
Treatment charges	—				121				—
Noncash and other costs, net	—				77			c	—
Revenue adjustments, primarily for pricing     on prior period open sales	(28		)		—				—
Eliminations and other	(60		)		(61		)		2
North America copper mines	2,740				1,905				272
Other mining & eliminationsd	4,592				3,286				535
Total mining	7,332				5,191				807
U.S. oil & gas operations	1,069				564				6,805		e
Corporate, other & eliminations	—				5				7
As reported in FCX’s consolidated financial statements	$	8,401			$	5,760			$	7,619	e

a. Reflects sales of molybdenum produced by certain of the North America copper mines to our molybdenum sales company at market-based pricing.

b. Includes gold and silver product revenues and production costs.

c. Includes charges totaling $11 million ($0.01 per pound) for LCM inventory adjustments.

d. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

e. Includes impairment of oil and gas properties of $5.8 billion.

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North America Copper Mines Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Six Months Ended June 30, 2014
(In millions)	By-Product			Co-Product Method
	Method			Copper			Molybdenuma		Otherb		Total
Revenues, excluding adjustments	$	2,535		$	2,535		$	194	$	59	$	2,788
Site production and delivery, before net noncash     and other costs shown below	1,481			1,388			110		38		1,536
By-product credits	(198		)	—			—		—		—
Treatment charges	93			91			—		2		93
Net cash costs	1,376			1,479			110		40		1,629
Depreciation, depletion and amortization	229			217			10		2		229
Noncash and other costs, net	59			58			—		1		59
Total costs	1,664			1,754			120		43		1,917
Revenue adjustments, primarily for pricing     on prior period open sales	(7		)	(7		)	—		—		(7		)
Gross profit	$	864		$	774		$	74	$	16	$	864
Copper sales (millions of recoverable pounds)	790			790
Molybdenum sales (millions of recoverable pounds)a							17
Gross profit per pound of copper/molybdenum:
Revenues, excluding adjustments	$	3.21		$	3.21		$	11.39
Site production and delivery, before net noncash
and other costs shown below	1.87			1.76			6.45
By-product credits	(0.25		)	—			—
Treatment charges	0.12			0.12			—
Unit net cash costs	1.74			1.88			6.45
Depreciation, depletion and amortization	0.29			0.27			0.58
Noncash and other costs, net	0.08			0.07			0.04
Total unit costs	2.11			2.22			7.07
Revenue adjustments, primarily for pricing
on prior period open sales	(0.01		)	(0.01		)	—
Gross profit per pound	$	1.09		$	0.98		$	4.32
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	2,788		$	1,536		$	229
Treatment charges	—			93			—
Noncash and other costs, net	—			59			—
Revenue adjustments, primarily for pricing     on prior period open sales	(7		)	—			—
Eliminations and other	(26		)	(32		)	6
North America copper mines	2,755			1,656			235
Other mining & eliminationsc	5,255			3,524			505
Total mining	8,010			5,180			740
U.S. oil & gas operations	2,497			640			1,232
Corporate, other & eliminations	—			(1		)	7
As reported in FCX’s consolidated financial statements	$	10,507		$	5,819		$	1,979

a. Reflects sales of molybdenum produced by certain of the North America copper mines to our molybdenum sales company at market-based pricing.

b. Includes gold and silver product revenues and production costs.

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

71

South America Mining Product Revenues, Production Costs and Unit Net Cash Costs

Three Months Ended June 30, 2015
(In millions)	By-Product			Co-Product Method
	Method			Copper			Othera				Total
Revenues, excluding adjustments	$	479		$	479		$	14			$	493
Site production and delivery, before net noncash     and other costs shown below	314			305			15				320
By-product credits	(8		)	—			—				—
Treatment charges	30			30			—				30
Royalty on metals	1			1			—				1
Net cash costs	337			336			15				351
Depreciation, depletion and amortization	72			70			2				72
Noncash and other (credits) costs, net	(4		)	(5		)	1				(4		)
Total costs	405			401			18				419
Revenue adjustments, primarily for pricing     on prior period open sales	(8		)	(8		)	—				(8		)
Gross profit (loss)	$	66		$	70		$	(4	)		$	66
Copper sales (millions of recoverable pounds)	178			178
Gross profit per pound of copper:
Revenues, excluding adjustments	$	2.69		$	2.69
Site production and delivery, before net noncash     and other costs shown below	1.77			1.72
By-product credits	(0.04		)	—
Treatment charges	0.17			0.17
Royalty on metals	—			—
Unit net cash costs	1.90			1.89
Depreciation, depletion and amortization	0.40			0.39
Noncash and other (credits) costs, net	(0.02		)	(0.03		)
Total unit costs	2.28			2.25
Revenue adjustments, primarily for pricing
on prior period open sales	(0.05		)	(0.05		)
Gross profit per pound	$	0.36		$	0.39
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	493		$	320		$	72
Treatment charges	(30		)	—			—
Royalty on metals	(1		)	—			—
Noncash and other (credits) costs, net	—			(4		)	—
Revenue adjustments, primarily for pricing     on prior period open sales	(8		)	—			—
Eliminations and other	(1		)	(1		)	—
South America mining	453			315			72
Other mining & eliminationsb	3,226			2,250			330
Total mining	3,679			2,565			402
U.S. oil & gas operations	569			281			3,171			c
Corporate, other & eliminations	—			2			3
As reported in FCX’s consolidated financial statements	$	4,248		$	2,848		$	3,576		c

a. Includes silver sales of 373 thousand ounces ($15.15 per ounce average realized price). Also reflects sales of molybdenum produced by Cerro Verde to our molybdenum sales company at market-based pricing.

b. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

c. Includes impairment of oil and gas properties of $2.7 billion.

72

South America Mining Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Three Months Ended June 30, 2014
(In millions)	By-Product				Co-Product Method
	Method				Copper			Othera		Total
Revenues, excluding adjustments	$	984			$	984		$	75	$	1,059
Site production and delivery, before net noncash     and other costs shown below	511				474			41		515
By-product credits	(71		)		—			—		—
Treatment charges	55				55			—		55
Royalty on metals	3				3			—		3
Net cash costs	498			b	532			41		573
Depreciation, depletion and amortization	95				90			5		95
Noncash and other costs, net	23				19			4		23
Total costs	616				641			50		691
Revenue adjustments, primarily for pricing     on prior period open sales	32				32			—		32
Gross profit	$	400			$	375		$	25	$	400
Copper sales (millions of recoverable pounds)	310			b	310
Gross profit per pound of copper:
Revenues, excluding adjustments	$	3.17			$	3.17
Site production and delivery, before net noncash    and other costs shown below	1.64				1.52
By-product credits	(0.23		)		—
Treatment charges	0.18				0.18
Royalty on metals	0.01				0.01
Unit net cash costs	1.60			b	1.71
Depreciation, depletion and amortization	0.30				0.29
Noncash and other costs, net	0.08				0.06
Total unit costs	1.98				2.06
Revenue adjustments, primarily for pricing
on prior period open sales	0.10				0.10
Gross profit per pound	$	1.29			$	1.21
Reconciliation to Amounts Reported
(In millions)	Revenues				Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	1,059			$	515		$	95
Treatment charges	(55		)		—			—
Royalty on metals	(3		)		—			—
Noncash and other costs, net	—				23			—
Revenue adjustments, primarily for pricing     on prior period open sales	32				—			—
Eliminations and other	(2		)		(8		)	—
South America mining	1,031				530			95
Other mining & eliminationsc	3,255				2,224			299
Total mining	4,286				2,754			394
U.S. oil & gas operations	1,236				329			616
Corporate, other & eliminations	—				(1		)	3
As reported in FCX’s consolidated financial statements	$	5,522			$	3,082		$	1,013

a. Includes gold sales of 20 thousand ounces ($1,302 per ounce average realized price) and silver sales of 748 thousand ounces ($18.83 per ounce average realized price). Also reflects sales of molybdenum produced by Cerro Verde to our molybdenum sales company at market-based pricing.

b.Following is a reconciliation of South America mining's second-quarter 2014 unit net cash costs, excluding the Candelaria and Ojos del Salado mines:

	Net Cash Costs (in millions)		Copper Sales (millions of recoverable pounds)	Unit Net Cash Costs (per pound of copper)
Presented above	$	498	310	$	1.60
Less: Candelaria and Ojos del Salado	140		80
	$	358	230	$	1.55

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

73

South America Mining Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Six Months Ended June 30, 2015
(In millions)	By-Product			Co-Product Method
	Method			Copper			Othera				Total
Revenues, excluding adjustments	$	1,013		$	1,013		$	35			$	1,048
Site production and delivery, before net noncash     and other costs shown below	664			642			33				675
By-product credits	(24		)	—			—				—
Treatment charges	64			64			—				64
Royalty on metals	1			1			—				1
Net cash costs	705			707			33				740
Depreciation, depletion and amortization	147			143			4				147
Noncash and other costs, net	—			—			—				—
Total costs	852			850			37				887
Revenue adjustments, primarily for pricing     on prior period open sales	(31		)	(31		)	—				(31		)
Gross profit (loss)	$	130		$	132		$	(2	)		$	130
Copper sales (millions of recoverable pounds)	378			378
Gross profit per pound of copper:
Revenues, excluding adjustments	$	2.68		$	2.68
Site production and delivery, before net noncash
and other costs shown below	1.76			1.70
By-product credits	(0.06		)	—
Treatment charges	0.17			0.17
Royalty on metals	—			—
Unit net cash costs	1.87			1.87
Depreciation, depletion and amortization	0.39			0.38
Noncash and other costs, net	—			—
Total unit costs	2.26			2.25
Revenue adjustments, primarily for pricing
on prior period open sales	(0.08		)	(0.08		)
Gross profit per pound	$	0.34		$	0.35
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	1,048		$	675		$	147
Treatment charges	(64		)	—			—
Royalty on metals	(1		)	—			—
Noncash and other costs, net	—			—			—
Revenue adjustments, primarily for pricing     on prior period open sales	(31		)	—			—
Eliminations and other	(13		)	(15		)	—
South America mining	939			660			147
Other mining & eliminationsb	6,393			4,531			660
Total mining	7,332			5,191			807
U.S. oil & gas operations	1,069			564			6,805			c
Corporate, other & eliminations	—			5			7
As reported in FCX’s consolidated financial statements	$	8,401		$	5,760		$	7,619		c

a. Includes silver sales of 759 thousand ounces ($14.97 per ounce average realized price). Also reflects sales of molybdenum produced by Cerro Verde to our molybdenum sales company at market-based pricing.

b. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

c. Includes impairment of oil and gas properties of $5.8 billion.

74

South America Mining Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Six Months Ended June 30, 2014
(In millions)	By-Product				Co-Product Method
	Method				Copper			Othera		Total
Revenues, excluding adjustments	$	1,951			$	1,951		$	159	$	2,110
Site production and delivery, before net noncash     and other costs shown below	972				900			81		981
By-product credits	(150		)		—			—		—
Treatment charges	108				108			—		108
Royalty on metals	3				3			—		3
Net cash costs	933			b	1,011			81		1,092
Depreciation, depletion and amortization	182				170			12		182
Noncash and other costs, net	40				38			2		40
Total costs	1,155				1,219			95		1,314
Revenue adjustments, primarily for pricing     on prior period open sales	(67		)		(67		)	—		(67		)
Gross profit	$	729			$	665		$	64	$	729
Copper sales (millions of recoverable pounds)	617			b	617
Gross profit per pound of copper:
Revenues, excluding adjustments	$	3.16			$	3.16
Site production and delivery, before net noncash
and other costs shown below	1.57				1.46
By-product credits	(0.24		)		—
Treatment charges	0.18				0.18
Royalty on metals	—				—
Unit net cash costs	1.51			b	1.64
Depreciation, depletion and amortization	0.29				0.27
Noncash and other costs, net	0.07				0.06
Total unit costs	1.87				1.97
Revenue adjustments, primarily for pricing
on prior period open sales	(0.11		)		(0.11		)
Gross profit per pound	$	1.18			$	1.08
Reconciliation to Amounts Reported
(In millions)	Revenues				Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	2,110			$	981		$	182
Treatment charges	(108		)		—			—
Royalty on metals	(3		)		—			—
Noncash and other costs, net	—				40			—
Revenue adjustments, primarily for pricing     on prior period open sales	(67		)		—			—
Eliminations and other	(3		)		(15		)	—
South America mining	1,929				1,006			182
Other mining & eliminationsc	6,081				4,174			558
Total mining	8,010				5,180			740
U.S. oil & gas operations	2,497				640			1,232
Corporate, other & eliminations	—				(1		)	7
As reported in FCX’s consolidated financial statements	$	10,507			$	5,819		$	1,979

a. Includes gold sales of 43 thousand ounces ($1,302 per ounce average realized price) and silver sales of 1.5 million ounces ($19.34 per ounce average realized price). Also reflects sales of molybdenum produced by Cerro Verde to our molybdenum sales company at market-based pricing.

b. Following is a reconciliation of South America mining's unit net cash costs for the first six months of 2014, excluding the Candelaria and Ojos del Salado mines:

	Net Cash Costs (in millions)		Copper Sales (millions of recoverable pounds)	Unit Net Cash Costs (per pound of copper)
Presented above	$	933	617	$	1.51
Less: Candelaria and Ojos del Salado	263		174
	$	670	443	$	1.51

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

75

Indonesia Mining Product Revenues, Production Costs and Unit Net Cash Costs

Three Months Ended June 30, 2015
(In millions)	By-Product			Co-Product Method
	Method			Copper			Gold				Silvera		Total
Revenues, excluding adjustments	$	511		$	511		$	406			$	8	$	925
Site production and delivery, before net noncash      and other costs shown below	442			244			194				4		442
Gold and silver credits	(416		)	—			—				—		—
Treatment charges	62			34			27				1		62
Export duties	36			20			16				—		36
Royalty on metals	35			19			16				—		35
Net cash costs	159			317			253				5		575
Depreciation and amortization	78			43			34				1		78
Noncash and other costs, net	8			5			3				—		8
Total costs	245			365			290				6		661
Revenue adjustments, primarily for pricing     on prior period open sales	(4		)	(4		)	2				—		(2		)
PT Smelting intercompany loss	(5		)	(3		)	(2		)		—		(5		)
Gross profit	$	257		$	139		$	116			$	2	$	257
Copper sales (millions of recoverable pounds)	196			196
Gold sales (thousands of recoverable ounces)							346
Gross profit per pound of copper/per ounce of gold:
Revenues, excluding adjustments	$	2.61		$	2.61		$	1,173
Site production and delivery, before net noncash      and other costs shown below	2.26			1.25			560
Gold and silver credits	(2.13		)	—			—
Treatment charges	0.32			0.18			79
Export duties	0.18			0.10			45
Royalty on metals	0.18			0.10			45
Unit net cash costs	0.81			1.63			729
Depreciation and amortization	0.40			0.22			100
Noncash and other costs, net	0.04			0.02			10
Total unit costs	1.25			1.87			839
Revenue adjustments, primarily for pricing
on prior period open sales	(0.02		)	(0.02		)	7
PT Smelting intercompany loss	(0.02		)	(0.01		)	(5		)
Gross profit per pound/ounce	$	1.32		$	0.71		$	336
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	925		$	442		$	78
Treatment charges	(62		)	—			—
Export duties	(36		)	—			—
Royalty on metals	(35		)	—			—
Noncash and other costs, net	—			8			—
Revenue adjustments, primarily for pricing     on prior period open sales	(2		)	—			—
PT Smelting intercompany loss	—			5			—
Indonesia mining	790			455			78
Other mining & eliminationsb	2,889			2,110			324
Total mining	3,679			2,565			402
U.S. oil & gas operations	569			281			3,171			c
Corporate, other & eliminations	—			2			3
As reported in FCX’s consolidated financial statements	$	4,248		$	2,848		$	3,576		c

a. Includes silver sales of 558 thousand ounces ($15.48 per ounce average realized price).

b. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

c. Includes impairment of oil and gas properties of $2.7 billion.

76

Indonesia Mining Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Three Months Ended June 30, 2014
(In millions)	By-Product				Co-Product Method
	Method				Copper				Gold			Silvera			Total
Revenues, excluding adjustments	$	372			$	372			$	176		$	7		$	555
Site production and delivery, before net noncash     and other costs shown below	451				303				142			6			451
Gold and silver credits	(184		)		—				—			—			—
Treatment charges	30				20				10			—			30
Royalty on metals	14				9				5			—			14
Net cash costs	311				332				157			6			495
Depreciation and amortization	54				36				17			1			54
Noncash and other costs, net	64			b	43				20			1			64
Total costs	429				411				194			8			613
Revenue adjustments, primarily for pricing     on prior period open sales	11				11				1			—			12
PT Smelting intercompany profit	4				3				1			—			4
Gross loss	$	(42	)		$	(25	)		$	(16	)	$	(1	)	$	(42	)
Copper sales (millions of recoverable pounds)	117				117
Gold sales (thousands of recoverable ounces)									135
Gross profit per pound of copper/per ounce of gold:
Revenues, excluding adjustments	$	3.19			$	3.19			$	1,294
Site production and delivery, before net noncash     and other costs shown below	3.86				2.59				1,050
Gold and silver credits	(1.57		)		—				—
Treatment charges	0.26				0.17				70
Royalty on metals	0.11				0.08				31
Unit net cash costs	2.66				2.84				1,151
Depreciation and amortization	0.47				0.31				127
Noncash and other costs, net	0.55			b	0.37				151
Total unit costs	3.68				3.52				1,429
Revenue adjustments, primarily for pricing
on prior period open sales	0.09				0.09				5
PT Smelting intercompany profit	0.03				0.02				9
Gross loss per pound/ounce	$	(0.37	)		$	(0.22	)		$	(121	)
Reconciliation to Amounts Reported
(In millions)	Revenues				Production and Delivery				Depreciation, Depletion and Amortization
Totals presented above	$	555			$	451			$	54
Treatment charges	(30		)		—				—
Royalty on metals	(14		)		—				—
Noncash and other costs, net	—				64			b	—
Revenue adjustments, primarily for pricing     on prior period open sales	12				—				—
PT Smelting intercompany profit	—				(4		)		—
Indonesia mining	523				511				54
Other mining & eliminationsc	3,763				2,243				340
Total mining	4,286				2,754				394
U.S. oil & gas operations	1,236				329				616
Corporate, other & eliminations	—				(1		)		3
As reported in FCX’s consolidated financial statements	$	5,522			$	3,082			$	1,013

a. Includes silver sales of 367 thousand ounces ($19.67 per ounce average realized price).

b. Includes $56 million ($0.48 per pound) of fixed costs charged directly to cost of sales as a result of the impact of export restrictions on PT-FI's operating rates.

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

77

Indonesia Mining Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Six Months Ended June 30, 2015
(In millions)	By-Product			Co-Product Method
	Method			Copper			Gold			Silvera			Total
Revenues, excluding adjustments	$	933		$	933		$	716		$	16	a	$	1,665
Site production and delivery, before net noncash    and other costs shown below	882			494			380			8			882
Gold and silver credits	(741		)	—			—			—			—
Treatment charges	108			61			46			1			108
Export duties	57			32			24			1			57
Royalty on metals	60			33			26			1			60
Net cash costs	366			620			476			11			1,107
Depreciation and amortization	148			83			64			1			148
Noncash and other costs, net	14			8			6			—			14
Total costs	528			711			546			12			1,269
Revenue adjustments, primarily for pricing     on prior period open sales	(52		)	(52		)	9			—			(43		)
PT Smelting intercompany profit	2			2			—			—			2
Gross profit	$	355		$	172		$	179		$	4		$	355
Copper sales (millions of recoverable pounds)	351			351
Gold sales (thousands of recoverable ounces)							606
Gross profit per pound of copper/per ounce of gold:
Revenues, excluding adjustments	$	2.66		$	2.66		$	1,183
Site production and delivery, before net noncash
and other costs shown below	2.51			1.41			626
Gold and silver credits	(2.11		)	—			—
Treatment charges	0.31			0.17			77
Export duties	0.16			0.09			41
Royalty on metals	0.17			0.10			42
Unit net cash costs	1.04			1.77			786
Depreciation and amortization	0.42			0.24			106
Noncash and other costs, net	0.04			0.02			10
Total unit costs	1.50			2.03			902
Revenue adjustments, primarily for pricing
on prior period open sales	(0.15		)	(0.15		)	14
PT Smelting intercompany profit	0.01			0.01			2
Gross profit per pound/ounce	$	1.02		$	0.49		$	297
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	1,665		$	882		$	148
Treatment charges	(108		)	—			—
Export duties	(57		)	—			—
Royalty on metals	(60		)	—			—
Noncash and other costs, net	—			14			—
Revenue adjustments, primarily for pricing     on prior period open sales	(43		)	—			—
PT Smelting intercompany profit	—			(2		)	—
Indonesia mining	1,397			894			148
Other mining & eliminationsb	5,935			4,297			659
Total mining	7,332			5,191			807
U.S. oil & gas operations	1,069			564			6,805		c
Corporate, other & eliminations	—			5			7
As reported in FCX’s consolidated financial statements	$	8,401		$	5,760		$	7,619	c

a. Includes silver sales of 993 thousand ounces ($15.75 per ounce average realized price).

b. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

c. Includes impairment of oil and gas properties of $5.8 billion.

78

Indonesia Mining Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Six Months Ended June 30, 2014
(In millions)	By-Product				Co-Product Method
	Method				Copper				Gold		Silvera		Total
Revenues, excluding adjustments	$	713			$	713			$	386	$	14	$	1,113
Site production and delivery, before net noncash     and other costs shown below	814				521				283		10		814
Gold and silver credits	(419		)		—				—		—		—
Treatment charges	56				36				19		1		56
Royalty on metals	27				17				9		1		27
Net cash costs	478				574				311		12		897
Depreciation and amortization	102				65				36		1		102
Noncash and other costs, net	138			b	88				48		2		138
Total costs	718				727				395		15		1,137
Revenue adjustments, primarily for pricing     on prior period open sales	(56		)		(56		)		18		1		(37		)
PT Smelting intercompany profit	58				37				20		1		58
Gross (loss) profit	$	(3	)		$	(33	)		$	29	$	1	$	(3	)
Copper sales (millions of recoverable pounds)	226				226
Gold sales (thousands of recoverable ounces)									297
Gross profit per pound of copper/per ounce of gold:
Revenues, excluding adjustments	$	3.15			$	3.15			$	1,299
Site production and delivery, before net noncash
and other costs shown below	3.60				2.31				950
Gold and silver credits	(1.85		)		—				—
Treatment charges	0.25				0.16				65
Royalty on metals	0.12				0.07				31
Unit net cash costs	2.12				2.54				1,046
Depreciation and amortization	0.45				0.29				120
Noncash and other costs, net	0.61			b	0.39				161
Total unit costs	3.18				3.22				1,327
Revenue adjustments, primarily for pricing
on prior period open sales	(0.24		)		(0.24		)		59
PT Smelting intercompany profit	0.26				0.16				68
Gross (loss) profit per pound/ounce	$	(0.01	)		$	(0.15	)		$	99
Reconciliation to Amounts Reported
(In millions)	Revenues				Production and Delivery				Depreciation, Depletion and Amortization
Totals presented above	$	1,113			$	814			$	102
Treatment charges	(56		)		—				—
Royalty on metals	(27		)		—				—
Noncash and other costs, net	—				138			b	—
Revenue adjustments, primarily for pricing     on prior period open sales	(37		)		—				—
PT Smelting intercompany profit	—				(58		)		—
Indonesia mining	993				894				102
Other mining & eliminationsc	7,017				4,286				638
Total mining	8,010				5,180				740
U.S. oil & gas operations	2,497				640				1,232
Corporate, other & eliminations	—				(1		)		7
As reported in FCX’s consolidated financial statements	$	10,507			$	5,819			$	1,979

a. Includes silver sales of 700 thousand ounces ($19.84 per ounce average realized price).

b. Includes $109 million ($0.48 per pound) of fixed costs charged directly to cost of sales as a result of the impact of export restrictions on PT-FI's operating rates.

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

79

Africa Mining Product Revenues, Production Costs and Unit Net Cash Costs

Three Months Ended June 30, 2015
(In millions)	By-Product			Co-Product Method
	Method			Copper		Cobalt			Total
Revenues, excluding adjustmentsa	$	275		$	275	$	76		$	351
Site production and delivery, before net noncash     and other costs shown below	161			141		45			186
Cobalt creditsb	(55		)	—		—			—
Royalty on metals	6			5		1			6
Net cash costs	112			146		46			192
Depreciation, depletion and amortization	57			45		12			57
Noncash and other costs, net	4			3		1			4
Total costs	173			194		59			253
Revenue adjustments, primarily for pricing     on prior period open sales	2			2		4			6
Gross profit	$	104		$	83	$	21		$	104
Copper sales (millions of recoverable pounds)	104			104
Cobalt sales (millions of contained pounds)						8
Gross profit per pound of copper/cobalt:
Revenues, excluding adjustmentsa	$	2.63		$	2.63	$	9.27
Site production and delivery, before net noncash      and other costs shown below	1.54			1.35		5.48
Cobalt creditsb	(0.53		)	—		—
Royalty on metals	0.06			0.05		0.16
Unit net cash costs	1.07			1.40		5.64
Depreciation, depletion and amortization	0.55			0.43		1.42
Noncash and other costs, net	0.03			0.03		0.10
Total unit costs	1.65			1.86		7.16
Revenue adjustments, primarily for pricing
on prior period open sales	0.02			0.02		0.50
Gross profit per pound	$	1.00		$	0.79	$	2.61
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery		Depreciation, Depletion and Amortization
Totals presented above	$	351		$	186	$	57
Royalty on metals	(6		)	—		—
Noncash and other costs, net	—			4		—
Revenue adjustments, primarily for pricing     on prior period open sales	6			—		—
Africa mining	351			190		57
Other mining & eliminationsc	3,328			2,375		345
Total mining	3,679			2,565		402
U.S. oil & gas operations	569			281		3,171		d
Corporate, other & eliminations	—			2		3
As reported in FCX’s consolidated financial statements	$	4,248		$	2,848	$	3,576	d

a. Includes point-of-sale transportation costs as negotiated in customer contracts. 

b. Net of cobalt downstream processing and freight costs.

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

d. Includes impairment of oil and gas properties of $2.7 billion.

80

Africa Mining Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Three Months Ended June 30, 2014
(In millions)	By-Product			Co-Product Method
	Method			Copper			Cobalt			Total
Revenues, excluding adjustmentsa	$	362		$	362		$	65		$	427
Site production and delivery, before net noncash     and other costs shown below	171			159			35			194
Cobalt creditsb	(41		)	—			—			—
Royalty on metals	8			7			1			8
Net cash costs	138			166			36			202
Depreciation, depletion and amortization	63			54			9			63
Noncash and other costs, net	4			3			1			4
Total costs	205			223			46			269
Revenue adjustments, primarily for pricing     on prior period open sales	—			—			(1		)	(1		)
Gross profit	$	157		$	139		$	18		$	157
Copper sales (millions of recoverable pounds)	118			118
Cobalt sales (millions of contained pounds)							7
Gross profit per pound of copper/cobalt:
Revenues, excluding adjustmentsa	$	3.08		$	3.08		$	9.58
Site production and delivery, before net noncash      and other costs shown below	1.46			1.35			5.22
Cobalt creditsb	(0.34		)	—			—
Royalty on metals	0.06			0.06			0.15
Unit net cash costs	1.18			1.41			5.37
Depreciation, depletion and amortization	0.54			0.46			1.30
Noncash and other costs, net	0.03			0.03			0.08
Total unit costs	1.75			1.90			6.75
Revenue adjustments, primarily for pricing
on prior period open sales	—			—			(0.19		)
Gross profit per pound	$	1.33		$	1.18		$	2.64
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	427		$	194		$	63
Royalty on metals	(8		)	—			—
Noncash and other costs, net	—			4			—
Revenue adjustments, primarily for pricing     on prior period open sales	(1		)	—			—
Africa mining	418			198			63
Other mining & eliminationsc	3,868			2,556			331
Total mining	4,286			2,754			394
U.S. oil & gas operations	1,236			329			616
Corporate, other & eliminations	—			(1		)	3
As reported in FCX’s consolidated financial statements	$	5,522		$	3,082		$	1,013

a. Includes point-of-sale transportation costs as negotiated in customer contracts. 

b. Net of cobalt downstream processing and freight costs.

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

81

Africa Mining Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Six Months Ended June 30, 2015
(In millions)	By-Product			Co-Product Method
	Method			Copper			Cobalt				Total
Revenues, excluding adjustmentsa	$	631		$	631		$	152			$	783
Site production and delivery, before net noncash     and other costs shown below	370			325			92				417
Cobalt creditsb	(104		)	—			—				—
Royalty on metals	14			12			2				14
Net cash costs	280			337			94				431
Depreciation, depletion and amortization	130			109			21				130
Noncash and other costs, net	8			6			2				8
Total costs	418			452			117				569
Revenue adjustments, primarily for pricing     on prior period open sales	(7		)	(7		)	(1		)		(8		)
Gross profit	$	206		$	172		$	34			$	206
Copper sales (millions of recoverable pounds)	237			237
Cobalt sales (millions of contained pounds)							16
Gross profit per pound of copper/cobalt:
Revenues, excluding adjustmentsa	$	2.66		$	2.66		$	9.23
Site production and delivery, before net noncash
and other costs shown below	1.56			1.37			5.54
Cobalt creditsb	(0.44		)	—			—
Royalty on metals	0.06			0.05			0.15
Unit net cash costs	1.18			1.42			5.69
Depreciation, depletion and amortization	0.55			0.46			1.31
Noncash and other costs, net	0.03			0.03			0.08
Total unit costs	1.76			1.91			7.08
Revenue adjustments, primarily for pricing
on prior period open sales	(0.03		)	(0.03		)	(0.04		)
Gross profit per pound	$	0.87		$	0.72		$	2.11
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	783		$	417		$	130
Royalty on metals	(14		)	—			—
Noncash and other costs, net	—			8			—
Revenue adjustments, primarily for pricing     on prior period open sales	(8		)	—			—
Africa mining	761			425			130
Other mining & eliminationsc	6,571			4,766			677
Total mining	7,332			5,191			807
U.S. oil & gas operations	1,069			564			6,805			d
Corporate, other & eliminations	—			5			7
As reported in FCX’s consolidated financial statements	$	8,401		$	5,760		$	7,619		d

a. Includes point-of-sale transportation costs as negotiated in customer contracts. 

b. Net of cobalt downstream processing and freight costs.

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

d. Includes impairment of oil and gas properties of $5.8 billion.

82

Africa Mining Product Revenues, Production Costs and Unit Net Cash Costs (continued)

Six Months Ended June 30, 2014
(In millions)	By-Product			Co-Product Method
	Method			Copper			Cobalt		Total
Revenues, excluding adjustmentsa	$	621		$	621		$	137	$	758
Site production and delivery, before net noncash     and other costs shown below	296			262			77		339
Cobalt creditsb	(96		)	—			—		—
Royalty on metals	14			12			2		14
Net cash costs	214			274			79		353
Depreciation, depletion and amortization	114			99			15		114
Noncash and other costs, net	11			10			1		11
Total costs	339			383			95		478
Revenue adjustments, primarily for pricing     on prior period open sales	(1		)	(1		)	2		1
Gross profit	$	281		$	237		$	44	$	281
Copper sales (millions of recoverable pounds)	202			202
Cobalt sales (millions of contained pounds)							15
Gross profit per pound of copper/cobalt:
Revenues, excluding adjustmentsa	$	3.08		$	3.08		$	9.29
Site production and delivery, before net noncash
and other costs shown below	1.47			1.30			5.19
Cobalt creditsb	(0.48		)	—			—
Royalty on metals	0.07			0.06			0.16
Unit net cash costs	1.06			1.36			5.35
Depreciation, depletion and amortization	0.57			0.49			1.03
Noncash and other costs, net	0.05			0.04			0.09
Total unit costs	1.68			1.89			6.47
Revenue adjustments, primarily for pricing
on prior period open sales	(0.01		)	(0.01		)	0.13
Gross profit per pound	$	1.39		$	1.18		$	2.95
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	758		$	339		$	114
Royalty on metals	(14		)	—			—
Noncash and other costs, net	—			11			—
Revenue adjustments, primarily for pricing     on prior period open sales	1			—			—
Africa mining	745			350			114
Other mining & eliminationsc	7,265			4,830			626
Total mining	8,010			5,180			740
U.S. oil & gas operations	2,497			640			1,232
Corporate, other & eliminations	—			(1		)	7
As reported in FCX’s consolidated financial statements	$	10,507		$	5,819		$	1,979

a. Includes point-of-sale transportation costs as negotiated in customer contracts. 

b. Net of cobalt downstream processing and freight costs.

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.

83

Molybdenum Mines Product Revenues, Production Costs and Unit Net Cash Costs

	Three Months Ended June 30,
(In millions)	2015				2014
Revenues, excluding adjustmentsa	$	112			$	181
Site production and delivery, before net noncash and other costs shown below	80				79
Treatment charges and other	10				11
Net cash costs	90				90
Depreciation, depletion and amortization	25				24
Noncash and other costs, net	4			b	2
Total costs	119				116
Gross (loss) profit	$	(7	)		$	65
Molybdenum sales (millions of recoverable pounds)a	13				14
Gross profit per pound of molybdenum:
Revenues, excluding adjustmentsa	$	9.00			$	12.90
Site production and delivery, before net noncash and other costs shown below	6.35				5.64
Treatment charges and other	0.84				0.83
Unit net cash costs	7.19				6.47
Depreciation, depletion and amortization	1.97				1.69
Noncash and other costs, net	0.37			b	0.10
Total unit costs	9.53				8.26
Gross (loss) profit per pound	$	(0.53	)		$	4.64
Reconciliation to Amounts Reported
(In millions)
Three Months Ended June 30, 2015	Revenues				Production and Delivery				Depreciation, Depletion and Amortization
Totals presented above	$	112			$	80			$	25
Treatment charges and other	(10		)		—				—
Noncash and other costs, net	—				4			b	—
Molybdenum mines	102				84				25
Other mining & eliminationsc	3,577				2,481				377
Total mining	3,679				2,565				402
U.S. oil & gas operations	569				281				3,171		d
Corporate, other & eliminations	—				2				3
As reported in FCX’s consolidated financial statements	$	4,248			$	2,848			$	3,576	d
Three Months Ended June 30, 2014
Totals presented above	$	181			$	79			$	24
Treatment charges and other	(11		)		—				—
Noncash and other costs, net	—				2				—
Molybdenum mines	170				81				24
Other mining & eliminationsc	4,116				2,673				370
Total mining	4,286				2,754				394
U.S. oil & gas operations	1,236				329				616
Corporate, other & eliminations	—				(1		)		3
As reported in FCX’s consolidated financial statements	$	5,522			$	3,082			$	1,013

a. Reflects sales of the Molybdenum mines' production to our molybdenum sales company at market-based pricing. On a consolidated basis, realizations are based on the actual contract terms for sales to third parties; as a result, our consolidated average realized price per pound of molybdenum will differ from the amounts reported in this table.

b. Includes charges totaling $3 million ($0.21 per pound) for LCM inventory adjustments.

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10. Also includes amounts associated with our molybdenum sales company, which includes sales of molybdenum produced by the Molybdenum mines and by certain of the North and South America copper mines.

d. Includes impairment of oil and gas properties of $2.7 billion.

84

Molybdenum Mines Product Revenues, Production Costs and Unit Net Cash Costs (continued)

	Six Months Ended June 30,
(In millions)	2015				2014
Revenues, excluding adjustmentsa	$	236			$	318
Site production and delivery, before net noncash    and other costs shown below	161				154
Treatment charges and other	21				22
Net cash costs	182				176
Depreciation, depletion and amortization	51				46
Noncash and other costs, net	6			b	3
Total costs	239				225
Gross (loss) profit	$	(3	)		$	93
Molybdenum sales (millions of recoverable pounds)a	26				27
Gross profit per pound of molybdenum:
Revenues, excluding adjustmentsa	$	9.34			$	11.88
Site production and delivery, before net noncash    and other costs shown below	6.34				5.75
Treatment charges and other	0.84				0.83
Unit net cash costs	7.18				6.58
Depreciation, depletion and amortization	2.00				1.72
Noncash and other costs, net	0.25			b	0.10
Total unit costs	9.43				8.40
Gross (loss) profit per pound	$	(0.09	)		$	3.48
Reconciliation to Amounts Reported
(In millions)
Six Months Ended June 30, 2015	Revenues				Production and Delivery				Depreciation, Depletion and Amortization
Totals presented above	$	236			$	161			$	51
Treatment charges and other	(21		)		—				—
Noncash and other costs, net	—				6			b	—
Molybdenum mines	215				167				51
Other mining & eliminationsc	7,117				5,024				756
Total mining	7,332				5,191				807
U.S. oil & gas operations	1,069				564				6,805		d
Corporate, other & eliminations	—				5				7
As reported in FCX’s consolidated financial statements	$	8,401			$	5,760			$	7,619	d
Six Months Ended June 30, 2014
Totals presented above	$	318			$	154			$	46
Treatment charges and other	(22		)		—				—
Noncash and other costs,net	—				3				—
Molybdenum mines	296				157				46
Other mining & eliminationsc	7,714				5,023				694
Total mining	8,010				5,180				740
U.S. oil & gas operations	2,497				640				1,232
Corporate, other & eliminations	—				(1		)		7
As reported in FCX’s consolidated financial statements	$	10,507			$	5,819			$	1,979

a. Reflects sales of the Molybdenum mines' production to our molybdenum sales company at market-based pricing. On a consolidated basis, realizations are based on the actual contract terms for sales to third parties; as a result, our consolidated average realized price per pound of molybdenum will differ from the amounts reported in this table.

b. Includes charges totaling $3 million ($0.11 per pound) for LCM inventory adjustments.

c. Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10. Also includes amounts associated with our molybdenum sales company, which includes sales of molybdenum produced by the Molybdenum mines and by certain of the North and South America copper mines.

d. Includes impairment of oil and gas properties of $5.8 billion.

85

U.S. Oil & Gas Product Revenues, Cash Production Costs and Realizations

Three Months Ended June 30, 2015
(In millions)	Oil			Natural Gas		NGLs		Total U.S. Oil & Gas
Oil and gas revenues before derivatives	$	480		$	63	$	12	$	555
Cash gains on derivative contracts	101			—		—		101
Realized revenues	$	581		$	63	$	12	656
Less: cash production costs								249
Cash operating margin								407
Less: depreciation, depletion and amortization								485
Less: impairment of oil and gas properties								2,686
Less: accretion and other costs								32
Plus: net noncash mark-to-market losses on derivative contracts								(95		)
Plus: other net adjustments								8
Gross loss								$	(2,883	)
Oil (MMBbls)	8.6
Gas (Bcf)				23.5
NGLs (MMBbls)						0.6
Oil Equivalents (MMBOE)								13.1
	Oil (per barrel)			Natural Gas (per MMBtu)		NGLs (per barrel)		Per BOE
Oil and gas revenues before derivatives	$	55.82		$	2.66	$	20.50	$	42.31
Cash gains on derivative contracts	11.79			—		—		7.73
Realized revenues	$	67.61		$	2.66	$	20.50	50.04
Less: cash production costs								19.04
Cash operating margin								31.00
Less: depreciation, depletion and amortization								36.99
Less: impairment of oil and gas properties								204.91
Less: accretion and other costs								2.46
Plus: net noncash mark-to-market losses on derivative contracts								(7.26		)
Plus: other net adjustments								0.61
Gross loss								$	(220.01	)
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery		Depreciation, Depletion and Amortization
Totals presented above	$	555		$	249	$	485
Cash gains on derivative contracts	101			—		—
Net noncash mark-to-market losses on derivative contracts	(95		)	—		—
Accretion and other costs	—			32		—
Impairment of oil and gas properties	—			—		2,686
Other net adjustments	8			—		—
U.S. oil & gas operations	569			281		3,171
Total mininga	3,679			2,565		402
Corporate, other & eliminations	—			2		3
As reported in FCX's consolidated financial statements	$	4,248		$	2,848	$	3,576

a. Represents the combined total for mining operations and the related eliminations, as presented in Note 10.

86

U.S. Oil & Gas Product Revenues, Cash Production Costs and Realizations (continued)
Three Months Ended June 30, 2014
									Total
				Natural					U.S. Oil
(In millions)	Oil			Gas			NGLs		& Gas
Oil and gas revenues before derivatives	$	1,172		$	96		$	38	$	1,306		a
Cash losses on derivative contracts	(57		)	(6		)	—		(63		)
Realized revenues	$	1,115		$	90		$	38	1,243
Less: cash production costs									314			a
Cash operating margin									929
Less: depreciation, depletion and amortization									616
Less: accretion and other costs									15
Plus: net noncash mark-to-market losses on derivative contracts									(7		)
Plus: other net adjustments									—
Gross profit									$	291
Oil (MMBbls)	11.7
Gas (Bcf)				20.3
NGLs (MMBbls)							1.0
Oil Equivalents (MMBOE)									16.0
	Oil			Natural Gas			NGLs
	(per barrel)			(per MMBtu)			(per barrel)		Per BOE
Oil and gas revenues before derivatives	$	100.46		$	4.70		$	38.79	$	81.47		a
Cash losses on derivative contracts	(4.96		)	(0.26		)	—		(3.94		)
Realized revenues	$	95.50		$	4.44		$	38.79	77.53
Less: cash production costs									19.57			a
Cash operating margin									57.96
Less: depreciation, depletion and amortization									38.39
Less: accretion and other costs									0.94
Plus: net noncash mark-to-market losses on derivative contracts									(0.44		)
Plus: other net adjustments									0.04
Gross profit									$	18.23
Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	1,306		$	314		$	616
Cash losses on derivative contracts	(63		)	—			—
Net noncash mark-to-market losses on derivative contracts	(7		)	—			—
Accretion and other costs	—			15			—
Other net adjustments	—			—			—
U.S. oil & gas operations	1,236			329			616
Total miningb	4,286			2,754			394
Corporate, other & eliminations	—			(1		)	3
As reported in FCX's consolidated financial statements	$	5,522		$	3,082		$	1,013

a.Following is a reconciliation of FM O&G's second-quarter 2014 cash production costs per BOE, excluding Eagle Ford:

	Cash Production Costs (in millions)		Oil Equivalents (MMBOE)	Cash Production Costs Per BOE
Presented above	$	314	16.0	$	19.57
Less: Eagle Ford	53		4.0	13.23
	$	261	12.0	$	21.66

b. Represents the combined total for mining operations and the related eliminations, as presented in Note 10.

87

U.S. Oil & Gas Product Revenues, Cash Production Costs and Realizations (continued)

Six Months Ended June 30, 2015
(In millions)	Oil			Natural Gas		NGLs		Total U.S. Oil & Gas
Oil and gas revenues before derivatives	$	853		$	125	$	24	$	1,002
Cash gains on derivative contracts	201			—		—		201
Realized revenues	$	1,054		$	125	$	24	1,203
Less: cash production costs								503
Cash operating margin								700
Less: depreciation, depletion and amortization								1,015
Less: impairment of oil and gas properties								5,790
Less: accretion and other costs								61
Plus: net noncash mark-to-market losses on derivative   contracts								(143		)
Plus: other net adjustments								9
Gross loss								$	(6,300	)
Oil (MMBbls)	17.0
Gas (Bcf)				45.3
NGLs (MMBbls)						1.1
Oil Equivalents (MMBOE)								25.6
	Oil (per barrel)			Natural Gas (per MMBtu)		NGLs (per barrel)		Per BOE
Oil and gas revenues before derivatives	$	50.25		$	2.75	$	21.71	$	39.08
Cash gains on derivative contracts	11.88			—		—		7.87
Realized revenues	$	62.13		$	2.75	$	21.71	46.95
Less: cash production costs								19.62
Cash operating margin								27.33
Less: depreciation, depletion and amortization								39.59
Less: impairment of oil and gas properties								225.89
Less: accretion and other costs								2.39
Plus: net noncash mark-to-market losses on derivative   contracts								(5.60		)
Plus: other net adjustments								0.34
Gross loss								$	(245.80	)
Reconciliation to Amounts Reported
(In Millions)	Revenues			Production and Delivery		Depreciation, Depletion and Amortization
Totals presented above	$	1,002		$	503	$	1,015
Cash gains on derivative contracts	201			—		—
Net noncash mark-to-market losses on derivative contracts	(143		)	—		—
Accretion and other costs	—			61		—
Impairment of oil and gas properties	—			—		5,790
Other net adjustments	9			—		—
U.S. oil & gas operations	1,069			564		6,805
Total mininga	7,332			5,191		807
Corporate, other & eliminations	—			5		7
As reported in FCX's consolidated financial statements	$	8,401		$	5,760	$	7,619

a. Represents the combined total for mining operations and the related eliminations, as presented in Note 10.

88

U.S. Oil & Gas Product Revenues, Cash Production Costs and Realizations (continued)

Six Months Ended June 30, 2014
(In millions)	Oil			Natural Gas			NGLs		Total U.S. Oil & Gas
Oil and gas revenues before derivatives	$	2,334		$	194		$	88	$	2,616		a
Cash losses on derivative contracts	(115		)	(13		)	—		(128		)
Realized revenues	$	2,219		$	181		$	88	2,488
Less: cash production costs									612			a
Cash operating margin									1,876
Less: depreciation, depletion and amortization									1,232
Less: accretion and other costs									28
Plus: net noncash mark-to-market gains on derivative contracts									8
Plus: other net adjustments									1
Gross profit									$	625
Oil (MMBbls)	23.5
Gas (Bcf)				39.8
NGLs (MMBbls)							2.1
Oil Equivalents (MMBOE)									32.2
	Oil (per barrel)			Natural Gas (per MMBtu)			NGLs (per barrel)		Per BOE
Oil and gas revenues before derivatives	$	99.54		$	4.87		$	42.35	$	81.34		a
Cash losses on derivative contracts	(4.91		)	(0.32		)	—		(3.97		)
Realized revenues	$	94.63		$	4.55		$	42.35	77.37
Less: cash production costs									19.03			a
Cash operating margin									58.34
Less: depreciation, depletion and amortization									38.30
Less: accretion and other costs									0.87
Plus: net noncash mark-to-market gains on derivative contracts									0.23
Plus: other net adjustments									0.04
Gross profit									$	19.44
Reconciliation to Amounts Reported for the Six Months Ended June 30, 2014
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	2,616		$	612		$	1,232
Cash losses on derivative contracts	(128		)	—			—
Net noncash mark-to-market gains on derivative contracts	8			—			—
Accretion and other costs	—			28			—
Other net adjustments	1			—			—
U.S. oil & gas operations	2,497			640			1,232
Total miningb	8,010			5,180			740
Corporate, other & eliminations	—			(1		)	7
As reported in FCX's consolidated financial statements	$	10,507		$	5,819		$	1,979

a.Following is a reconciliation of FM O&G's cash production costs per BOE for the first six months of 2014, excluding Eagle Ford:

	Cash Production Costs (in millions)		Oil Equivalents (MMBOE)	Cash Production Costs Per BOE
Presented above	$	612	32.2	$	19.03
Less: Eagle Ford	113		8.7	12.97
	$	499	23.5	$	21.29

b. Represents the combined total for mining operations and the related eliminations, as presented in Note 10.

89

CAUTIONARY STATEMENT

Our discussion and analysis contains forward-looking statements in which we discuss factors we believe may affect our future performance. Forward-looking statements are all statements other than statements of historical facts, such as projections or expectations relating to ore grades and milling rates; production and sales volumes; unit net cash costs; cash production costs per BOE; operating cash flows; capital expenditures; exploration efforts and results; development and production activities and costs; liquidity; tax rates; the impact of copper, gold, molybdenum, cobalt, crude oil and natural gas price changes; the impact of derivative positions; the impact of deferred intercompany profits on earnings; reserve estimates; future dividend payments; debt reduction and share purchases. The words “anticipates,” “may,” “can,” “plans,” “believes,” “potential,” “estimates,” “expects,” “projects,” “targets,” “intends,” “likely,” “will,” “should,” “to be” and any similar expressions are intended to identify those assertions as forward-looking statements. The declaration of dividends is at the discretion of the Board and will depend on our financial results, cash requirements, future prospects, and other factors deemed relevant by the Board.

We caution readers that forward-looking statements are not guarantees of future performance and actual results may differ materially from those anticipated, projected or assumed in the forward-looking statements. In particular, on July 28, 2015, we announced that we are undertaking a comprehensive review of operating plans to target significant additional reductions in capital spending, and operating and administrative costs. As part of this process, on August 5, 2015, we announced revisions to our oil and gas capital expenditure and production outlook. We expect to report revised plans for our mining operations during third-quarter 2015.

Important factors that can cause our actual results to differ materially from those anticipated in the forward-looking statements include supply of and demand for, and prices of copper, gold, molybdenum, cobalt, crude oil and natural gas, mine sequencing, production rates, industry risks, regulatory changes, political risks, drilling results, potential additional oil and gas property impairment charges, potential LCM inventory adjustments, potential impairment of long-lived mining assets, the outcome of negotiations with the Indonesian government regarding PT-FI's COW, PT-FI's ability to obtain renewal of its export license after January 28, 2016, PT-FI's ability to renew its bi-annual labor agreement expiring in September 2015, PT Smelting's ability to restart smelter operations as expected in September 2015, the potential effects of violence in Indonesia, the resolution of administrative disputes in the DRC, weather- and climate-related risks, labor relations, environmental risks, litigation results and other factors described in more detail in Part I, Item 1A. “Risk Factors” of our annual report on Form 10-K for the year ended December 31, 2014, as updated by our subsequent filings with the SEC.

Investors are cautioned that many of the assumptions upon which our forward-looking statements are based are likely to change after the forward-looking statements are made, including for example commodity prices, which we cannot control, and production volumes and costs, some aspects of which we may not be able to control. Further, we may make changes to our business plans that could affect our results. We caution investors that, except for our expectation that we will report revised plans for our mining operations during third-quarter 2015, we do not intend to update forward-looking statements more frequently than quarterly notwithstanding any changes in our assumptions, changes in business plans, actual experience or other changes, and we undertake no obligation to update any forward-looking statements.

90

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

There have been no material changes in our market risks during the three-month period ended June 30, 2015. For additional information on market risks, refer to “Disclosures About Market Risks” included in Part I, Item 2. of our annual report on Form 10-K for the year ended December 31, 2014. For projected sensitivities of our operating cash flow to changes in commodity prices, refer to “Outlook” in Part I, Item 2. of this quarterly report on Form 10-Q for the period ended June 30, 2015; for projected sensitivities of our provisionally priced copper sales and derivative instruments to changes in commodity prices refer to “Consolidated Results – Revenues” in Part I, Item 2. of this quarterly report on Form 10-Q for the period ended June 30, 2015.

Item 4. Controls and Procedures.

(a) Evaluation of disclosure controls and procedures. Our chief executive officer and chief financial officer, with the participation of management, have evaluated the effectiveness of our “disclosure controls and procedures” (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this quarterly report on Form 10-Q. Based on their evaluation, they have concluded that our disclosure controls and procedures are effective as of June 30, 2015.

(b) Changes in internal control over financial reporting. There has been no change in our internal control over financial reporting that occurred during the quarter ended June 30, 2015, that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

Part II. OTHER INFORMATION

Item 1. Legal Proceedings.

We are involved in numerous legal proceedings that arise in the ordinary course of our business or that are associated with environmental issues arising from legacy operations conducted over the years by Freeport Minerals Corporation and its affiliates. We are also involved from time to time in other reviews, investigations and proceedings by government agencies, some of which may result in adverse judgments, settlements, fines, penalties, injunctions or other relief.

Management does not believe, based on currently available information, that the outcome of any proceeding reported in Note 12 and incorporated by reference into Part I, Item 3. “Legal Proceedings” of our annual report on Form 10-K for the year ended December 31, 2014, as updated in Note 9 to the financial statements included in this quarterly report on Form 10-Q for the quarter ended June 30, 2015, will have a material adverse effect on our financial condition; although individual outcomes could be material to our operating results for a particular period, depending on the nature and magnitude of the outcome and the operating results for the period.

Item 1A. Risk Factors.

There have been no material changes to our risk factors during the three-month period ended June 30, 2015 . For additional information on risk factors, refer to Part I, Item 1A. "Risk Factors" of our annual report on Form 10-K for the year ended December 31, 2014.

91

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

(c) The following table sets forth information with respect to shares of our common stock purchased by us during the three months ended June 30, 2015:

Period	(a) Total Number of Shares Purchased	(b) Average Price Paid Per Share		(c) Total Number of Shares Purchased as Part of Publicly Announced Plans or Programsa	(d) Maximum Number of Shares That May Yet Be Purchased Under the Plans or Programsa
April 1-30, 2015	—	$	—	—	23,685,500
May 1-31, 2015	—	$	—	—	23,685,500
June 1-30, 2015	—	$	—	—	23,685,500
Total	—	$	—	—	23,685,500

a. On July 21, 2008, our Board of Directors approved an increase in our open-market share purchase program for up to 30 million shares. There have been no purchases under this program since 2008. This program does not have an expiration date.

Item 4. Mine Safety Disclosure.

The safety and health of all employees is our highest priority. Management believes that safety and health considerations are integral to, and compatible with, all other functions in the organization and that proper safety and health management will enhance production and reduce costs. Our approach towards the safety and health of our workforce is to continuously improve performance through implementing robust management systems and providing adequate training, safety incentive and occupational health programs. The information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K is included in Exhibit 95.1 to this quarterly report on Form 10-Q.

Item 6. Exhibits.

The exhibits to this report are listed in the Exhibit Index beginning on Page E-1 hereof.

92

FREEPORT-McMoRan INC.

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

FREEPORT-McMoRan INC.
By:	/s/ C. Donald Whitmire, Jr.
	C. Donald Whitmire, Jr.
	Vice President and
	Controller - Financial Reporting
	(authorized signatory
	and Principal Accounting Officer)

Date:  August 10, 2015

93

FREEPORT-McMoRan INC.
EXHIBIT INDEX
		Filed
Exhibit		with this	Incorporated by Reference
Number	Exhibit Title	Form 10-Q	Form	File No.	Date Filed
3.1	Composite Certificate of Incorporation of FCX		10-Q	001-11307-01	8/8/2014
3.2	Composite By-Laws of FCX as of July 14, 2014		8-K	001-11307-01	7/2/2014
4.1	Indenture dated as of February 13, 2012, between FCX and U.S. Bank National Association, as Trustee (relating to the 2.15% Senior Notes due 2017, the 3.55% Senior Notes due 2022, the 2.30% Senior Notes due 2017, the 4.00% Senior Notes due 2021, the 4.55% Senior Notes due 2024, and the 5.40% Senior Notes due 2034).		8-K	001-11307-01	2/13/2012
4.2	Second Supplemental Indenture dated as of February 13, 2012, between FCX and U.S. Bank National Association, as Trustee (relating to the 2.15% Senior Notes due 2017).		8-K	001-11307-01	2/13/2012
4.3	Third Supplemental Indenture dated as of February 13, 2012, between FCX and U.S. Bank National Association, as Trustee (relating to the 3.55% Senior Notes due 2022).		8-K	001-11307-01	2/13/2012
4.4	Fourth Supplemental Indenture dated as of May 31, 2013, among FCX, Freeport-McMoRan Oil & Gas LLC and U.S. Bank National Association, as Trustee (relating to the 2.15% Senior Notes due 2017, and the 3.55% Senior Notes due 2022, the 2.30% Senior Notes due 2017, the 4.00% Senior Notes due 2021, the 4.55% Senior Notes due 2024, and the 5.40% Senior Notes due 2034).		8-K	001-11307-01	6/3/2013
4.5	Fifth Supplemental Indenture dated as of November 14, 2014 among FCX, Freeport-McMoRan Oil & Gas LLC and U.S. Bank National Association, as Trustee (relating to the 2.30% Senior Notes due 2017).		8-K	001-11307-01	11/14/2014
4.6	Sixth Supplemental Indenture dated as of November 14, 2014 among FCX, Freeport-McMoRan Oil & Gas LLC and U.S. Bank National Association, as Trustee (relating to the 4.00% Senior Notes due 2021).		8-K	001-11307-01	11/14/2014
4.7	Seventh Supplemental Indenture dated as of November 14, 2014 among FCX, Freeport-McMoRan Oil & Gas LLC and U.S. Bank National Association, as Trustee. (relating to the 4.55% Senior Notes due 2024).		8-K	001-11307-01	11/14/2014
4.8	Eighth Supplemental Indenture dated as of November 14, 2014 among FCX, Freeport-McMoRan Oil & Gas LLC and U.S. Bank National Association, as Trustee (relating to the 5.40% Senior Notes due 2034).		8-K	001-11307-01	11/14/2014
4.9	Indenture dated as of March 7, 2013, between FCX and U.S. Bank National Association, as Trustee (relating to the 2.375% Senior Notes due 2018, the 3.100% Senior Notes due 2020, the 3.875% Senior Notes due 2023, and the 5.450% Senior Notes due 2043).		8-K	001-11307-01	3/7/2013
4.10	Supplemental Indenture dated as of May 31, 2013, among FCX, Freeport-McMoRan Oil & Gas LLC and U.S. Bank National Association, as Trustee (relating to the 2.375% Senior Notes due 2018, the 3.100% Senior Notes due 2020, the 3.875% Senior Notes due 2023, and the 5.450% Senior Notes due 2043).		8-K	001-11307-01	6/3/2013

E-1

FREEPORT-McMoRan INC.
EXHIBIT INDEX
		Filed
Exhibit		with this	Incorporated by Reference
Number	Exhibit Title	Form 10-Q	Form	File No.	Date Filed
4.11	Indenture dated as of March 13, 2007, among Plains Exploration & Production Company, the Subsidiary Guarantors parties thereto, and Wells Fargo Bank, N.A., as Trustee (relating to the 6.625% Senior Notes due 2021, the 6.75% Senior Notes due 2022, the 6.125% Senior Notes due 2019, the 6.5% Senior Notes due 2020, and the 6.875% Senior Notes due 2023).		8-K	001-31470	3/13/2007
4.12	Twelfth Supplemental Indenture dated as of March 29, 2011 to the Indenture dated as of March 13, 2007, among Plains Exploration & Production Company, the Subsidiary Guarantors parties thereto and Wells Fargo Bank, N.A., as Trustee (relating to the 6.625% Senior Notes due 2021).		8-K	001-31470	3/29/2011
4.13	Thirteenth Supplemental Indenture dated as of November 21, 2011 to the Indenture dated as of March 13, 2007, among Plains Exploration & Production Company, the Subsidiary Guarantors parties thereto and Wells Fargo Bank, N.A., as Trustee (relating to the 6.75% Senior Notes due 2022).		8-K	001-31470	11/22/2011
4.14	Fourteenth Supplemental Indenture dated as of April 27, 2012 to the Indenture dated as of March 13, 2007, among Plains Exploration & Production Company, the Subsidiary Guarantors parties thereto and Wells Fargo Bank, N.A., as Trustee (relating to the 6.125% Senior Notes due 2019).		8-K	001-31470	4/27/2012
4.15	Sixteenth Supplemental Indenture dated as of October 26, 2012 to the Indenture dated as of March 13, 2007, among Plains Exploration & Production Company, the Subsidiary Guarantors parties thereto and Wells Fargo Bank, N.A., as Trustee (relating to the 6.5% Senior Notes due 2020).		8-K	001-31470	10/26/2012
4.16	Seventeenth Supplemental Indenture dated as of October 26, 2012 to the Indenture dated as of March 13, 2007, among Plains Exploration & Production Company, the Subsidiary Guarantors parties thereto and Wells Fargo Bank, N.A., as Trustee (relating to the 6.875% Senior Notes due 2023).		8-K	001-31470	10/26/2012
4.17	Eighteenth Supplemental Indenture dated as of May 31, 2013 to the Indenture dated as of March 13, 2007, among Freeport-McMoRan Oil & Gas LLC, as Successor Issuer, FCX Oil & Gas Inc., as Co-Issuer, FCX, as Parent Guarantor, Plains Exploration & Production Company, as Original Issuer, and Wells Fargo Bank, N.A., as Trustee (relating to the 6.625% Senior Notes due 2021, the 6.75% Senior Notes due 2022, the 6.125% Senior Notes due 2019, the 6.5% Senior Notes due 2020, and the 6.875% Senior Notes due 2023).		8-K	001-11307-01	6/3/2013
4.18	Form of Indenture dated as of September 22, 1997, between Phelps Dodge Corporation and The Chase Manhattan Bank, as Trustee (relating to the 7.125% Senior Notes due 2027, the 9.50% Senior Notes due 2031, and the 6.125% Senior Notes due 2034).		S-3	333-36415	9/25/1997

E-2

FREEPORT-McMoRan INC.
EXHIBIT INDEX
		Filed
Exhibit		with this	Incorporated by Reference
Number	Exhibit Title	Form 10-Q	Form	File No.	Date Filed
4.19	Form of 7.125% Debenture due November 1, 2027 of Phelps Dodge Corporation issued on November 5, 1997, pursuant to the Indenture dated as of September 22, 1997, between Phelps Dodge Corporation and The Chase Manhattan Bank, as Trustee (relating to the 7.125% Senior Notes due 2027).		8-K	01-00082	11/3/1997
4.20	Form of 9.5% Note due June 1, 2031 of Phelps Dodge Corporation issued on May 30, 2001, pursuant to the Indenture dated as of September 22, 1997, between Phelps Dodge Corporation and First Union National Bank, as successor Trustee (relating to the 9.50% Senior Notes due 2031).		8-K	01-00082	5/30/2001
4.21	Form of 6.125% Note due March 15, 2034 of Phelps Dodge Corporation issued on March 4, 2004, pursuant to the Indenture dated as of September 22, 1997, between Phelps Dodge Corporation and First Union National Bank, as successor Trustee (relating to the 6.125% Senior Notes due 2034).		10-K	01-00082	3/7/2005
10.1	Amendment dated July 21, 2015, to the Restated Trust Agreement dated as of October 11, 1996, among PT Freeport Indonesia, PT Rio Tinto Indonesia (formerly P.T. RTZ-CRA Indonesia), U.S. Bank National Association, as trustee, JP Morgan Chase Bank, N.A., as depository, and the Secured Creditors.	X
15.1	Letter from Ernst & Young LLP regarding unaudited interim financial statements.	X
31.1	Certification of Principal Executive Officer pursuant to Rule 13a-14(a)/15d – 14(a).	X
31.2	Certification of Principal Financial Officer pursuant to Rule 13a-14(a)/15d – 14(a).	X
32.1	Certification of Principal Executive Officer pursuant to 18 U.S.C. Section 1350.	X
32.2	Certification of Principal Financial Officer pursuant to 18 U.S.C Section 1350.	X
95.1	Mine Safety and Health Administration Safety Data.	X
101.INS	XBRL Instance Document.	X
101.SCH	XBRL Taxonomy Extension Schema.	X
101.CAL	XBRL Taxonomy Extension Calculation Linkbase.	X
101.DEF	XBRL Taxonomy Extension Definition Linkbase.	X
101.LAB	XBRL Taxonomy Extension Label Linkbase.	X
101.PRE	XBRL Taxonomy Extension Presentation Linkbase.	X

Note: Certain instruments with respect to long-term debt of FCX have not been filed as exhibits to this Quarterly Report on Form 10-Q since the total amount of securities authorized under any such instrument does not exceed 10 percent of the total assets of FCX and its subsidiaries on a consolidated basis. FCX agrees to furnish a copy of each such instrument upon request of the Securities and Exchange Commission.

E-3

EX-10.1

Exhibit 10.1

AMENDMENT TO RESTATED TRUST AGREEMENT

AMENDMENT dated as of July 21, 2015 (this “Amendment”) to the Restated Trust Agreement dated as of October 11, 1996 (as amended from time to time, including as supplemented by Financing Annexes thereto, hereinafter referred to as the “Restated Trust Agreement”), among PT FREEPORT INDONESIA, a limited liability company organized under the laws of Indonesia (“FI”), PT Rio Tinto Indonesia (f/k/a P.T. RTZ-CRA INDONESIA), a company formed under the laws of the Republic of Indonesia (“PT-RTZ”), U.S. BANK NATIONAL ASSOCIATION, a national banking association (successor to FIRST TRUST OF NEW YORK, NATIONAL ASSOCIATION, a national banking association), as trustee, JPMORGAN CHASE BANK, N.A. (successor to THE CHASE MANHATTAN BANK (as successor to The Chase Manhattan Bank (National Association)), as depositary, and certain Secured Creditors of FI listed as the Secured Creditors in each Financing Annex to the Trust Agreement.

WHEREAS, the Trust Agreement dated as of May 15, 1970, as theretofore amended and restated, was restated in the form of the Restated Trust Agreement dated as of October 11, 1996 pursuant an Agreement to Amend and Restate Trust Agreement entered into by The RTZ Corporation PLC, a public limited company organized under the laws of England, RTZ Lender (as defined in the Restated Trust Agreement), FI, PT-RTZ, the Trustee, The Chase Manhattan Bank (as successor to The Chase Manhattan Bank (National Association)), as depositary, and The Chase Manhattan Bank, acting on behalf of certain Secured Creditors; and

WHEREAS, the parties to the Restated Trust Agreement have agreed to amend the Restated Trust Agreement in order to comply with certain Applicable Laws (as defined herein), including, but not limited to, regulations pertaining to the deposit of Proceeds (as defined in the Restated Trust Agreement) into a foreign exchange bank in Indonesia, as set forth in this Amendment;

NOW, THEREFORE, in consideration of the mutual agreements herein contained and other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto hereby agree as follows:

SECTION 1. Definitions. Capitalized terms used in this Amendment and not otherwise defined herein shall have the meanings given to such terms in the Restated Trust Agreement.

SECTION 2. Amendment of the Restated Trust Agreement. The Restated Trust Agreement is hereby amended as follows:

(a) The heading of Article I is amended by the addition of “; Compliance with Applicable Laws” after “Definitions” so that the heading of Article I shall now read as follows:

{N3064778.2} 1

Exhibit 10.1

“ARTICLE I

Definitions; Compliance with Applicable Laws”

(b) Section 1.01 of the Restated Trust Agreement is amended by the addition of the following defined term as set forth below:

“Applicable Law” means, collectively, all applicable statutes, treaties, conventions, rules, guidelines, regulations, ordinances, codes and administrative or judicial precedents or authorities of the Republic of Indonesia, including, but not limited to regulations pertaining to the deposit of Proceeds into a foreign exchange bank in Indonesia, the interpretation or administration thereof by any governmental authority charged with the enforcement, interpretation or administration thereof, and all applicable administrative orders and decrees of courts or any governmental authority.

(c) A new Section 1.02 is added to the Restated Trust Agreement as set forth below:

SECTION 1.02. Compliance with Applicable Laws. To the extent required by Applicable Law, any Proceeds, including those from any letter of credit required to be received through a foreign exchange bank in Indonesia shall be directed to such bank account as determined from time to time by FI. To the extent such direction to a foreign exchange bank in Indonesia is not required by Applicable Law, all Proceeds shall be directed in accordance with Articles II through IV of this Agreement. For the avoidance of doubt, the provisions of Articles II through IV of this Agreement shall not apply to any Proceeds deposited into accounts in Indonesia pursuant to this Section 1.02.

(d) Section 3.01(a) of the of the Restated Trust Agreement is amended by the addition of the phrase “and to the extent permitted by Applicable Law” immediately following the phrase “Simultaneously with the execution and delivery hereof”.

(e) Section 3.01(a)(z) of the Restated Trust Agreement is amended by the addition of the phrase “except those required by Applicable Law to be directed to a foreign exchange bank account in Indonesia pursuant to Section 1.02 of this Agreement” immediately following the phrase “all Proceeds”.

(f) Section 3.01(c) of the Restated Trust Agreement is amended by the replacement of “Indonesian law” with “Applicable Law” and by the addition of the phrase “and to the extent permitted by Applicable Law” immediately following the phrase “to the extent possible”.

(g) The first sentence of Section 3.02(a) of the Restated Trust Agreement is amended by the replacement of the phrase “FI represents and warrants that the assignments made by it” with the phrase “FI represents and warrants that such assignments permitted by Applicable law and made by it”.

{N3064778.2} 2

Exhibit 10.1

(h) The second sentence of Section 3.02(a) of the Restated Trust Agreement is amended by the replacement of the phrase “FI represents warrants that the Concentrate Sales Agreements” with the phrase “FI represents and warrants that, to the extent permitted by Applicable Law, the Concentrate Sales Agreements”.

SECTION 3. Effect of Amendment; Severability. Except as expressly set forth in this Amendment, all provisions of the Restated Trust Agreement shall remain in full force and effect. All provisions of this Amendment are independent and severable from each other. If for any reason any one or more of the provisions herein shall be void, invalid, illegal or unenforceable, in whole or in part, in any respect under any applicable law, including the Applicable Law, such provision, or part thereof, shall to that extent be deemed not to form part of this Amendment and the validity, legality and enforceability of the remaining provisions contained herein shall not be affected or impaired in any way and shall be enforced as written. In any such event, each party hereto shall execute such additional documents or amendments as the other party may reasonably request in order to give valid, legal and enforceable effect to any provision hereof which is determined to be invalid, illegal or unenforceable.

SECTION 4. Governing Law. THIS AMENDMENT SHALL BE CONSTRUED AND BE ENFORCEABLE IN ACCORDANCE WITH THE LAW OF THE STATE OF NEW YORK EXCEPT TO THE EXTENT THAT DOING SO WOULD RESULT IN THE APPLICATION OF THE LAWS OF ANOTHER JURISDICTION.

SECTION 5. Headings; Counterparts. The headings in this Amendment are for convenience of reference only and shall not limit or otherwise affect the meaning hereof. This Amendment may be executed in several counterparts, each of which is an original, but all of which together shall constitute one instrument.

[Remainder of page intentionally left blank]

{N3064778.2} 3

Exhibit 10.1

IN WITNESS WHEREOF, the parties hereto have caused this Amendment to be duly executed and delivered, as of the day and year first above written.

PT FREEPORT INDONESIA,
By:
	/s/ Robert R. Boyce
	Name: Robert R. Boyce
	Title: Treasurer

PT RIO TINTO INDONESIA (F/K/A P.T. RTZ-CRA INDONESIA),
By:
	/s/ Greg Sinclair
	Name: Greg Sinclair
	Title: President Director

US BANK NATIONAL ASSOCIATION, as Trustee,
By:
	/s/ Beverly A. Freeney
	Name: Beverly A. Freeney
	Title: Vice President

{N3064778.2}

EX-15.1

Exhibit 15.1

To the Board of Directors and Stockholders of Freeport-McMoRan Inc.:

We are aware of the incorporation by reference in the following Registration Statements:

1) Registration Statement (Form S-8 No. 333-85803) pertaining to the Freeport-McMoRan Copper & Gold Inc.

1999 Stock Incentive Plan,

2) Registration Statement (Form S-8 No. 333-105535) pertaining to the Freeport-McMoRan Copper & Gold Inc. 2003 Stock Incentive Plan,

3) Registration Statement (Form S-8 No. 333-115292) pertaining to the Freeport-McMoRan Copper & Gold Inc. 2004 Director Compensation Plan,

4) Registration Statement (Form S-8 No. 333-136084) pertaining to the  Freeport-McMoRan Copper & Gold Inc. 2006 Stock Incentive Plan,

5) Registration Statement (Form S-8 No. 333-141358) pertaining to the Phelps Dodge 2003 Stock Option and Restricted Stock Plan and the Phelps Dodge 1998 Stock Option and Restricted Stock Plan,

6) Registration Statement (Form S-8 No. 333-147413) pertaining to the Amended and Restated Freeport-McMoRan Copper & Gold Inc. 2006 Stock Incentive Plan, and

7) Registration Statement (Form S-8 No. 333-189047) pertaining to the Plains Exploration & Production Company 2010 Incentive Award Plan; the Plains Exploration & Production 2004 Stock Incentive Plan; the McMoRan Exploration Co. Amended and Restated 2008 Stock Incentive Plan; the McMoRan Exploration Co. 2005 Stock Incentive Plan, as amended and restated; the McMoRan Exploration Co. 2004 Director Compensation Plan, as amended and restated; the McMoRan Exploration Co. 2003 Stock Incentive Plan, as amended and restated; the McMoRan Exploration Co. 2001 Stock Incentive Plan, as amended and restated; the McMoRan Exploration Co. 2000 Stock Incentive Plan, as amended and restated; the McMoRan Exploration Co. 1998 Stock Option Plan, as amended and restated; and the McMoRan Exploration Co. 1998 Stock Option Plan for Non-Employee Directors, as amended and restated;

of our report dated August 10, 2015 relating to the unaudited condensed consolidated interim financial statements of Freeport-McMoRan Inc. (formerly Freeport-McMoRan Copper & Gold Inc.) that is included in its Form 10-Q for the quarter ended June 30, 2015.

/s/ ERNST & YOUNG LLP

Phoenix, Arizona

August 10, 2015

EX-31.1

Exhibit 31.1

Certification

I, Richard C. Adkerson, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Freeport-McMoRan Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Dated: August 10, 2015

By:          /s/  Richard C. Adkerson

Richard C. Adkerson

Vice Chairman,

President and Chief Executive Officer

EX-31.2

Exhibit 31.2

Certification

I, Kathleen L. Quirk, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Freeport-McMoRan Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Dated: August 10, 2015

By:          /s/  Kathleen L. Quirk

Kathleen L. Quirk

Executive Vice President,

Chief Financial Officer and Treasurer

EX-32.1

Exhibit 32.1

Certification Pursuant to 18 U.S.C. Section 1350

(Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002)

In connection with the Quarterly Report on Form 10-Q of Freeport-McMoRan Inc. (the “Company”) for the quarter ending June 30, 2015, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), Richard C. Adkerson, as Vice Chairman, President and Chief Executive Officer of the Company, hereby certifies, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that, to the best of his knowledge:

(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: August 10, 2015

By:          /s/  Richard C. Adkerson

Richard C. Adkerson

Vice Chairman,

President and Chief Executive Officer

A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

This certification shall not be deemed filed by the Company for purposes of § 18 of the Securities Exchange Act of 1934, as amended.

EX-32.2

Exhibit 32.2

Certification Pursuant to 18 U.S.C. Section 1350

(Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002)

In connection with the Quarterly Report on Form 10-Q of Freeport-McMoRan Inc.(the “Company”) for the quarter ending June 30, 2015, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), Kathleen L. Quirk, as Executive Vice President, Chief Financial Officer and Treasurer of the Company, hereby certifies, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that, to the best of her knowledge:

(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: August 10, 2015

By:          /s/  Kathleen L. Quirk

Kathleen L. Quirk

Executive Vice President,

Chief Financial Officer and Treasurer

A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

This certification shall not be deemed filed by the Company for purposes of § 18 of the Securities Exchange Act of 1934, as amended.

EX-95.1

Exhibit 95.1

Mine Safety and Health Administration (MSHA) Safety Data

FCX's U.S. mining operations are subject to regulations issued by MSHA under the U.S. Federal Mine Safety and Health Act of 1977 (the Mine Act). MSHA inspects our U.S. mines on a regular basis and issues various citations and orders when it believes a violation has occurred under the Mine Act. Whenever MSHA issues a citation or order, it also generally proposes a civil penalty, or fine, related to the alleged violation. Citations or orders can be contested and appealed, and as part of that process, are often reduced in severity and amount, and are sometimes dismissed. The number of citations, orders and proposed assessments varies depending on the size and type (underground or surface) of the mine, among other factors.

The following disclosures have been provided pursuant to Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act (the Act).

Mine Safety Data. Following provides additional information about references used in the table below to describe the categories of violations, orders or citations issued by MSHA under the Mine Act:

• Section 104 S&S Citations: Citations issued by MSHA under Section 104(a) of the Mine Act for violations of health or safety standards that could significantly and substantially contribute to a serious injury if left unabated.

• Section 104(b) Orders: Orders issued under Section 104(b) of the Mine Act, which represent a failure to abate a citation under Section 104(a) within the period prescribed by MSHA. This results in an order of immediate withdrawal from the area of the mine affected by the condition until MSHA determines that the violation has been abated.

• Section 104(d) Citations and Orders: Citations and orders issued by MSHA under Section 104(d) of the Mine Act for unwarrantable failure to comply with mandatory health or safety standards. These types of violations could significantly and substantially contribute to a serious injury; however, the conditions do not cause imminent danger (refer to discussion of imminent danger orders below).

• Section 110(b)(2) Violations: Flagrant violations identified by MSHA under Section 110(b)(2) of the Mine Act. The term flagrant with respect to a violation is defined as “a reckless or repeated failure to make reasonable efforts to eliminate a known violation of a mandatory health or safety standard that substantially and proximately caused, or reasonably could have expected to cause, death or serious bodily injury.”

• Section 107(a) Orders: Orders issued by MSHA under Section 107(a) of the Mine Act for situations in which MSHA determined an imminent danger existed. Orders issued under Section 107(a) of the Mine Act require the operator of the mine to cause all persons (except authorized persons) to be withdrawn from the mine until the imminent danger and the conditions that caused such imminent danger cease to exist.

The following table details the violations, citations and orders issued to us by MSHA during the three months ended June 30, 2015:

										Potential
										to Have
									Pattern of	Pattern of
				Section					Violations	Violation
		Section	Section	104(d)	Section	Section		Mining	Under	Under
		104 S&S	104(b)	Citations	110(b)(2)	107(a)	Proposed	Related	Section	Section
		Citations	Orders	and Orders	Violations	Orders	Assessments(2)	Fatalities	104(e)	104(e)
Mine ID(1)	Mine or Operation Name	(#)	(#)	(#)	(#)	(#)	($)	(#)	(yes/no)	(yes/no)
0200137	Freeport-McMoRan Bagdad Inc. (Bagdad)	34	—	—	—	—	55,466	—	No	No
2900708	Freeport-McMoRan Chino Mines Company (Chino)	—	—	—	—	—	—	—	No	No
0200112	Freeport-McMoRan Miami Inc (Miami)	2	—	—	—	—	1,119	—	No	No
0200024	Freeport-McMoRan Morenci Inc (Morenci)	—	—	—	—	—	—	—	No	No
0203131	Freeport-McMoRan Safford Inc (Safford)	4	—	—	—	—	6,677	—	No	No
0200144	Freeport-McMoRan Sierrita Inc (Sierrita)	10	—	—	—	—	32,145	—	No	No
2900159	Tyrone Mine (Tyrone)	—	—	—	—	—	—	—	No	No
0500790	Henderson Operations (Henderson)	4	—	—	—	—	3,846	—	No	No
0502256	Climax Mine (Climax)	7	—	—	—	—	9,112	—	No	No
	Freeport-McMoRan Cobre Mining Company:
2900725	Open Pit & Continental Surf Comp	—	—	—	—	—	100	—	No	No
2900731	Continental Mill Complex	—	—	—	—	—	207	—	No	No
0201656	Copper Queen Branch	—	—	—	—	—	—	—	No	No
0202579	Cyprus Tohono Corporation	—	—	—	—	—	100	—	No	No
0203262	Twin Buttes Mine	—	—	—	—	—	—	—	No	No
2902395	Chieftain 2100 Screening Plant	—	—	—	—	—	—	—	No	No
0203254	Warrior 1800 Screening Plant	—	—	—	—	—	—	—	No	No

(1) MSHA assigns an identification number to each mine or operation and may or may not assign separate identification numbers to related facilities.

(2) Amounts represent the total dollar value of proposed assessments received on or before July 31, 2015, for citations or orders issued by MSHA during the three months ended June 30, 2015. FCX is currently contesting $500 of these proposed assessments.

Pending Legal Actions. The table below provides a summary of legal actions pending before the Federal Mine Safety and Health Review Commission (the Commission) as well as the aggregate number of legal actions instituted and resolved during the three months ended June 30, 2015. The Commission is an independent adjudicative agency established by the Mine Act that provides administrative trial and appellate review of legal disputes arising under the Mine Act. These cases may involve, among other questions, challenges by operators to citations, orders and penalties they have received from MSHA, or complaints of discrimination by miners under Section 105 of the Mine Act.

The following provides additional information of the types of proceedings that may be brought before the Commission:

• Contest Proceedings - A contest proceeding may be filed by an operator to challenge the issuance of a citation or order issued by MSHA.

• Civil Penalty Proceedings - A civil penalty proceeding may be filed by an operator to challenge a civil penalty MSHA has proposed for a violation contained in a citation or order. FCX does not institute civil penalty proceedings based solely on the assessment amount of proposed penalties. Any initiated adjudications described in the table below address substantive matters of law and policy instituted on conditions that are alleged to be in violation of mandatory standards or the Mine Act.

• Discrimination Proceedings - Involves a miner's allegation that he or she has suffered adverse employment action because he or she engaged in activity protected under the Mine Act, such as making a safety complaint. Also includes temporary reinstatement proceedings involving cases in which a miner has filed a complaint with MSHA stating that he or she has suffered discrimination and the miner has lost his or her position.

• Compensation Proceedings - A compensation proceeding may be filed by miners entitled to compensation when a mine is closed by certain closure orders issued by MSHA. The purpose of the proceeding is to determine the amount of compensation, if any, due to miners idled by the orders.

• Temporary Relief - Applications for temporary relief are applications filed under section 105(b)(2) of the Mine Act for temporary relief from any modification or termination of any order.

• Appeals - An appeal may be filed by an operator to challenge judges decisions or orders to the commission, including petitions for discretionary review and review by the commission on its own motion.

	Legal Actions Pending at June 30, 2015
	Contest	Civil Penalty	Discrimination	Compensation	Temporary			Legal Actions	Legal Actions
	Proceedings	Proceedings	Proceedings	Proceedings	Relief	Appeals	Total	Instituted(2)	Resolved(3)
Mine ID(1)	(#)	(#)	(#)	(#)	(#)	(#)	(#)	(#)	(#)
0200137	—	—	—	—	—	—	—	—	—
2900708	1	9	—	—	—	—	10	—	—
0200112	—	—	—	—	—	—	—	—	—
0200024	—	2	—	—	—	—	2	—	3
0203131	—	—	—	—	—	—	—	—	—
0200144	9	—	—	—	—	—	9	—	—
2900159	—	—	—	—	—	—	—	—	—
0500790	—	—	—	—	—	—	—	—	—
0502256	1	2	—	—	—	—	3	—	—
2900725	—	—	—	—	—	—	—	—	—
2900731	—	—	—	—	—	—	—	—	—
0201656	—	—	—	—	—	—	—	—	—
0202579	—	—	—	—	—	—	—	—	—
0203262	—	—	—	—	—	—	—	—	—
2902395	—	—	—	—	—	—	—	—	—
0203254	—	—	—	—	—	—	—	—	—

(1) MSHA assigns an identification number to each mine or operation and may or may not assign separate identification numbers to related facilities. Refer to "Mine Safety Data" table for related mine or operation name.

(2) Legal actions pending at June 30, 2015, and legal actions instituted during the three month period are based on the date that a docket number was assigned to the proceeding.

(3) Legal actions resolved during the three month period are based on the date that the settlement motion resolving disputed matters is filed with the Commission and the matter is effectively closed by MSHA.

XML

Fair Value Measurement (Unaudited) (Details) - USD ($) $ in Millions		Jun. 30, 2015	Dec. 31, 2014
Derivatives:
Derivative assets		$ 194	$ 330
Derivatives:
Derivative Liability		70	99
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	25	23
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	9	11
Derivatives:
Derivative assets	[2],[5]	0	0
Total assets		34	34
Derivatives:
Derivative Liability	[2],[5]	5	6
Long-term debt, including current portion	[6]	0	0
Total liabilities		5	6
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	23	23
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	161	161
Derivatives:
Derivative assets	[2],[5]	21	15
Total assets		205	199
Derivatives:
Derivative Liability	[2],[5]	66	94
Long-term debt, including current portion	[6]	20,191	18,735
Total liabilities		20,257	18,829
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	0	0
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Derivatives:
Derivative assets	[2],[5]	174	316
Total assets		174	316
Derivatives:
Derivative Liability	[2],[5]	0	0
Long-term debt, including current portion	[6]	0	0
Total liabilities		0	0
Fair Value, Measurements, Recurring [Member] | Copper forward contracts [Member] | Fair Value, Inputs, Level 1 [Member]
Derivatives:
Derivative Liability	[2],[5]	0
Fair Value, Measurements, Recurring [Member] | Copper forward contracts [Member] | Fair Value, Inputs, Level 2 [Member]
Derivatives:
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Fair Value, Measurements, Recurring [Member] | Copper forward contracts [Member] | Fair Value, Inputs, Level 3 [Member]
Derivatives:
Derivative Liability	[2],[5]	0
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Derivatives:
Derivative Liability	[2],[5]	0	0
Fair Value, Measurements, Recurring [Member] | Embedded derivatives in provisional sales/purchases contracts [Member] | Fair Value, Inputs, Level 2 [Member]
Derivatives:
Derivative Liability	[2],[5]	65	93
Fair Value, Measurements, Recurring [Member] | Embedded derivatives in provisional sales/purchases contracts [Member] | Fair Value, Inputs, Level 3 [Member]
Derivatives:
Derivative Liability	[2],[5]	0	0
Fair Value, Measurements, Recurring [Member] | Copper futures and swap contracts [Member] | Fair Value, Inputs, Level 1 [Member]
Derivatives:
Derivative Liability	[2],[5]	5	6
Fair Value, Measurements, Recurring [Member] | Copper futures and swap contracts [Member] | Fair Value, Inputs, Level 2 [Member]
Derivatives:
Derivative Liability	[2],[5]	0	1
Fair Value, Measurements, Recurring [Member] | Copper futures and swap contracts [Member] | Fair Value, Inputs, Level 3 [Member]
Derivatives:
Derivative Liability	[2],[5]	0	0
Fair Value, Measurements, Recurring [Member] | U.S. core fixed income fund [Member] | Fair Value, Inputs, Level 1 [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	0	0
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Legally restricted funds	[1],[2],[3],[4]	0	0
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Investment securities	[1],[2]	23	23
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Legally restricted funds	[1],[2],[3],[4]	51	52
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Investment securities (current and long-term):
Investment securities	[1],[2]	0	0
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Legally restricted funds	[1],[2],[3],[4]	0	0
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Investment securities (current and long-term):
Investment securities	[1],[2]	22	20
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	9	11
Fair Value, Measurements, Recurring [Member] | Money market funds [Member] | Fair Value, Inputs, Level 2 [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	0	0
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Money market funds [Member] | Fair Value, Inputs, Level 3 [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	0	0
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Collateralized mortgage-backed securities [Member] | Fair Value, Inputs, Level 1 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Collateralized mortgage-backed securities [Member] | Fair Value, Inputs, Level 2 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	8	6
Fair Value, Measurements, Recurring [Member] | Collateralized mortgage-backed securities [Member] | Fair Value, Inputs, Level 3 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Equity securities [Member] | Fair Value, Inputs, Level 1 [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	3	3
Fair Value, Measurements, Recurring [Member] | Equity securities [Member] | Fair Value, Inputs, Level 2 [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	0	0
Fair Value, Measurements, Recurring [Member] | Equity securities [Member] | Fair Value, Inputs, Level 3 [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	0	0
Fair Value, Measurements, Recurring [Member] | Government bonds and notes [Member] | Fair Value, Inputs, Level 1 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Government bonds and notes [Member] | Fair Value, Inputs, Level 2 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	35	39
Fair Value, Measurements, Recurring [Member] | Government bonds and notes [Member] | Fair Value, Inputs, Level 3 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Government mortgage-backed securities [Member] | Fair Value, Inputs, Level 1 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Government mortgage-backed securities [Member] | Fair Value, Inputs, Level 2 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	24	19
Fair Value, Measurements, Recurring [Member] | Government mortgage-backed securities [Member] | Fair Value, Inputs, Level 3 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Corporate bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Corporate bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	28	27
Fair Value, Measurements, Recurring [Member] | Corporate bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Asset-backed securities [Member] | Fair Value, Inputs, Level 1 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Asset-backed securities [Member] | Fair Value, Inputs, Level 2 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	14	17
Fair Value, Measurements, Recurring [Member] | Asset-backed securities [Member] | Fair Value, Inputs, Level 3 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Municipal bonds [Member] | Fair Value, Inputs, Level 1 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Municipal bonds [Member] | Fair Value, Inputs, Level 2 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	1	1
Fair Value, Measurements, Recurring [Member] | Municipal bonds [Member] | Fair Value, Inputs, Level 3 [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	0	0
Fair Value, Measurements, Recurring [Member] | Embedded derivatives in provisional sales/purchases contracts [Member] | Fair Value, Inputs, Level 1 [Member]
Derivatives:
Derivative assets	[2],[5]	0	0
Fair Value, Measurements, Recurring [Member] | Embedded derivatives in provisional sales/purchases contracts [Member] | Fair Value, Inputs, Level 2 [Member]
Derivatives:
Derivative assets	[2],[5]	21	15
Fair Value, Measurements, Recurring [Member] | Embedded derivatives in provisional sales/purchases contracts [Member] | Fair Value, Inputs, Level 3 [Member]
Derivatives:
Derivative assets	[2],[5]	0	0
Fair Value, Measurements, Recurring [Member] | Crude oil options [Member] | Fair Value, Inputs, Level 1 [Member]
Derivatives:
Derivative assets	[2],[5]	0	0
Fair Value, Measurements, Recurring [Member] | Crude oil options [Member] | Fair Value, Inputs, Level 2 [Member]
Derivatives:
Derivative assets	[2],[5]	0	0
Fair Value, Measurements, Recurring [Member] | Crude oil options [Member] | Fair Value, Inputs, Level 3 [Member]
Derivatives:
Derivative assets	[2],[5]	174	316
Deferred Option Premiums and Accrued Interest [Member]
Derivatives:
Derivative assets		106	210
Other Current Assets [Member]
Derivatives:
Derivative assets		174	316
Derivatives:
Derivative Liability		0	0
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	48	46
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	170	172
Derivatives:
Derivative assets	[2],[5]	195	331
Derivatives:
Derivative Liability	[2],[5]	71	100
Long-term debt, including current portion	[6]	20,902	18,849
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Copper forward contracts [Member]
Derivatives:
Derivative Liability	[2],[5]	1
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Embedded derivatives in provisional sales/purchases contracts [Member]
Derivatives:
Derivative Liability	[2],[5]	65	93
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Copper futures and swap contracts [Member]
Derivatives:
Derivative Liability	[2],[5]	5	7
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | U.S. core fixed income fund [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	23	23
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	51	52
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Money market funds [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	22	20
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	9	11
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Collateralized mortgage-backed securities [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	8	6
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Equity securities [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	3	3
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Government bonds and notes [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	35	39
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Government mortgage-backed securities [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	24	19
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Corporate bonds [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	28	27
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Asset-backed securities [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	14	17
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Municipal bonds [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	1	1
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Embedded derivatives in provisional sales/purchases contracts [Member]
Derivatives:
Derivative assets	[2],[5]	21	15
Reported Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Crude oil options [Member]
Derivatives:
Derivative assets	[2],[5]	174	316
Reported Value Measurement [Member] | Other Assets [Member] | Fair Value, Measurements, Recurring [Member] | Time Deposits [Member]
Derivatives:
Escrow Deposit Disbursements Related to Property Acquisition		117	115
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	48	46
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	170	172
Derivatives:
Derivative assets	[2],[5]	195	331
Total assets		413	549
Derivatives:
Derivative Liability	[2],[5]	71	100
Long-term debt, including current portion	[6]	20,191	18,735
Total liabilities		20,262	18,835
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Copper forward contracts [Member]
Derivatives:
Derivative Liability	[2],[5]	1
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Embedded derivatives in provisional sales/purchases contracts [Member]
Derivatives:
Derivative Liability	[2],[5]	65	93
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Copper futures and swap contracts [Member]
Derivatives:
Derivative Liability	[2],[5]	5	7
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | U.S. core fixed income fund [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	23	23
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	51	52
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Money market funds [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	22	20
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	9	11
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Collateralized mortgage-backed securities [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	8	6
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Equity securities [Member]
Investment securities (current and long-term):
Investment securities	[1],[2]	3	3
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Government bonds and notes [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	35	39
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Government mortgage-backed securities [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	24	19
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Corporate bonds [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	28	27
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Asset-backed securities [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	14	17
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Municipal bonds [Member]
Legally restricted funds (long-term):
Legally restricted funds	[1],[2],[3],[4]	1	1
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Embedded derivatives in provisional sales/purchases contracts [Member]
Derivatives:
Derivative assets	[2],[5]	21	15
Estimate of Fair Value Measurement [Member] | Fair Value, Measurements, Recurring [Member] | Crude oil options [Member]
Derivatives:
Derivative assets	[2],[5]	174	316
Reclamation Guarantee [Member] | Reported Value Measurement [Member] | Other Current Assets [Member] | Fair Value, Measurements, Recurring [Member] | Time Deposits [Member]
Investment securities (current and long-term):
Investment securities		$ 10	8
Customs Audit Assessment [Member] | Reported Value Measurement [Member] | Other Current Assets [Member] | Fair Value, Measurements, Recurring [Member] | Time Deposits [Member]
Investment securities (current and long-term):
Investment securities			$ 9

[1] Current portion included in other current assets and long-term portion included in other assets.

[2] Recorded at fair value.

[3] Excludes time deposits (which approximated fair value) included in other assets of $117 million at June 30, 2015, and $115 million at December 31, 2014, associated with an assurance bond to support PT Freeport Indonesia's (PT-FI) commitment for smelter development in Indonesia.

[4] Excludes time deposits (which approximated fair value) included in other current assets of $10 million at June 30, 2015, and $8 million at December 31, 2014, associated with a reclamation guarantee at PT-FI. Also, excludes a time deposit of $9 million at December 31, 2014, associated with a customs audit assessment.

[5] Refer to Note 7 for further discussion and balance sheet classifications. Crude oil options are net of $106 million at June 30, 2015, and $210 million at December 31, 2014, for deferred premiums and accrued interest.

[6] Recorded at cost except for debt assumed in acquisitions, which were recorded at fair value at the respective acquisition dates.

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Subsequent Events (Unaudited) (Details) - PT Freeport Indonesia [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Mar. 31, 2016	Sep. 30, 2015	Jun. 30, 2015
Subsequent Event [Line Items]
Assurance Bond, Smelter Development			$ 115
Subsequent Event [Member]
Subsequent Event [Line Items]
Progressive Export Duty on Copper Concentrates, Percent		5.00%
Expiration Date, Memorandum of Understanding with Foreign Government		Jul. 25, 2015
Export Permit Renewal Term		6 months
Expiration Date, Export Permit	Jan. 28, 2016
Effective Date, Export Permit		Jul. 29, 2015
Stage 1 [Member]
Subsequent Event [Line Items]
Progressive Export Duty on Copper Concentrates, Percent			7.50%
Stage 2 [Member]
Subsequent Event [Line Items]
Progressive Export Duty on Copper Concentrates, Percent			5.00%
Smelter Development Progress, Percent			7.50%
Stage 3 [Member]
Subsequent Event [Line Items]
Progressive Export Duty on Copper Concentrates, Percent			0.00%
Smelter Development Progress, Percent			30.00%

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Guarantor Financial Statements (Unaudited) Condensed Consolidating Statements of Cash Flows (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Cash flow from operating activities:
Net (loss) income	$ (1,799)	$ 660	$ (4,205)	$ 1,286
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	890	1,013	1,829	1,979
Impairment of oil and gas properties	2,686	0	5,790	0
Net (gains) losses on crude oil and natural gas derivative contracts			(58)	120
Net gain on early extinguishment of debt	0	(5)	0	(5)
Equity in losses (earnings) of consolidated subsidiaries			(1)	(2)
Other, net			(1,379)	(14)
Changes in working capital and other tax payments			(190)	(777)
Net cash provided by operating activities			1,786	2,587
Cash flow from investing activities:
Capital expenditures	(1,661)	(1,950)	(3,528)	(3,562)
Acquisition of Deepwater Gulf of Mexico interests			0	(925)
Intercompany loans			0	0
Dividends from (investments in) consolidated subsidiaries			0	0
Net proceeds from sale of Eagle Ford shale assets			0	3,009
Other, net			136	(363)
Net cash used in investing activities			(3,392)	(1,841)
Cash flow from financing activities:
Proceeds from debt			4,422	1,248
Repayments of debt			(2,360)	(1,611)
Intercompany loans			0	0
Cash dividends and distributions paid, and contributions received			(440)	(903)
Other, net			(14)	(7)
Net cash provided by (used in) financing activities			1,608	(1,273)
Net increase (decrease) in cash and cash equivalents			2	(527)
Cash and cash equivalents at beginning of year			464	1,985
Cash and cash equivalents at end of period	466	1,458	466	1,458
FCX Issuer [Member]
Cash flow from operating activities:
Net (loss) income	(1,851)	482	(4,325)	992
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization			2	2
Impairment of oil and gas properties			0
Net (gains) losses on crude oil and natural gas derivative contracts			0	0
Net gain on early extinguishment of debt		1		1
Equity in losses (earnings) of consolidated subsidiaries			3,524	(1,152)
Other, net			(1,431)	121
Changes in working capital and other tax payments			2,222	(164)
Net cash provided by operating activities			(8)	(200)
Cash flow from investing activities:
Capital expenditures			0	0
Acquisition of Deepwater Gulf of Mexico interests				0
Intercompany loans			(1,073)	1,318
Dividends from (investments in) consolidated subsidiaries			438	(364)
Net proceeds from sale of Eagle Ford shale assets				0
Other, net			(10)	0
Net cash used in investing activities			(645)	954
Cash flow from financing activities:
Proceeds from debt			2,735	890
Repayments of debt			(1,690)	(990)
Intercompany loans			0	0
Cash dividends and distributions paid, and contributions received			(380)	(653)
Other, net			(12)	(1)
Net cash provided by (used in) financing activities			653	(754)
Net increase (decrease) in cash and cash equivalents			0	0
Cash and cash equivalents at beginning of year			0	0
Cash and cash equivalents at end of period	0	0	0	0
FM O&G LLC Guarantor [Member]
Cash flow from operating activities:
Net (loss) income	(2,596)	196	(5,680)	360
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization			223	545
Impairment of oil and gas properties	990		2,052
Net (gains) losses on crude oil and natural gas derivative contracts			(58)	120
Net gain on early extinguishment of debt		(6)		(6)
Equity in losses (earnings) of consolidated subsidiaries			4,279	(256)
Other, net			9	(12)
Changes in working capital and other tax payments			(550)	(2,165)
Net cash provided by operating activities			275	(1,414)
Cash flow from investing activities:
Capital expenditures			(734)	(897)
Acquisition of Deepwater Gulf of Mexico interests				0
Intercompany loans			(794)	1,629
Dividends from (investments in) consolidated subsidiaries			(31)	(96)
Net proceeds from sale of Eagle Ford shale assets				3,009
Other, net			(1)	(381)
Net cash used in investing activities			(1,560)	3,264
Cash flow from financing activities:
Proceeds from debt			0	0
Repayments of debt			0	(224)
Intercompany loans			1,321	(170)
Cash dividends and distributions paid, and contributions received			0	(1,453)
Other, net			(37)	(2)
Net cash provided by (used in) financing activities			1,284	(1,849)
Net increase (decrease) in cash and cash equivalents			(1)	1
Cash and cash equivalents at beginning of year			1	0
Cash and cash equivalents at end of period	0	1	0	1
Non-Guarantor Subsidiaries [Member]
Cash flow from operating activities:
Net (loss) income	(3,819)	804	(8,518)	1,674
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization			1,638	1,440
Impairment of oil and gas properties	1,674		3,717
Net (gains) losses on crude oil and natural gas derivative contracts			0	0
Net gain on early extinguishment of debt		0		0
Equity in losses (earnings) of consolidated subsidiaries			6,502	39
Other, net			43	(123)
Changes in working capital and other tax payments			(1,870)	1,552
Net cash provided by operating activities			1,512	4,582
Cash flow from investing activities:
Capital expenditures			(2,787)	(2,665)
Acquisition of Deepwater Gulf of Mexico interests				(925)
Intercompany loans			0	0
Dividends from (investments in) consolidated subsidiaries			74	1,079
Net proceeds from sale of Eagle Ford shale assets				0
Other, net			137	18
Net cash used in investing activities			(2,576)	(2,493)
Cash flow from financing activities:
Proceeds from debt			1,687	358
Repayments of debt			(670)	(397)
Intercompany loans			546	(2,777)
Cash dividends and distributions paid, and contributions received			(481)	203
Other, net			(15)	(4)
Net cash provided by (used in) financing activities			1,067	(2,617)
Net increase (decrease) in cash and cash equivalents			3	(528)
Cash and cash equivalents at beginning of year			463	1,985
Cash and cash equivalents at end of period	466	1,457	466	1,457
Eliminations [Member]
Cash flow from operating activities:
Net (loss) income	6,467	(822)	14,318	(1,740)
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization			(34)	(8)
Impairment of oil and gas properties			21
Net (gains) losses on crude oil and natural gas derivative contracts			0	0
Net gain on early extinguishment of debt		0		0
Equity in losses (earnings) of consolidated subsidiaries			(14,306)	1,367
Other, net			0	0
Changes in working capital and other tax payments			8	0
Net cash provided by operating activities			7	(381)
Cash flow from investing activities:
Capital expenditures			(7)	0
Acquisition of Deepwater Gulf of Mexico interests				0
Intercompany loans			1,867	(2,947)
Dividends from (investments in) consolidated subsidiaries			(481)	(619)
Net proceeds from sale of Eagle Ford shale assets				0
Other, net			10	0
Net cash used in investing activities			1,389	(3,566)
Cash flow from financing activities:
Proceeds from debt			0	0
Repayments of debt			0	0
Intercompany loans			(1,867)	2,947
Cash dividends and distributions paid, and contributions received			421	1,000
Other, net			50	0
Net cash provided by (used in) financing activities			(1,396)	3,947
Net increase (decrease) in cash and cash equivalents			0	0
Cash and cash equivalents at beginning of year			0	0
Cash and cash equivalents at end of period	$ 0	$ 0	$ 0	$ 0

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Debt and Equity Transactions (Unaudited) Interest, Dividends and Maturities (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Capitalized Interest [Line Items]
Interest costs incurred	$ 215	$ 225	$ 425	$ 449
Dividends Payable, Date Declared			Jun. 24, 2015
Dividends declared per share of common stock	$ 0.1605	$ 0.3125	$ 0.2105	$ 0.625
Authorized Quarterly Rate Of Common Stock Dividend	$ 0.0500
Dividends Payable, Date to be Paid	Aug. 03, 2015
Dividends Payable, Date of Record	Jul. 15, 2015
Special Dividend, Per Share	$ 0.1105
Property, Plant, Equipment and Mining Development Costs, Net [Member]
Capitalized Interest [Line Items]
Interest costs capitalized	$ 47	$ 39	$ 92	$ 79
Oil and Gas Properties Not Subject to Amortization [Member]
Capitalized Interest [Line Items]
Interest costs capitalized	$ 19	$ 22	$ 38	$ 45

XML

Business Segments (Unaudited) (Tables)

6 Months Ended

Jun. 30, 2015

Segment Reporting [Abstract]

Schedule of Segment Reporting Information By Segment

Financial Information by Business Segments

(In millions)	Mining Operations
	North America Copper Mines							South America							Indonesia				Africa
																											Atlantic			Other										Corporate,
																					Molyb-						Copper			Mining						U.S.				Other
			Other					Cerro			Other										denum				Rod &		Smelting			& Elimi-				Total		Oil & Gas				& Elimi-			FCX
	Morenci		Mines			Total		Verde			Minesa		Total		Grasberg				Tenke		Mines				Refining		& Refining			nations				Mining		Operationsb				nations			Total
Three Months Ended June 30, 2015
Revenues:
Unaffiliated customers	$	180	$	92		$	272	$	195		$	221	$	416	$	792		c	$	310	$	—			$	1,089	$	495		$	305		d	$	3,679	$	569		e	$	—		$	4,248
Intersegment	427		706			1,133		37			—		37		(2		)	f	41		102				8		5			(1,324		)		—		—				—			—
Production and delivery	386		576		g	962		165			150		315		455				190		84			g	1,088		468			(997		)	g	2,565		281				2			2,848
Depreciation, depletion and amortization	55		84			139		40			32		72		78				57		25				3		9			19				402		485				3			890
Impairment of oil and gas properties	—		—			—		—			—		—		—				—		—				—		—			—				—		2,686				—			2,686
Selling, general and administrative expenses	—		2			2		—			1		1		25				3		—				—		4			5				40		49				62			151
Mining exploration and research expenses	—		2			2		—			—		—		—				—		—				—		—			34				36		—				—			36
Environmental obligations and shutdown costs	—		—			—		—			—		—		—				—		—				—		—			11				11		—				—			11
Operating income (loss)	166		134			300		27			38		65		232				101		(7		)		6		19			(91		)		625		(2,932		)		(67		)	(2,374		)
Interest expense, net	—		1			1		—			—		—		—				—		—				—		2			39				42		41				66			149
Provision for (benefit from) income taxes	—		—			—		(5		)	11		6		95				27		—				—		—			—				128		—				(815		)	(687		)
Total assets at June 30, 2015	3,806		5,582			9,388		8,567			1,935		10,502		8,959				5,125		2,052				286		786			1,336				38,434		15,393				181			54,008
Capital expenditures	79		28			107		444			13		457		213				58		4				—		4			11				854		777				30			1,661
Three Months Ended June 30, 2014
Revenues:
Unaffiliated customers	$	52	$	55		$	107	$	421		$	524	$	945	$	523		c	$	386	$	—			$	1,234	$	623		$	468		d	$	4,286	$	1,236		e	$	—		$	5,522
Intersegment	474		888			1,362		23			63		86		—				32		170				8		6			(1,664		)		—		—				—			—
Production and delivery	312		558			870		195			335		530		511				198		81				1,233		618			(1,287		)		2,754		329				(1		)	3,082
Depreciation, depletion and amortization	43		85			128		43			52		95		54				63		24				3		10			17				394		616				3			1,013
Selling, general and administrative expenses	1		—			1		1			1		2		25				3		—				—		5			6				42		59				63			164
Mining exploration and research expenses	—		2			2		—			—		—		—				—		—				—		—			32				34		—				—			34
Environmental obligations and shutdown costs	—		—			—		—			—		—		—				—		—				—		—			76				76		—				—			76
Operating income (loss)	170		298			468		205			199		404		(67		)		154		65				6		(4		)	(40		)		986		232				(65		)	1,153
Interest expense, net	—		1			1		—			—		—		—				—		—				—		3			18				22		74				68			164
Provision for (benefit from) income taxes	—		—			—		73			67		140		(33		)		33		—				—		—			—				140		—				188			328
Total assets at June 30, 2014	3,675		5,822			9,497		6,876			3,791		10,667		7,972				4,952		2,095				299		882			1,127				37,491		25,293				1,119			63,903
Capital expenditures	289		35			324		391			25		416		243				29		14				1		5			17				1,049		903				(2		)	1,950

a. Second-quarter 2014 includes the results of the Candelaria and Ojos del Salado mining operations, which were sold in November 2014.

b. Second-quarter 2014 includes the results from Eagle Ford, which was sold in June 2014.

c. Includes PT-FI’s sales to PT Smelting totaling $293 million in second-quarter2015 and $540 million in second-quarter2014.

d. Includes revenues from FCX's molybdenum sales company, which includes sales of molybdenum produced by the Molybdenum mines and by certain of the North and South America copper mines.

e. Includes net mark-to-market gains (losses) associated with crude oil and natural gas derivative contracts totaling $6 million in second-quarter2015 and $(70) million in second-quarter2014.

f. Amounts include net reductions for provisional pricing adjustments to prior period open sales. There were no intersegment sales from Grasberg in second-quarter 2015.

g. Includes LCM inventory adjustments totaling $11 million at other North America copper mines, $3 million at Molybdenum mines and $45 million at other mining & eliminations (see Note 4).

(In millions)	Mining Operations
	North America Copper Mines									South America								Indonesia				Africa
																														Atlantic			Other											Corporate,
																								Molyb-						Copper			Mining							U.S.				Other
			Other							Cerro		Other												denum				Rod &		Smelting			& Elimi-				Total			Oil & Gas				& Elimi-			FCX
	Morenci		Mines				Total			Verde		Minesa				Total		Grasberg				Tenke		Mines				Refining		& Refining			nations				Mining			Operationsb				nations			Total
Six Months Ended June 30, 2015
Revenues:
Unaffiliated customers	$	286	$	207			$	493		$	443	$	452			$	895	$	1,413		c	$	692	$	—			$	2,151	$	1,035		$	653		d	$	7,332		$	1,069		e	$	—		$	8,401
Intersegment	877		1,370				2,247			51		(7		)	f	44		(16		)	f	69		215				15		11			(2,585		)		—			—				—			—
Production and delivery	760		1,145			g	1,905			363		297				660		894				425		167			g	2,151		987			(1,998		)	g	5,191			564				5			5,760
Depreciation, depletion and amortization	106		166				272			77		70				147		148				130		51				5		19			35				807			1,015				7			1,829
Impairment of oil and gas properties	—		—				—			—		—				—		—				—		—				—		—			—				—			5,790				—			5,790
Selling, general and administrative expenses	1		2				3			1		1				2		50				6		—				—		9			11				81			103				121			305
Mining exploration and research expenses	—		5				5			—		—				—		—				—		—				—		—			64				69			—				—			69
Environmental obligations and shutdown costs	—		—				—			—		—				—		—				—		—				—		—			24				24			—				—			24
Net gain on sales of assets	—		(39		)		(39		)	—		—				—		—				—		—				—		—			—				(39		)	—				—			(39		)
Operating income (loss)	296		298				594			53		77				130		305				200		(3		)		10		31			(68		)		1,199			(6,403		)		(133		)	(5,337		)
Interest expense, net	1		1				2			1		—				1		—				—		—				—		5			79				87			78				130			295
Provision for (benefit from) income taxes	—		—				—			—		30				30		124				53		—				—		—			—				207			—				(1,589		)	(1,382		)
Capital expenditures	163		51				214			875		27				902		438				97		7				1		8			27				1,694			1,795				39			3,528
Six Months Ended June 30, 2014
Revenues:
Unaffiliated customers	$	75	$	116			$	191		$	701	$	946			$	1,647	$	985		c	$	692	$	—			$	2,380	$	1,211		$	904		d	$	8,010		$	2,497		e	$	—		$	10,507
Intersegment	918		1,646				2,564			87		195				282		8				53		296				16		11			(3,230		)		—			—				—			—
Production and delivery	595		1,061				1,656			360		646				1,006		894				350		157				2,381		1,206			(2,470		)		5,180			640				(1		)	5,819
Depreciation, depletion and amortization	77		158				235			79		103				182		102				114		46				5		20			36				740			1,232				7			1,979
Selling, general and administrative expenses	1		1				2			2		2				4		46				6		—				—		9			13				80			116				103			299
Mining exploration and research expenses	—		4				4			—		—				—		—				—		—				—		—			60				64			—				—			64
Environmental obligations and shutdown costs	—		—				—			—		—				—		—				—		—				—		—			82				82			—				—			82
Operating income (loss)	320		538				858			347		390				737		(49		)		275		93				10		(13		)	(47		)		1,864			509				(109		)	2,264
Interest expense, net	1		1				2			—		—				—		—				—		—				—		7			36				45			150				130			325
Provision for (benefit from) income taxes	—		—				—			130		137				267		(15		)		57		—				—		—			—				309			—				376			685
Capital expenditures	533		94				627			791		48				839		479				60		33				2		6			27				2,073			1,484				5			3,562

a. The first six months of 2014 include the results of the Candelaria and Ojos del Salado mining operations, which were sold in November 2014.

b. The first six months of 2014 include the results from Eagle Ford, which was sold in June 2014.

c. Includes PT-FI’s sales to PT Smelting totaling $643 million for the first six months of 2015 and $913 million for the first six months of 2014.

d. Includes revenues from FCX's molybdenum sales company, which includes sales of molybdenum produced by the Molybdenum mines and by certain of the North and South America copper mines.

e. Includes net mark-to-market gains (losses) associated with crude oil and natural gas derivative contracts totaling $58 million for the first six months2015 and $(120) million for the first six months of 2014.

f. Amounts include net reductions for provisional pricing adjustments to prior period open sales. There were no intersegment sales from El Abra or Grasberg for the first six months of 2015.

g. Includes LCM inventory adjustments totaling $11 million at other North America copper mines, $3 million at Molybdenum mines and $49 million at other mining & eliminations (see Note 4).

XML

Business Segments (Unaudited) (Details) - USD ($) $ in Millions		3 Months Ended				6 Months Ended
		Jun. 30, 2015		Jun. 30, 2014		Jun. 30, 2015		Jun. 30, 2014		Dec. 31, 2014
Revenues:
Unaffiliated customers		$ 4,248		$ 5,522		$ 8,401		$ 10,507
Intersegment		0		0		0		0
Production and delivery		2,848		3,082		5,760		5,819
Depreciation, depletion and amortization		890		1,013		1,829		1,979
Impairment of oil and gas properties		2,686		0		5,790		0
Selling, general and administrative expenses		151		164		305		299
Mining exploration and research expenses		36		34		69		64
Environmental obligations and shutdown costs		11		76		24		82
Net gain on sale of assets		0		0		(39)		0
Operating income (loss)		(2,374)		1,153		(5,337)		2,264
Interest expense, net		149		164		295		325
Provision for (benefit from) income taxes		(687)		328		(1,382)		685
Total Assets		54,008		63,903		54,008		63,903		$ 58,674
Capital expenditures		1,661		1,950		3,528		3,562
Lower of cost or market inventory adjustments		(59)				(63)		0
Mining Operations [Member]
Revenues:
Unaffiliated customers		3,679		4,286		7,332		8,010
Intersegment		0		0		0		0
Production and delivery		2,565		2,754		5,191		5,180
Depreciation, depletion and amortization		402		394		807		740
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		40		42		81		80
Mining exploration and research expenses		36		34		69		64
Environmental obligations and shutdown costs		11		76		24		82
Net gain on sale of assets						(39)
Operating income (loss)		625		986		1,199		1,864
Interest expense, net		42		22		87		45
Provision for (benefit from) income taxes		128		140		207		309
Total Assets		38,434		37,491		38,434		37,491
Capital expenditures		854		1,049		1,694		2,073
North America Copper Mines [Member]
Revenues:
Unaffiliated customers		272		107		493		191
Intersegment		1,133		1,362		2,247		2,564
Production and delivery		962		870		1,905		1,656
Depreciation, depletion and amortization		139		128		272		235
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		2		1		3		2
Mining exploration and research expenses		2		2		5		4
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						(39)
Operating income (loss)		300		468		594		858
Interest expense, net		1		1		2		2
Provision for (benefit from) income taxes		0		0		0		0
Total Assets		9,388		9,497		9,388		9,497
Capital expenditures		107		324		214		627
Morenci [Member]
Revenues:
Unaffiliated customers		180		52		286		75
Intersegment		427		474		877		918
Production and delivery		386		312		760		595
Depreciation, depletion and amortization		55		43		106		77
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		0		1		1		1
Mining exploration and research expenses		0		0		0		0
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						0
Operating income (loss)		166		170		296		320
Interest expense, net		0		0		1		1
Provision for (benefit from) income taxes		0		0		0		0
Total Assets		3,806		3,675		3,806		3,675
Capital expenditures		79		289		163		533
Other North America Copper Mines [Member]
Revenues:
Unaffiliated customers		92		55		207		116
Intersegment		706		888		1,370		1,646
Production and delivery		576	[1]	558		1,145	[2]	1,061
Depreciation, depletion and amortization		84		85		166		158
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		2		0		2		1
Mining exploration and research expenses		2		2		5		4
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						(39)
Operating income (loss)		134		298		298		538
Interest expense, net		1		1		1		1
Provision for (benefit from) income taxes		0		0		0		0
Total Assets		5,582		5,822		5,582		5,822
Capital expenditures		28		35		51		94
Lower of cost or market inventory adjustments		(11)				(11)
South America Mines [Member]
Revenues:
Unaffiliated customers		416		945		895		1,647
Intersegment		37		86		44		282
Production and delivery		315		530		660		1,006
Depreciation, depletion and amortization		72		95		147		182
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		1		2		2		4
Mining exploration and research expenses		0		0		0		0
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						0
Operating income (loss)		65		404		130		737
Interest expense, net		0		0		1		0
Provision for (benefit from) income taxes		6		140		30		267
Total Assets		10,502		10,667		10,502		10,667
Capital expenditures		457		416		902		839
Cerro Verde [Member]
Revenues:
Unaffiliated customers		195		421		443		701
Intersegment		37		23		51		87
Production and delivery		165		195		363		360
Depreciation, depletion and amortization		40		43		77		79
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		0		1		1		2
Mining exploration and research expenses		0		0		0		0
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						0
Operating income (loss)		27		205		53		347
Interest expense, net		0		0		1		0
Provision for (benefit from) income taxes		(5)		73		0		130
Total Assets		8,567		6,876		8,567		6,876
Capital expenditures		444		391		875		791
Other South America Mines [Member]
Revenues:
Unaffiliated customers		221	[3]	524	[3]	452	[4]	946	[4]
Intersegment		0	[3]	63	[3]	(7)	[4],[5]	195	[4]
Production and delivery		150	[3]	335	[3]	297	[4]	646	[4]
Depreciation, depletion and amortization		32	[3]	52	[3]	70	[4]	103	[4]
Impairment of oil and gas properties		0	[3]			0	[4]
Selling, general and administrative expenses		1	[3]	1	[3]	1	[4]	2	[4]
Mining exploration and research expenses		0	[3]	0	[3]	0	[4]	0	[4]
Environmental obligations and shutdown costs		0	[3]	0	[3]	0	[4]	0	[4]
Net gain on sale of assets	[4]					0
Operating income (loss)		38	[3]	199	[3]	77	[4]	390	[4]
Interest expense, net		0	[3]	0	[3]	0	[4]	0	[4]
Provision for (benefit from) income taxes		11	[3]	67	[3]	30	[4]	137	[4]
Total Assets	[3]	1,935		3,791		1,935		3,791
Capital expenditures		13	[3]	25	[3]	27	[4]	48	[4]
Indonesia - Grasberg [Member]
Revenues:
Unaffiliated customers		792	[6]	523	[6]	1,413	[7]	985	[7]
Intersegment		(2)	[8]	0		(16)	[5]	8
Production and delivery		455		511		894		894
Depreciation, depletion and amortization		78		54		148		102
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		25		25		50		46
Mining exploration and research expenses		0		0		0		0
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						0
Operating income (loss)		232		(67)		305		(49)
Interest expense, net		0		0		0		0
Provision for (benefit from) income taxes		95		(33)		124		(15)
Total Assets		8,959		7,972		8,959		7,972
Capital expenditures		213		243		438		479
Africa - Tenke [Member]
Revenues:
Unaffiliated customers		310		386		692		692
Intersegment		41		32		69		53
Production and delivery		190		198		425		350
Depreciation, depletion and amortization		57		63		130		114
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		3		3		6		6
Mining exploration and research expenses		0		0		0		0
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						0
Operating income (loss)		101		154		200		275
Interest expense, net		0		0		0		0
Provision for (benefit from) income taxes		27		33		53		57
Total Assets		5,125		4,952		5,125		4,952
Capital expenditures		58		29		97		60
Molybdenum mines [Member]
Revenues:
Unaffiliated customers		0		0		0		0
Intersegment		102		170		215		296
Production and delivery		84	[1]	81		167	[2]	157
Depreciation, depletion and amortization		25		24		51		46
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		0		0		0		0
Mining exploration and research expenses		0		0		0		0
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						0
Operating income (loss)		(7)		65		(3)		93
Interest expense, net		0		0		0		0
Provision for (benefit from) income taxes		0		0		0		0
Total Assets		2,052		2,095		2,052		2,095
Capital expenditures		4		14		7		33
Lower of cost or market inventory adjustments		(3)				(3)
Rod & Refining [Member]
Revenues:
Unaffiliated customers		1,089		1,234		2,151		2,380
Intersegment		8		8		15		16
Production and delivery		1,088		1,233		2,151		2,381
Depreciation, depletion and amortization		3		3		5		5
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		0		0		0		0
Mining exploration and research expenses		0		0		0		0
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						0
Operating income (loss)		6		6		10		10
Interest expense, net		0		0		0		0
Provision for (benefit from) income taxes		0		0		0		0
Total Assets		286		299		286		299
Capital expenditures		0		1		1		2
Atlantic Copper Smelting & Refining [Member]
Revenues:
Unaffiliated customers		495		623		1,035		1,211
Intersegment		5		6		11		11
Production and delivery		468		618		987		1,206
Depreciation, depletion and amortization		9		10		19		20
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		4		5		9		9
Mining exploration and research expenses		0		0		0		0
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						0
Operating income (loss)		19		(4)		31		(13)
Interest expense, net		2		3		5		7
Provision for (benefit from) income taxes		0		0		0		0
Total Assets		786		882		786		882
Capital expenditures		4		5		8		6
Other Mining & Eliminations [Member]
Revenues:
Unaffiliated customers	[9]	305		468		653		904
Intersegment		(1,324)		(1,664)		(2,585)		(3,230)
Production and delivery		(997)	[1]	(1,287)		(1,998)	[2]	(2,470)
Depreciation, depletion and amortization		19		17		35		36
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		5		6		11		13
Mining exploration and research expenses		34		32		64		60
Environmental obligations and shutdown costs		11		76		24		82
Net gain on sale of assets						0
Operating income (loss)		(91)		(40)		(68)		(47)
Interest expense, net		39		18		79		36
Provision for (benefit from) income taxes		0		0		0		0
Total Assets		1,336		1,127		1,336		1,127
Capital expenditures		11		17		27		27
Lower of cost or market inventory adjustments		(45)				(49)
U.S. Oil & Gas Operations [Member]
Revenues:
Unaffiliated customers		569	[10],[11]	1,236	[10],[11]	1,069	[12],[13]	2,497	[12],[13]
Intersegment		0	[11]	0	[11]	0	[13]	0	[13]
Production and delivery		281	[11]	329	[11]	564	[13]	640	[13]
Depreciation, depletion and amortization		485	[11]	616	[11]	1,015	[13]	1,232	[13]
Impairment of oil and gas properties		2,686	[11]			5,790	[13]
Selling, general and administrative expenses		49	[11]	59	[11]	103	[13]	116	[13]
Mining exploration and research expenses		0	[11]	0	[11]	0	[13]	0	[13]
Environmental obligations and shutdown costs		0	[11]	0	[11]	0	[13]	0	[13]
Net gain on sale of assets	[13]					0
Operating income (loss)		(2,932)	[11]	232	[11]	(6,403)	[13]	509	[13]
Interest expense, net		41	[11]	74	[11]	78	[13]	150	[13]
Provision for (benefit from) income taxes		0	[11]	0	[11]	0	[13]	0	[13]
Total Assets	[11]	15,393		25,293		15,393		25,293
Capital expenditures		777	[11]	903	[11]	1,795	[13]	1,484	[13]
Corporate, Other & Eliminations [Member]
Revenues:
Unaffiliated customers		0		0		0		0
Intersegment		0		0		0		0
Production and delivery		2		(1)		5		(1)
Depreciation, depletion and amortization		3		3		7		7
Impairment of oil and gas properties		0				0
Selling, general and administrative expenses		62		63		121		103
Mining exploration and research expenses		0		0		0		0
Environmental obligations and shutdown costs		0		0		0		0
Net gain on sale of assets						0
Operating income (loss)		(67)		(65)		(133)		(109)
Interest expense, net		66		68		130		130
Provision for (benefit from) income taxes		(815)		188		(1,589)		376
Total Assets		181		1,119		181		1,119
Capital expenditures		30		(2)		39		5
Crude oil and natural gas swaps [Member]
Revenues:
Net mark-to-market gains (losses) on derivative contracts		6		(70)		$ 58		(120)
Pt Smelting [Member]
Segment Reporting Information [Line Items]
Deferred Intercompany Profit, Percentage						25.00%
Revenues:
Revenues		$ 293		$ 540		$ 643		$ 913
Equity Method Investment, Ownership Percentage		25.00%				25.00%

[1] Includes LCM inventory adjustments totaling $11 million at other North America copper mines, $3 million at Molybdenum mines and $45 million at other mining & eliminations (see Note 4).

[2] Includes LCM inventory adjustments totaling $11 million at other North America copper mines, $3 million at Molybdenum mines and $49 million at other mining & eliminations (see Note 4).

[3] Second-quarter 2014 includes the results of the Candelaria and Ojos del Salado mining operations, which were sold in November 2014.

[4] The first six months of 2014 include the results of the Candelaria and Ojos del Salado mining operations, which were sold in November 2014.

[5] Amounts include net reductions for provisional pricing adjustments to prior period open sales. There were no intersegment sales from El Abra or Grasberg for the first six months of 2015.

[6] Includes PT-FI’s sales to PT Smelting totaling $293 million in second-quarter 2015 and $540 million in second-quarter 2014.

[7] Includes PT-FI’s sales to PT Smelting totaling $643 million for the first six months of 2015 and $913 million for the first six months of 2014.

[8] Amounts include net reductions for provisional pricing adjustments to prior period open sales. There were no intersegment sales from Grasberg in second-quarter 2015.

[9] Includes revenues from FCX's molybdenum sales company, which includes sales of molybdenum produced by the Molybdenum mines and by certain of the North and South America copper mines.

[10] Includes net mark-to-market gains (losses) associated with crude oil and natural gas derivative contracts totaling $6 million in second-quarter 2015 and $(70) million in second-quarter 2014.

[11] Second-quarter 2014 includes the results from Eagle Ford, which was sold in June 2014.

[12] Includes net mark-to-market gains (losses) associated with crude oil and natural gas derivative contracts totaling $58 million for the first six months 2015 and $(120) million for the first six months of 2014.

[13] The first six months of 2014 include the results from Eagle Ford, which was sold in June 2014.

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Financial Instruments (Unaudited) Unsettled Derivatives (Details) - USD ($) $ in Millions		Jun. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Derivative Asset		$ 194	$ 330
Derivative Liability		70	99
Paid to brokers associated with margin requirements		9	10
Trade Accounts Receivable [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset		3	5
Derivative Liability		53	56
Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset		174	316
Derivative Liability		0	0
Accounts Payable and Accrued Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset		17	9
Derivative Liability		17	43
Commodity Contract [Member] | Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Asset position		195	331
Liability position		71	100
Derivative Asset, Fair Value, Gross Liability		1	1
Derivative Liability, Fair Value, Gross Asset		1	1
Derivative Asset		194	330
Derivative Liability		70	99
Commodity Contract [Member] | Copper Derivatives [Member] | Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Asset position		0	0
Liability position		6	7
Derivative Asset, Fair Value, Gross Liability		0	0
Derivative Liability, Fair Value, Gross Asset		0	0
Derivative Asset		0	0
Derivative Liability		6	7
Commodity Contract [Member] | Copper futures and swap contracts [Member] | Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Liability position	[1]	5	7
Commodity Contract [Member] | Copper forward contracts [Member] | Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Liability position		1	0
Commodity Contract [Member] | Embedded derivatives in provisional sales/purchases contracts [Member] | Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Asset position		21	15
Liability position		65	93
Derivative Asset, Fair Value, Gross Liability		1	1
Derivative Liability, Fair Value, Gross Asset		1	1
Derivative Asset		20	14
Derivative Liability		64	92
Commodity Contract [Member] | Crude Oil and Natural Gas Derivatives [Member] | Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Asset position		174	316
Liability position		0	0
Derivative Asset		174	316
Derivative Liability		0	0
Commodity Contract [Member] | Crude Oil Options [Member] | Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Asset position	[2]	174	316
Deferred Option Premiums and Accrued Interest [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset		$ 106	$ 210

[1] FCX paid $9 million to brokers at June 30, 2015, and $10 million at December 31, 2014, for margin requirements (recorded in other current assets).

[2] Amounts are net of $106 million at June 30, 2015, and $210 million at December 31, 2014, for deferred premiums and accrued interest.

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New Accounting Standard (Unaudited) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
New Accounting Standards [Abstract]
Unamortized Debt Issuance Expense	$ 116	$ 121

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Earnings Per Share (Unaudited)

6 Months Ended

Jun. 30, 2015

Earnings Per Share [Abstract]

Earnings Per Share

EARNINGS PER SHARE

FCX’s basic net (loss) income per share of common stock was computed by dividing net (loss) income attributable to common stockholders by the weighted-average shares of common stock outstanding during the period. Diluted net income per share of common stock was computed using the most dilutive of (a) the two-class method or (b) the treasury stock method. Under the two-class method, net income is allocated to each class of common stock and participating securities as if all of the earnings for the period had been distributed. FCX’s participating securities consist of vested restricted stock units (RSUs) for which the underlying common shares are not yet issued and entitle holders to non-forfeitable dividends.

A reconciliation of net (loss) income and weighted-average shares of common stock outstanding for purposes of calculating basic and diluted net (loss) income per share follows (in millions, except per share amounts):

	Three Months Ended								Six Months Ended
	June 30,								June 30,
	2015				2014				2015				2014
Net (loss) income	$	(1,799	)		$	660			$	(4,205	)		$	1,286
Net income attributable to noncontrolling interests	(42		)		(168		)		(100		)		(274		)
Preferred dividends on redeemable noncontrolling interest	(10		)		(10		)		(20		)		(20		)
Undistributed earnings allocable to participating securities	(3		)		(2		)		(3		)		(3		)
Net (loss) income allocable to common stockholders	$	(1,854	)		$	480			$	(4,328	)		$	989
Basic weighted-average shares of common stock outstanding	1,040				1,039				1,040				1,039
Add shares issuable upon exercise or vesting of dilutive stock options and RSUs	—			a	6			a	—			a	6			a
Diluted weighted-average shares of common stock outstanding	1,040				1,045				1,040				1,045
Basic net (loss) income per share attributable to common stockholders	$	(1.78	)		$	0.46			$	(4.16	)		$	0.95
Diluted net (loss) income per share attributable to common stockholders	$	(1.78	)		$	0.46			$	(4.16	)		$	0.95

a. Excludes approximately four million shares of common stock for both the quarter and six months ended June 30, 2015, and three million shares of common stock for both the quarter and six months ended June 30, 2014, associated with outstanding stock options with exercise prices less than the average market price of FCX's common stock and RSUs that were anti-dilutive.

Outstanding stock options with exercise prices greater than the average market price of FCX’s common stock during the period are excluded from the computation of diluted net income per share of common stock. Excluded stock options totaled 40 million for both the quarter and six months ended June 30, 2015, and 30 million for both the quarter andsix months ended June 30, 2014.

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Guarantor Financial Statements (Unaudited) (Details)	Jun. 30, 2015
FM O&G LLC Guarantor [Member]
Debt Instrument [Line Items]
Noncontrolling Interest, Ownership Percentage by Parent	100.00%

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Earnings Per Share (Unaudited) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Earnings Per Share [Abstract]
Net (loss) income		$ (1,799)	$ 660	$ (4,205)	$ 1,286
Net income attributable to noncontrolling interests		(42)	(168)	(100)	(274)
Preferred dividends on redeemable noncontrolling interest		(10)	(10)	(20)	(20)
Undistributed earnings allocable to participating securities		(3)	(2)	(3)	(3)
Net (loss) income allocable to common stockholders		$ (1,854)	$ 480	$ (4,328)	$ 989
Basic weighted-average shares of common stock outstanding		1,040	1,039	1,040	1,039
Add shares issuable upon exercise or vesting of dilutive stock options and RSUs	[1]	0	6	0	6
Diluted weighted-average shares of common stock outstanding		1,040	1,045	1,040	1,045
Basic net (loss) income per share attributable to common stockholders		$ (1.78)	$ 0.46	$ (4.16)	$ 0.95
Diluted net (loss) income per share attributable to common stockholders		$ (1.78)	$ 0.46	$ (4.16)	$ 0.95
Potential anti-dilutive additional shares of common stock (in shares)		4	3	4	3
Outstanding stock options with exercise prices greater than average market price of common stock (in shares)		40	30	40	30

[1] Excludes approximately four million shares of common stock for both the quarter and six months ended June 30, 2015, and three million shares of common stock for both the quarter and six months ended June 30, 2014, associated with outstanding stock options with exercise prices less than the average market price of FCX's common stock and RSUs that were anti-dilutive.

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Acquisitions and Dispositions (Unaudited) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2014	Jun. 20, 2014
Business Acquisition [Line Items]
Income Tax Expense (Benefit), Changes in Deferred Tax Liabilities and Deferred Tax Asset Valuation Allowances	$ 58.0	$ 58.0
Eagle Ford [Member]
Business Acquisition [Line Items]
Disposal Date		Jun. 20, 2014
Business Combination, Consideration Transferred		$ 3,100.0
Effective Date		Apr. 01, 2014
Income Tax Expense (Benefit), Changes in Deferred Tax Liabilities and Deferred Tax Asset Valuation Allowances		$ 58.0
Adjustment to Goodwill		221.0
Escrow Deposit Disbursements Related to Property Acquisition			$ 1,300.0
Deepwater Gulf of Mexico Interests [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred		$ 918.0
Effective Date		Jun. 30, 2014
Business Combination, Adjustment to Recognized Identifiable Assets Acquired and Liabilities Assumed Oil and Gas Properties Subject to Depletion		$ 451.0
Business Combination, Adjustment to Recognized Identifiable Assets Acquired and Liabilities Assumed Oil and Gas Properties Not Subject to Depletion		477.0
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Asset Retirement Costs		$ 10.0

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Guarantor Financial Statements (Unaudited) Condensed Consolidating Balance Sheets (Details) - USD ($) $ in Millions		Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014
ASSETS
Current assets		$ 8,697	$ 9,045
Property, plant, equipment and mining development costs, net		27,095	26,220
Oil and gas properties, net - full cost method
Subject to amortization, less accumulated amortization		4,649	9,187
Not subject to amortization		9,312	10,087
Investments in consolidated subsidiaries		0	0
Other assets		4,255	4,135
Total assets		54,008	58,674	$ 63,903
LIABILITIES AND EQUITY
Current liabilities		4,739	5,172
Long-term debt, less current portion		20,111	18,371
Deferred income taxes		4,870	6,398
Environmental and asset retirement obligations, less current portion		3,716	3,647
Other liabilities		1,760	1,861
Total liabilities		35,196	35,449
Redeemable noncontrolling interest		757	751
Equity:
Stockholders' equity		13,805	18,287
Noncontrolling interests		4,250	4,187
Total equity		18,055	22,474
Total liabilities and equity		54,008	58,674
FCX Issuer [Member]
ASSETS
Current assets		257	323
Property, plant, equipment and mining development costs, net		20	22
Oil and gas properties, net - full cost method
Subject to amortization, less accumulated amortization		0	0
Not subject to amortization		0	0
Investments in consolidated subsidiaries		24,153	28,765
Other assets		9,991	8,914
Total assets		34,421	38,024
LIABILITIES AND EQUITY
Current liabilities		3,106	1,592
Long-term debt, less current portion		15,841	14,930
Deferred income taxes	[1]	1,613	3,161
Environmental and asset retirement obligations, less current portion		0	0
Other liabilities		56	54
Total liabilities		20,616	19,737
Redeemable noncontrolling interest		0	0
Equity:
Stockholders' equity		13,805	18,287
Noncontrolling interests		0	0
Total equity		13,805	18,287
Total liabilities and equity		34,421	38,024
FM O&G LLC Guarantor [Member]
ASSETS
Current assets		2,900	2,635
Property, plant, equipment and mining development costs, net		51	46
Oil and gas properties, net - full cost method
Subject to amortization, less accumulated amortization		1,507	3,296
Not subject to amortization		2,649	2,447
Investments in consolidated subsidiaries		2,216	6,460
Other assets		4,703	3,947
Total assets		14,026	18,831
LIABILITIES AND EQUITY
Current liabilities		433	560
Long-term debt, less current portion		5,181	3,874
Deferred income taxes		0	0
Environmental and asset retirement obligations, less current portion		307	302
Other liabilities		3,361	3,372
Total liabilities		9,282	8,108
Redeemable noncontrolling interest		0	0
Equity:
Stockholders' equity		4,744	10,723
Noncontrolling interests		0	0
Total equity		4,744	10,723
Total liabilities and equity		14,026	18,831
Non-Guarantor Subsidiaries [Member]
ASSETS
Current assets		9,665	8,659
Property, plant, equipment and mining development costs, net		27,024	26,152
Oil and gas properties, net - full cost method
Subject to amortization, less accumulated amortization		3,142	5,907
Not subject to amortization		6,659	7,640
Investments in consolidated subsidiaries		4,019	10,246
Other assets		4,179	4,061
Total assets		54,688	62,665
LIABILITIES AND EQUITY
Current liabilities		5,325	5,592
Long-term debt, less current portion		10,221	8,879
Deferred income taxes		3,257	3,237
Environmental and asset retirement obligations, less current portion		3,409	3,345
Other liabilities		1,829	1,910
Total liabilities		24,041	22,963
Redeemable noncontrolling interest		757	751
Equity:
Stockholders' equity		26,173	35,268
Noncontrolling interests		3,717	3,683
Total equity		29,890	38,951
Total liabilities and equity		54,688	62,665
Eliminations [Member]
ASSETS
Current assets		(4,125)	(2,572)
Property, plant, equipment and mining development costs, net		0	0
Oil and gas properties, net - full cost method
Subject to amortization, less accumulated amortization		0	(16)
Not subject to amortization		4	0
Investments in consolidated subsidiaries		(30,388)	(45,471)
Other assets		(14,618)	(12,787)
Total assets		(49,127)	(60,846)
LIABILITIES AND EQUITY
Current liabilities		(4,125)	(2,572)
Long-term debt, less current portion		(11,132)	(9,312)
Deferred income taxes		0	0
Environmental and asset retirement obligations, less current portion		0	0
Other liabilities		(3,486)	(3,475)
Total liabilities		(18,743)	(15,359)
Redeemable noncontrolling interest		0	0
Equity:
Stockholders' equity		(30,917)	(45,991)
Noncontrolling interests		533	504
Total equity		(30,384)	(45,487)
Total liabilities and equity		$ (49,127)	$ (60,846)

[1] All U.S. related deferred income taxes are recorded at the parent company.

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Inventories, Including Long-Term Mill and Leach Stockpiles (Unaudited) (Details) - USD ($) $ in Millions		3 Months Ended	6 Months Ended
		Jun. 30, 2015	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Components of Inventories [Line Items]
Raw materials (primarily concentrates)		$ 306	$ 306		$ 288
Work-in-process		155	155		174
Finished goods		1,023	1,023		1,099
Total product inventories		1,484	1,484		1,561
Total mill and leach stockpiles		1,933	1,933		1,914
Total materials and supplies, net	[1]	2,014	2,014		1,886
Total long-term mill and leach stockpiles		2,277	2,277		2,179
Inventory obsolescence reserves		25	25		20
Lower of cost or market inventory adjustments		(59)	(63)	$ 0
Current [Member]
Components of Inventories [Line Items]
Mill stockpiles		130	130		86
Leach stockpiles		1,803	1,803		1,828
Total mill and leach stockpiles		1,933	1,933		1,914
Long-Term [Member]
Components of Inventories [Line Items]
Mill stockpiles		361	361		360
Leach stockpiles		1,916	1,916		1,819
Total long-term mill and leach stockpiles	[2]	2,277	2,277		$ 2,179
Molybdenum [Member]
Components of Inventories [Line Items]
Lower of cost or market inventory adjustments		(48)	(52)
Copper [Member]
Components of Inventories [Line Items]
Lower of cost or market inventory adjustments		$ (11)	$ (11)

[1] Materials and supplies inventory was net of obsolescence reserves totaling $25 million at June 30, 2015, and $20 million at December 31, 2014.

[2] Estimated metals in stockpiles not expected to be recovered within the next 12 months.

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Income Taxes (Unaudited) (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2015		Jun. 30, 2014		Jun. 30, 2015		Jun. 30, 2014
Income Tax Disclosure [Abstract]
U.S. operations	$ (829)	[1]	$ 149	[2]	$ (1,664)	[1]	$ 285	[2]
International operations	142		179		282		400
Total	(687)		328		$ (1,382)		685
Income Tax Expense (Benefit), Changes in Deferred Tax Liabilities and Deferred Tax Asset Valuation Allowances			$ 58				$ 58
Consolidated effective income tax rate (percent)					25.00%		35.00%
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount	$ (305)				$ (763)
Effective Income Tax Rate, Adjusted, Percent					38.00%

[1] As a result of the impairment to oil and gas properties, FCX recorded tax charges of $305 million for second-quarter 2015 and $763 million for the first six months of 2015 to establish a valuation allowance primarily against U.S. federal alternative minimum tax credits. Excluding this charge, FCX's consolidated effective income tax rate was 38 percent for the first six months of 2015.

[2] FCX recognized a $58 million charge for deferred taxes recorded in connection with the allocation of goodwill to the sale of Eagle Ford shale assets.

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Acquisitions and Dispositions (Unaudited) (Notes)

6 Months Ended

Jun. 30, 2015

Acquisitions and Dispositions [Abstract]

Business Combination Disclosure [Text Block]

ACQUISITIONS AND DISPOSITIONS

Eagle Ford Disposition. On June 20, 2014, FCX completed the sale of its Eagle Ford shale assets to a subsidiary of Encana Corporation for cash consideration of $3.1 billion, before closing adjustments from the April 1, 2014, effective date. Under full cost accounting rules, the proceeds were recorded as a reduction of capitalized oil and gas properties, with no gain or loss recognition, except for $58 million of deferred tax expense recorded in connection with the allocation of $221 million of goodwill (for which deferred taxes were not previously provided) to the Eagle Ford shale assets. Approximately $1.3 billion of proceeds from this transaction was placed in a like-kind exchange escrow and was used to reinvest in additional Deepwater Gulf of Mexico (GOM) oil and gas interests, as discussed below and in Note 2 of FCX's annual report on Form 10-K for the year ended December 31, 2014. The remaining proceeds were used to repay debt.

Deepwater GOM Acquisition. On June 30, 2014, FCX completed the acquisition of interests in the Deepwater GOM from a subsidiary of Apache Corporation, including interests in the Lucius and Heidelberg oil fields and several exploration leases, for $918 million ($451 million for oil and gas properties subject to amortization and $477 million for costs not subject to amortization, including transaction costs and $10 million of asset retirement costs). The Deepwater GOM acquisition was funded by the like-kind exchange escrow.

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Debt and Equity Transactions (Unaudited) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Feb. 27, 2015	Dec. 31, 2014	Apr. 30, 2014
Extinguishment of Debt [Line Items]
Long-term Debt, Gross	$ 20,900,000,000		$ 20,900,000,000
Liabilities, Fair Value Adjustment			225,000,000
Debt Instrument, Unamortized Discount (Premium), Net	21,000,000		21,000,000
Unamortized Debt Issuance Expense	116,000,000		116,000,000			$ 121,000,000
Net gain on early extinguishment of debt	0	$ 5,000,000	0	$ 5,000,000
Bank Term Loan [Member]
Extinguishment of Debt [Line Items]
Debt Instrument, Face Amount	4,000,000,000		4,000,000,000
Long-term Debt, Maturities, Repayments of Principal in Year Two					$ 205,000,000	650,000,000
Long-term Debt, Maturities, Repayments of Principal in Year Three					272,000,000	200,000,000
Long-term Debt, Maturities, Repayments of Principal in Year Four					1,000,000,000	$ 2,200,000,000
Long-term Debt, Maturities, Repayments of Principal in Year Five					313,000,000
Long-term Debt, Maturities, Repayments of Principal after Year Five					$ 1,300,000,000
Credit Facility [Domain] | Revolving Credit Facility [Member]
Extinguishment of Debt [Line Items]
Long-term Debt, Gross	985,000,000		985,000,000
Letters of Credit Outstanding, Amount	42,000,000		42,000,000
Line of Credit Facility, Remaining Borrowing Capacity	3,000,000,000		3,000,000,000
Line Of Credit Facility Remaining Borrowing Capacity Available For Letters Of Credit	1,500,000,000		1,500,000,000
Senior Notes [Member] | 6.625% Senior Notes due 2021 [Member]
Extinguishment of Debt [Line Items]
Extinguishment of Debt, Amount		210,000,000
Debt Instrument, Interest Rate, Stated Percentage							6.625%
Net gain on early extinguishment of debt		$ 6,000,000
Cerro Verde [Member] | Credit Facility [Domain]
Extinguishment of Debt [Line Items]
Long-term Debt, Gross	1,300,000,000		1,300,000,000
Line of Credit Facility, Maximum Borrowing Capacity	1,800,000,000		1,800,000,000
Letters of Credit Outstanding, Amount	0		0
Line of Credit Facility, Remaining Borrowing Capacity	$ 531,000,000		$ 531,000,000
Term of Debt Agreement			5 years

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Fair Value Measurement (Unaudited) Unobservable Inputs (Details) - Jun. 30, 2015 $ in Millions		USD ($) $ / bbl
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset		$ 330
Derivative Asset		194
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset	[1],[2]	316
Derivative Asset	[1],[2]	174
Crude Oil Options [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Derivative Asset		316
Net realized gains		21
Net unrealized gains included in earnings related to assets and liabilities still held at the end of the period	[3]	36
Net settlement (receipts) payments	[4]	(199)
Derivative Asset		$ 174
Crude Oil Options [Member] | Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Assumptions, Implied Volatilities		28.00%
Crude Oil Options [Member] | Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Assumptions, Implied Volatilities		41.00%
Crude Oil Options [Member] | Weighted Average [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Deferred Premium Price | $ / bbl		6.89
Crude Oil Options [Member] | Weighted Average [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Fair Value Assumptions, Implied Volatilities		32.00%
Sales [Member] | Crude Oil Options [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Net unrealized gains included in earnings related to assets and liabilities still held at the end of the period		$ 37
Interest Expense [Member] | Crude Oil Options [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Net unrealized gains included in earnings related to assets and liabilities still held at the end of the period	[3]	1
Net settlement (receipts) payments		$ (2)

[1] Recorded at fair value.

[2] Refer to Note 7 for further discussion and balance sheet classifications. Crude oil options are net of $106 million at June 30, 2015, and $210 million at December 31, 2014, for deferred premiums and accrued interest.

[3] Includes net unrealized gains of $37 million, partially offset by $1 million of interest expense associated with the deferred premiums.

[4] Includes interest payments of $2 million.

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Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions		Jun. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents		$ 466	$ 464
Trade accounts receivable		949	953
Other accounts receivable		1,323	1,610
Inventories:
Materials and supplies, net	[1]	2,014	1,886
Mill and leach stockpiles		1,933	1,914
Product		1,484	1,561
Other current assets		528	657
Total current assets		8,697	9,045
Property, plant, equipment and mining development costs, net		27,095	26,220
Oil and gas properties, net - full cost method
Subject to amortization, less accumulated amortization		4,649	9,187
Not subject to amortization		9,312	10,087
Long-term mill and leach stockpiles		2,277	2,179
Other assets		1,978	1,956
Total assets		54,008	58,674
Current liabilities:
Accounts payable and accrued liabilities		3,376	3,653
Current portion of debt		791	478
Current portion of environmental and asset retirement obligations		330	296
Dividends payable		175	335
Accrued income taxes		67	410
Total current liabilities		4,739	5,172
Long-term debt, less current portion		20,111	18,371
Deferred income taxes		4,870	6,398
Environmental and asset retirement obligations, less current portion		3,716	3,647
Other liabilities		1,760	1,861
Total liabilities		35,196	35,449
Redeemable noncontrolling interest		757	751
Stockholders’ equity:
Common stock		117	117
Capital in excess of par value		22,330	22,281
(Accumulated deficit) retained earnings		(4,417)	128
Accumulated other comprehensive loss		(523)	(544)
Common stock held in treasury		(3,702)	(3,695)
Total stockholders’ equity		13,805	18,287
Noncontrolling interests		4,250	4,187
Total equity		18,055	22,474
Total liabilities and equity		$ 54,008	$ 58,674

[1] Materials and supplies inventory was net of obsolescence reserves totaling $25 million at June 30, 2015, and $20 million at December 31, 2014.

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Guarantor Financial Statements (Unaudited) Condensed Consolidating Statements of Income (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2015		Jun. 30, 2014	Jun. 30, 2015		Jun. 30, 2014
Revenues	$ 4,248		$ 5,522	$ 8,401		$ 10,507
Total costs and expenses	6,622		4,369	13,738		8,243
Operating (loss) income	(2,374)		1,153	(5,337)		2,264
Interest expense, net	(149)		(164)	(295)		(325)
Net gain on early extinguishment of debt	0		5	0		5
Other income (expense), net	37		(8)	44		25
(Loss) income before income taxes and equity in affiliated companies' net earnings	(2,486)		986	(5,588)		1,969
Benefit from (provision for) income taxes	687		(328)	1,382		(685)
Equity in affiliated companies' net (losses) earnings	0		2	1		2
Net (loss) income	(1,799)		660	(4,205)		1,286
Net income and preferred dividends attributable to noncontrolling interests	(52)		(178)	(120)		(294)
Net (loss) income attributable to common stockholders	(1,851)		482	(4,325)		992
Other comprehensive income (loss)	9		1	21		4
Total comprehensive (loss) income	(1,842)		483	(4,304)		996
Impairment of oil and gas properties	2,686		0	5,790		0
FCX Issuer [Member]
Revenues	0		0	0		0
Total costs and expenses	19		21	35		32
Operating (loss) income	(19)		(21)	(35)		(32)
Interest expense, net	(121)		(87)	(236)		(169)
Net gain on early extinguishment of debt			(1)			(1)
Other income (expense), net	127		17	156		37
(Loss) income before income taxes and equity in affiliated companies' net earnings	(13)		(92)	(115)		(165)
Benefit from (provision for) income taxes	(265)		26	(686)		5
Equity in affiliated companies' net (losses) earnings	(1,573)		548	(3,524)		1,152
Net (loss) income	(1,851)		482	(4,325)		992
Net income and preferred dividends attributable to noncontrolling interests	0		0	0		0
Net (loss) income attributable to common stockholders	(1,851)		482	(4,325)		992
Other comprehensive income (loss)	9		1	21		4
Total comprehensive (loss) income	(1,842)		483	(4,304)		996
Impairment of oil and gas properties				0
FM O&G LLC Guarantor [Member]
Revenues	169		570	350		1,214
Total costs and expenses	1,217	[1]	489	2,535	[2]	1,015
Operating (loss) income	(1,048)		81	(2,185)		199
Interest expense, net	(2)		(44)	(6)		(85)
Net gain on early extinguishment of debt			6			6
Other income (expense), net	0		1	0		1
(Loss) income before income taxes and equity in affiliated companies' net earnings	(1,050)		44	(2,191)		121
Benefit from (provision for) income taxes	374		26	790		(17)
Equity in affiliated companies' net (losses) earnings	(1,920)		126	(4,279)		256
Net (loss) income	(2,596)		196	(5,680)		360
Net income and preferred dividends attributable to noncontrolling interests	0		0	0		0
Net (loss) income attributable to common stockholders	(2,596)		196	(5,680)		360
Other comprehensive income (loss)	0		0	0		0
Total comprehensive (loss) income	(2,596)		196	(5,680)		360
Impairment of oil and gas properties	990			2,052
Non-Guarantor Subsidiaries [Member]
Revenues	4,079		4,952	8,051		9,293
Total costs and expenses	5,383	[1]	3,865	11,181	[2]	7,204
Operating (loss) income	(1,304)		1,087	(3,130)		2,089
Interest expense, net	(67)		(51)	(124)		(109)
Net gain on early extinguishment of debt			0			0
Other income (expense), net	(56)		(8)	(48)		25
(Loss) income before income taxes and equity in affiliated companies' net earnings	(1,427)		1,028	(3,302)		2,005
Benefit from (provision for) income taxes	580		(378)	1,286		(670)
Equity in affiliated companies' net (losses) earnings	(2,972)		154	(6,502)		339
Net (loss) income	(3,819)		804	(8,518)		1,674
Net income and preferred dividends attributable to noncontrolling interests	(38)		(180)	(94)		(291)
Net (loss) income attributable to common stockholders	(3,857)		624	(8,612)		1,383
Other comprehensive income (loss)	9		1	21		4
Total comprehensive (loss) income	(3,848)		625	(8,591)		1,387
Impairment of oil and gas properties	1,674			3,717
Eliminations [Member]
Revenues	0		0	0		0
Total costs and expenses	3		(6)	(13)		(8)
Operating (loss) income	(3)		6	13		8
Interest expense, net	41		18	71		38
Net gain on early extinguishment of debt			0			0
Other income (expense), net	(34)		(18)	(64)		(38)
(Loss) income before income taxes and equity in affiliated companies' net earnings	4		6	20		8
Benefit from (provision for) income taxes	(2)		(2)	(8)		(3)
Equity in affiliated companies' net (losses) earnings	6,465		(826)	14,306		(1,745)
Net (loss) income	6,467		(822)	14,318		(1,740)
Net income and preferred dividends attributable to noncontrolling interests	(14)		2	(26)		(3)
Net (loss) income attributable to common stockholders	6,453		(820)	14,292		(1,743)
Other comprehensive income (loss)	(9)		(1)	(21)		(4)
Total comprehensive (loss) income	$ 6,444		$ (821)	14,271		$ (1,747)
Impairment of oil and gas properties				$ 21

[1] Includes charges totaling $1.0 billion at the FM O&G LLC guarantor and $1.7 billion at the non-guarantor subsidiaries related to ceiling test impairment of FCX's oil and gas properties pursuant to full cost accounting rules.

[2] Includes charges totaling $2.1 billion at the FM O&G LLC guarantor and $3.7 billion at the non-guarantor subsidiaries related to ceiling test impairment of FCX's oil and gas properties pursuant to full cost accounting rules.

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Consolidated Statement of Equity (Unaudited) - 6 months ended Jun. 30, 2015 - USD ($) shares in Millions, $ in Millions	Total	Total FCX Stockholders' Equity [Member]	Common Stock [Member]	Capital in Excess of Par Value [Member]	Retained Earnings (Accumulated Deficit) [Member]	Accumulated Other Comprehensive Loss [Member]	Common Stock Held in Treasury [Member]	Noncontrolling Interests [Member]
Balance at Dec. 31, 2014	$ 22,474	$ 18,287	$ 117	$ 22,281	$ 128	$ (544)	$ (3,695)	$ 4,187
Balance (in shares) at Dec. 31, 2014			1,167				128
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Exercised and issued stock-based awards	3	3	$ 0	3	0	0	$ 0	0
Exercised and issued stock-based awards (in shares)			1				0
Stock-based compensation	57	50	$ 0	50	0	0	$ 0	7
Reserve of tax benefit for stock-based awards	(2)	(2)	0	(2)	0	0	0	0
Tender of shares for stock-based awards	(7)	(7)	$ 0	0	0	0	$ (7)	0
Tender of shares for stock-based awards (in shares)			0				0
Dividends on common stock	(220)	(220)	$ 0	0	(220)	0	$ 0	0
Dividends to noncontrolling interests	(46)	0	0	0	0	0	0	(46)
Noncontrolling interests' share of contributed capital in subsidiary	0	(2)	0	(2)	0	0	0	2
Net loss attributable to common stockholders	(4,325)	(4,325)	0	0	(4,325)	0	0	0
Net income attributable to noncontrolling interests	100	0	0	0	0	0	0	100
Other comprehensive income	21	21	0	0	0	21	0	0
Balance at Jun. 30, 2015	$ 18,055	$ 13,805	$ 117	$ 22,330	$ (4,417)	$ (523)	$ (3,702)	$ 4,250
Balance (in shares) at Jun. 30, 2015			1,168				128

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Financial Instruments (Unaudited) Not Designated as Hedging Instruments (Details) - Jun. 30, 2015 oz in Thousands, lb in Millions	lb oz $ / lb $ / oz
Embedded derivatives in provisional sales contracts - Copper [Member] | Derivatives not designated as hedging instruments [Member]
Derivative [Line Items]
Open positions (in lbs except gold in oz) | lb	572
Average contract price	2.68
Average market price	2.58
Maturities through	Nov. 30, 2015
Embedded derivatives in provisional sales contracts - Gold [Member] | Derivatives not designated as hedging instruments [Member]
Derivative [Line Items]
Open positions (in lbs except gold in oz) | oz	229
Average contract price | $ / oz	1,189
Average market price | $ / oz	1,174
Maturities through	Sep. 30, 2015
Embedded derivatives in provisional purchase contracts - Copper [Member] | Derivatives not designated as hedging instruments [Member]
Derivative [Line Items]
Open positions (in lbs except gold in oz) | lb	134
Average contract price	2.75
Average market price	2.61
Maturities through	Oct. 31, 2015
Atlantic Copper [Member] | Copper forward contracts [Member] | Derivatives not designated as hedging instruments [Member]
Derivative [Line Items]
Open positions (in lbs except gold in oz) | lb	31
Average contract price	2.65
Maturities through	Aug. 31, 2015
Copper futures and swap contracts [Member] | Fair Value Hedging [Member] | Derivatives designated as hedging instruments [Member]
Derivative [Line Items]
Open positions (in lbs except gold in oz) | lb	51
Average contract price	2.71
Maturities through	May 31, 2017

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Income Taxes (Unaudited) (Tables)

6 Months Ended

Jun. 30, 2015

Income Tax Disclosure [Abstract]

Geographic Sources of Provision for Income Taxes

Geographic sources of FCX's (benefit from) provision for income taxes follow (in millions):

	Three Months Ended							Six Months Ended
	June 30,							June 30,
	2015				2014			2015				2014
U.S. operations	$	(829	)	a	$	149	b	$	(1,664	)	a	$	285	b
International operations	142				179			282				400
Total	$	(687	)		$	328		$	(1,382	)		$	685

a. As a result of the impairment to oil and gas properties, FCX recorded tax charges of $305 million for second-quarter2015 and $763 million for the first six months of 2015 to establish a valuation allowance primarily against U.S. federal alternative minimum tax credits. Excluding this charge, FCX's consolidated effective income tax rate was 38 percent for the first six months of 2015.

b. FCX recognized a $58 million charge for deferred taxes recorded in connection with the allocation of goodwill to the sale of Eagle Ford shale assets.

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Financial Instruments (Unaudited) Oil and Gas (Details) - Types of Financial Instruments [Domain] MMBTU in Millions, $ in Millions		6 Months Ended
		Jun. 30, 2015 USD ($) MBbls MMBTU $ / bbl	Dec. 31, 2014 USD ($)
Derivative [Line Items]
Derivative Liability | $		$ 70	$ 99
Maximum Price Limit per Barrel		20
2015 Positions [Member] | Derivatives not designated as hedging instruments [Member] | Crude Oil Options [Member]
Derivative [Line Items]
Daily Volumes (Bbls) | MMBTU		15.5
2015 Positions [Member] | Derivatives not designated as hedging instruments [Member] | Crude Oil Options [Member] | 84 MBbls [Member]
Derivative [Line Items]
Daily Volumes (Bbls) | MBbls	[1]	84
Derivative, Average Floor Price	[1],[2]	90
Derivative, Average Floor Price Limit	[1],[2]	70
Derivative, Underlying Basis	[1]	Brent
Weighted Average [Member] | Crude Oil Options [Member]
Derivative [Line Items]
Deferred Premium Price		6.89
Weighted Average [Member] | 2015 Positions [Member] | Derivatives not designated as hedging instruments [Member] | Crude Oil Options [Member] | 84 MBbls [Member]
Derivative [Line Items]
Deferred Premium Price	[1]	6.89

[1] If the index price is less than the per barrel floor, FCX receives the difference between the per barrel floor and the index price up to a maximum of $20 per barrel less the option premium. If the index price is at or above the per barrel floor, FCX pays the option premium and no cash settlement is received.

[2] The average strike prices do not reflect any premiums to purchase the put options.

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Fair Value Measurement (Unaudited) (Tables)

6 Months Ended

Jun. 30, 2015

Fair Value Disclosures [Abstract]

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]

A summary of the changes in the fair value of FCX's most significant Level 3 instruments, crude oil options, follows (in millions):

	Crude Oil
	Options
Fair value at December 31, 2014	$	316
Net realized gains	21
Net unrealized gains included in earnings related to assets and liabilities   still held at the end of the period	36			a
Net settlement receipts	(199		)	b
Fair value at June 30, 2015	$	174

a. Includes net unrealized gains of $37 million, partially offset by $1 million of interest expense associated with the deferred premiums.

b. Includes interest payments of $2 million.

Carrying Amount and Fair Value of Other Financial Instruments

A summary of the carrying amount and fair value of FCX’s financial instruments, other than cash and cash equivalents, accounts receivable, restricted cash, accounts payable and accrued liabilities, and dividends payable (refer to Note 7), follows (in millions):

	At June 30, 2015
	Carrying		Fair Value
	Amount		Total		Level 1		Level 2		Level 3
Assets
Investment securities:a,b
U.S. core fixed income fund	$	23	$	23	$	—	$	23	$	—
Money market funds	22		22		22		—		—
Equity securities	3		3		3		—		—
Total	48		48		25		23		—
Legally restricted funds:a,b,c,d
U.S. core fixed income fund	51		51		—		51		—
Government bonds and notes	35		35		—		35		—
Corporate bonds	28		28		—		28		—
Government mortgage-backed securities	24		24		—		24		—
Asset-backed securities	14		14		—		14		—
Money market funds	9		9		9		—		—
Collateralized mortgage-backed securities	8		8		—		8		—
Municipal bonds	1		1		—		1		—
Total	170		170		9		161		—
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross asset position	21		21		—		21		—
Crude oil options	174		174		—		—		174
Total	195		195		—		21		174
Total assets			$	413	$	34	$	205	$	174
Liabilities
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross liability position	$	65	$	65	$	—	$	65	$	—
Copper futures and swap contracts	5		5		5		—		—
Copper forward contracts	1		1		—		1		—
Total	71		71		5		66		—
Long-term debt, including current portionf	20,902		20,191		—		20,191		—
Total liabilities			$	20,262	$	5	$	20,257	$	—

	At December 31, 2014
	Carrying		Fair Value
	Amount		Total		Level 1		Level 2		Level 3
Assets
Investment securities:a,b
U.S. core fixed income fund	$	23	$	23	$	—	$	23	$	—
Money market funds	20		20		20		—		—
Equity securities	3		3		3		—		—
Total	46		46		23		23		—
Legally restricted funds:a,b,c,d
U.S. core fixed income fund	52		52		—		52		—
Government bonds and notes	39		39		—		39		—
Corporate bonds	27		27		—		27		—
Government mortgage-backed securities	19		19		—		19		—
Asset-backed securities	17		17		—		17		—
Money market funds	11		11		11		—		—
Collateralized mortgage-backed securities	6		6		—		6		—
Municipal bonds	1		1		—		1		—
Total	172		172		11		161		—
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross asset position	15		15		—		15		—
Crude oil options	316		316		—		—		316
Total	331		331		—		15		316
Total assets			$	549	$	34	$	199	$	316
Liabilities
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross liability position	$	93	$	93	$	—	$	93	$	—
Copper futures and swap contracts	7		7		6		1		—
Total	100		100		6		94		—
Long-term debt, including current portionf	18,849		18,735		—		18,735		—
Total liabilities			$	18,835	$	6	$	18,829	$	—

a. Recorded at fair value. 

b. Current portion included in other current assets and long-term portion included in other assets.

c. Excludes time deposits (which approximated fair value) included in other assets of $117 million at June 30, 2015, and $115 million at December 31, 2014, associated with an assurance bond to support PT Freeport Indonesia's (PT-FI) commitment for smelter development in Indonesia.

d. Excludes time deposits (which approximated fair value) included in other current assets of $10 million at June 30, 2015, and $8 million at December 31, 2014, associated with a reclamation guarantee at PT-FI. Also, excludes a time deposit of $9 million at December 31, 2014, associated with a customs audit assessment.

e. Refer to Note 7 for further discussion and balance sheet classifications. Crude oil options are net of $106 million at June 30, 2015, and $210 million at December 31, 2014, for deferred premiums and accrued interest.

f. Recorded at cost except for debt assumed in acquisitions, which were recorded at fair value at the respective acquisition dates.

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General Information (Unaudited)

6 Months Ended

Jun. 30, 2015

General Information [Abstract]

General Information

GENERAL INFORMATION

The accompanying unaudited consolidated financial statements have been prepared in accordance with the instructions to Form 10-Q and do not include all information and disclosures required by generally accepted accounting principles (GAAP) in the United States (U.S.). Therefore, this information should be read in conjunction with Freeport-McMoRan Inc.'s (FCX) consolidated financial statements and notes contained in its annual report on Form 10-K for the year ended December 31, 2014. The information furnished herein reflects all adjustments that are, in the opinion of management, necessary for a fair statement of the results for the interim periods reported. With the exception of the oil and gas properties impairment discussed below and the related tax charge to establish a deferred tax valuation allowance, all such adjustments are, in the opinion of management, of a normal recurring nature. Operating results for the quarter and six months ended June 30, 2015, are not necessarily indicative of the results that may be expected for the year ending December 31, 2015.

Oil and Gas Properties. Under the U.S. Securities and Exchange Commission's (SEC) full cost accounting rules, FCX reviews the carrying value of its oil and gas properties each quarter on a country-by-country basis. Under these rules, capitalized costs of oil and gas properties (net of accumulated depreciation, depletion, amortization and impairment, and related deferred income taxes) for each cost center may not exceed a “ceiling” equal to:

• the present value, discounted at 10 percent, of estimated future net cash flows from the related proved oil and natural gas reserves, net of estimated future income taxes; plus

• the cost of the related unproved properties not being amortized; plus

• the lower of cost or estimated fair value of the related unproved properties included in the costs being amortized (net of related tax effects).

These rules require that FCX price its future oil and gas production at the twelve-month average of the first-day-of-the-month historical reference prices as adjusted for location and quality differentials. FCX's reference prices are West Texas Intermediate (WTI) for oil and the Henry Hub spot price for natural gas. Such prices are utilized except where different prices are fixed and determinable from applicable contracts for the remaining term of those contracts. The reserve estimates exclude the effect of any crude oil derivatives FCX has in place. The estimated future net cash flows also exclude future cash outflows associated with settling asset retirement obligations included in the net book value of the oil and gas properties. The rules require an impairment if the capitalized costs exceed this “ceiling.”

At June 30, 2015, and March 31, 2015, net capitalized costs with respect to FCX's proved U.S. oil and gas properties exceeded the related ceiling test limitation; therefore, impairment charges of $2.7 billion were recorded in second-quarter 2015 and $5.8 billion for the first six months of 2015, primarily because of the lower twelve-month average of the first-day-of-the-month historical reference oil price and higher capitalized costs at such dates. The SEC requires that the twelve-month average of the first-day-of-the-month historical reference oil price be used in determining the ceiling amount under its full cost accounting rules. This price (using WTI as the reference oil price) was $71.68 per barrel at June 30, 2015 (the twelve-month average was $82.72 per barrel at March 31, 2015).

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Consolidated Statements of Operations (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues	$ 4,248	$ 5,522	$ 8,401	$ 10,507
Cost of sales:
Production and delivery	2,848	3,082	5,760	5,819
Depreciation, depletion and amortization	890	1,013	1,829	1,979
Impairment of oil and gas properties	2,686	0	5,790	0
Total cost of sales	6,424	4,095	13,379	7,798
Selling, general and administrative expenses	151	164	305	299
Mining exploration and research expenses	36	34	69	64
Environmental obligations and shutdown costs	11	76	24	82
Net gain on sale of assets	0	0	(39)	0
Total costs and expenses	6,622	4,369	13,738	8,243
Operating (loss) income	(2,374)	1,153	(5,337)	2,264
Interest expense, net	(149)	(164)	(295)	(325)
Insurance and other third-party recoveries	92	0	92	0
Net gain on early extinguishment of debt	0	5	0	5
Other (expense) income, net	(55)	(8)	(48)	25
(Loss) income before income taxes and equity in affiliated companies' net earnings	(2,486)	986	(5,588)	1,969
Benefit from (provision for) income taxes	687	(328)	1,382	(685)
Equity in affiliated companies’ net earnings	0	2	1	2
Net (loss) income	(1,799)	660	(4,205)	1,286
Net income attributable to noncontrolling interests	(42)	(168)	(100)	(274)
Preferred dividends attributable to redeemable noncontrolling interest	(10)	(10)	(20)	(20)
Net (loss) income attributable to common stockholders	$ (1,851)	$ 482	$ (4,325)	$ 992
Net (loss) income per share attributable to common stockholders:
Basic	$ (1.78)	$ 0.46	$ (4.16)	$ 0.95
Diluted	$ (1.78)	$ 0.46	$ (4.16)	$ 0.95
Weighted-average common shares outstanding:
Basic	1,040	1,039	1,040	1,039
Diluted	1,040	1,045	1,040	1,045
Dividends declared per share of common stock	$ 0.1605	$ 0.3125	$ 0.2105	$ 0.625

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Guarantor Financial Statements (Unaudited) (Notes)

6 Months Ended

Jun. 30, 2015

Guarantor Financial Statements [Abstract]

Guarantor Financial Statements [Text Block]

GUARANTOR FINANCIAL STATEMENTS

All of the senior notes issued by FCX are fully and unconditionally guaranteed on a senior basis jointly and severally by Freeport-McMoRan Oil & Gas LLC (FM O&G LLC), as guarantor, which is a 100 percent owned subsidiary of FM O&G and FCX. The guarantee is an unsecured obligation of the guarantor and ranks equal in right of payment with all existing and future indebtedness of FM O&G LLC, including indebtedness under the revolving credit facility. The guarantee ranks senior in right of payment with all of FM O&G LLC's future subordinated obligations and is effectively subordinated in right of payment to any debt of FM O&G LLC's subsidiaries. The indentures provide that FM O&G LLC's guarantee may be released or terminated for certain obligations under the following circumstances: (i) all or substantially all of the equity interests or assets of FM O&G LLC are sold to a third party; or (ii) FM O&G LLC no longer has any obligations under any FM O&G senior notes or any refinancing thereof and no longer guarantees any obligations of FCX under the revolver, the Term Loan or any other senior debt.

The following condensed consolidating financial information includes information regarding FCX, as issuer, FM O&G LLC, as guarantor, and all other non-guarantor subsidiaries of FCX. Included are the condensed consolidating balance sheets at June 30, 2015, and December 31, 2014, and the related condensed consolidating statements of comprehensive (loss) income for the three and six months ended June 30, 2015 and 2014, and condensed consolidating statements of cash flows for the six months ended June 30, 2015 and 2014 (in millions), which should be read in conjunction with FCX's notes to the consolidated financial statements.

CONDENSED CONSOLIDATING BALANCE SHEET

June 30, 2015

	FCX			FM O&G LLC		Non-guarantor					Consolidated
	Issuer			Guarantor		Subsidiaries		Eliminations			FCX
ASSETS
Current assets	$	257		$	2,900	$	9,665	$	(4,125	)	$	8,697
Property, plant, equipment and mining development costs, net	20			51		27,024		—			27,095
Oil and gas properties, net - full cost method:
Subject to amortization, less accumulated amortization	—			1,507		3,142		—			4,649
Not subject to amortization	—			2,649		6,659		4			9,312
Investments in consolidated subsidiaries	24,153			2,216		4,019		(30,388		)	—
Other assets	9,991			4,703		4,179		(14,618		)	4,255
Total assets	$	34,421		$	14,026	$	54,688	$	(49,127	)	$	54,008
LIABILITIES AND EQUITY
Current liabilities	$	3,106		$	433	$	5,325	$	(4,125	)	$	4,739
Long-term debt, less current portion	15,841			5,181		10,221		(11,132		)	20,111
Deferred income taxes	1,613		a	—		3,257		—			4,870
Environmental and asset retirement obligations, less current portion	—			307		3,409		—			3,716
Other liabilities	56			3,361		1,829		(3,486		)	1,760
Total liabilities	20,616			9,282		24,041		(18,743		)	35,196
Redeemable noncontrolling interest	—			—		757		—			757
Equity:
Stockholders' equity	13,805			4,744		26,173		(30,917		)	13,805
Noncontrolling interests	—			—		3,717		533			4,250
Total equity	13,805			4,744		29,890		(30,384		)	18,055
Total liabilities and equity	$	34,421		$	14,026	$	54,688	$	(49,127	)	$	54,008

a. All U.S. related deferred income taxes are recorded at the parent company.

CONDENSED CONSOLIDATING BALANCE SHEET

December 31, 2014

	FCX			FM O&G LLC		Non-guarantor					Consolidated
	Issuer			Guarantor		Subsidiaries		Eliminations			FCX
ASSETS
Current assets	$	323		$	2,635	$	8,659	$	(2,572	)	$	9,045
Property, plant, equipment and mining development costs, net	22			46		26,152		—			26,220
Oil and gas properties, net - full cost method:
Subject to amortization, less accumulated amortization	—			3,296		5,907		(16		)	9,187
Not subject to amortization	—			2,447		7,640		—			10,087
Investments in consolidated subsidiaries	28,765			6,460		10,246		(45,471		)	—
Other assets	8,914			3,947		4,061		(12,787		)	4,135
Total assets	$	38,024		$	18,831	$	62,665	$	(60,846	)	$	58,674
LIABILITIES AND EQUITY
Current liabilities	$	1,592		$	560	$	5,592	$	(2,572	)	$	5,172
Long-term debt, less current portion	14,930			3,874		8,879		(9,312		)	18,371
Deferred income taxes	3,161		a	—		3,237		—			6,398
Environmental and asset retirement obligations, less current portion	—			302		3,345		—			3,647
Other liabilities	54			3,372		1,910		(3,475		)	1,861
Total liabilities	19,737			8,108		22,963		(15,359		)	35,449
Redeemable noncontrolling interest	—			—		751		—			751
Equity:
Stockholders' equity	18,287			10,723		35,268		(45,991		)	18,287
Noncontrolling interests	—			—		3,683		504			4,187
Total equity	18,287			10,723		38,951		(45,487		)	22,474
Total liabilities and equity	$	38,024		$	18,831	$	62,665	$	(60,846	)	$	58,674

a. All U.S. related deferred income taxes are recorded at the parent company.

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE (LOSS) INCOME

Three Months Ended June 30, 2015
	FCX			FM O&G LLC				Non-guarantor							Consolidated
	Issuer			Guarantor				Subsidiaries				Eliminations			FCX
Revenues	$	—		$	169			$	4,079			$	—		$	4,248
Total costs and expenses	19			1,217			a	5,383			a	3			6,622
Operating (loss) income	(19		)	(1,048		)		(1,304		)		(3		)	(2,374		)
Interest expense, net	(121		)	(2		)		(67		)		41			(149		)
Other income (expense), net	127			—				(56		)		(34		)	37
(Loss) income before income taxes and equity in affiliated companies' net (losses) earnings	(13		)	(1,050		)		(1,427		)		4			(2,486		)
(Provision for) benefit from income taxes	(265		)	374				580				(2		)	687
Equity in affiliated companies' net (losses) earnings	(1,573		)	(1,920		)		(2,972		)		6,465			—
Net (loss) income	(1,851		)	(2,596		)		(3,819		)		6,467			(1,799		)
Net income and preferred dividends attributable to noncontrolling interests	—			—				(38		)		(14		)	(52		)
Net (loss) income attributable to common stockholders	$	(1,851	)	$	(2,596	)		$	(3,857	)		$	6,453		$	(1,851	)
Other comprehensive income (loss)	9			—				9				(9		)	9
Total comprehensive (loss) income	$	(1,842	)	$	(2,596	)		$	(3,848	)		$	6,444		$	(1,842	)

a. Includes charges totaling $1.0 billion at the FM O&G LLC guarantor and $1.7 billion at the non-guarantor subsidiaries related to ceiling test impairment of FCX's oil and gas properties pursuant to full cost accounting rules.

Six Months Ended June 30, 2015
	FCX			FM O&G LLC				Non-guarantor							Consolidated
	Issuer			Guarantor				Subsidiaries				Eliminations			FCX
Revenues	$	—		$	350			$	8,051			$	—		$	8,401
Total costs and expenses	35			2,535			a	11,181			a	(13		)	13,738
Operating (loss) income	(35		)	(2,185		)		(3,130		)		13			(5,337		)
Interest expense, net	(236		)	(6		)		(124		)		71			(295		)
Other income (expense), net	156			—				(48		)		(64		)	44
(Loss) income before income taxes and equity in affiliated companies' net (losses) earnings	(115		)	(2,191		)		(3,302		)		20			(5,588		)
(Provision for) benefit from income taxes	(686		)	790				1,286				(8		)	1,382
Equity in affiliated companies' net (losses) earnings	(3,524		)	(4,279		)		(6,502		)		14,306			1
Net (loss) income	(4,325		)	(5,680		)		(8,518		)		14,318			(4,205		)
Net income and preferred dividends attributable to noncontrolling interests	—			—				(94		)		(26		)	(120		)
Net (loss) income attributable to common stockholders	$	(4,325	)	$	(5,680	)		$	(8,612	)		$	14,292		$	(4,325	)
Other comprehensive income (loss)	21			—				21				(21		)	21
Total comprehensive (loss) income	$	(4,304	)	$	(5,680	)		$	(8,591	)		$	14,271		$	(4,304	)

a. Includes charges totaling $2.1 billion at the FM O&G LLC guarantor and $3.7 billion at the non-guarantor subsidiaries related to ceiling test impairment of FCX's oil and gas properties pursuant to full cost accounting rules.

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

Three Months Ended June 30, 2014
	FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Revenues	$	—		$	570		$	4,952		$	—		$	5,522
Total costs and expenses	21			489			3,865			(6		)	4,369
Operating (loss) income	(21		)	81			1,087			6			1,153
Interest expense, net	(87		)	(44		)	(51		)	18			(164		)
Net (loss) gain on early extinguishment of debt	(1		)	6			—			—			5
Other income (expense), net	17			1			(8		)	(18		)	(8		)
(Loss) income before income taxes and equity in affiliated companies' net earnings (losses)	(92		)	44			1,028			6			986
Benefit from (provision for) income taxes	26			26			(378		)	(2		)	(328		)
Equity in affiliated companies' net earnings (losses)	548			126			154			(826		)	2
Net income (loss)	482			196			804			(822		)	660
Net income and preferred dividends attributable to noncontrolling interests	—			—			(180		)	2			(178		)
Net income (loss) attributable to common stockholders	$	482		$	196		$	624		$	(820	)	$	482
Other comprehensive income (loss)	1			—			1			(1		)	1
Total comprehensive income (loss)	$	483		$	196		$	625		$	(821	)	$	483

Six Months Ended June 30, 2014
	FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Revenues	$	—		$	1,214		$	9,293		$	—		$	10,507
Total costs and expenses	32			1,015			7,204			(8		)	8,243
Operating (loss) income	(32		)	199			2,089			8			2,264
Interest expense, net	(169		)	(85		)	(109		)	38			(325		)
Net (loss) gain on early extinguishment of debt	(1		)	6			—			—			5
Other income (expense), net	37			1			25			(38		)	25
(Loss) income before income taxes and equity in affiliated companies' net earnings (losses)	(165		)	121			2,005			8			1,969
Benefit from (provision for) income taxes	5			(17		)	(670		)	(3		)	(685		)
Equity in affiliated companies' net earnings (losses)	1,152			256			339			(1,745		)	2
Net income (loss)	992			360			1,674			(1,740		)	1,286
Net income and preferred dividends attributable to noncontrolling interests	—			—			(291		)	(3		)	(294		)
Net income (loss) attributable to common stockholders	$	992		$	360		$	1,383		$	(1,743	)	$	992
Other comprehensive income (loss)	4			—			4			(4		)	4
Total comprehensive income (loss)	$	996		$	360		$	1,387		$	(1,747	)	$	996

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Six Months Ended June 30, 2015

	FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Cash flow from operating activities:
Net (loss) income	$	(4,325	)	$	(5,680	)	$	(8,518	)	$	14,318		$	(4,205	)
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	2			223			1,638			(34		)	1,829
Impairment of oil and gas properties	—			2,052			3,717			21			5,790
Net gains on crude oil derivative contracts	—			(58		)	—			—			(58		)
Equity in losses (earnings) of consolidated subsidiaries	3,524			4,279			6,502			(14,306		)	(1		)
Other, net	(1,431		)	9			43			—			(1,379		)
Changes in working capital and other tax payments	2,222			(550		)	(1,870		)	8			(190		)
Net cash (used in) provided by operating activities	(8		)	275			1,512			7			1,786
Cash flow from investing activities:
Capital expenditures	—			(734		)	(2,787		)	(7		)	(3,528		)
Intercompany loans	(1,073		)	(794		)	—			1,867			—
Dividends from (investments in) consolidated subsidiaries	438			(31		)	74			(481		)	—
Other, net	(10		)	(1		)	137			10			136
Net cash (used in) provided by investing activities	(645		)	(1,560		)	(2,576		)	1,389			(3,392		)
Cash flow from financing activities:
Proceeds from debt	2,735			—			1,687			—			4,422
Repayments of debt	(1,690		)	—			(670		)	—			(2,360		)
Intercompany loans	—			1,321			546			(1,867		)	—
Cash dividends and distributions paid, and contributions received	(380		)	—			(481		)	421			(440		)
Other, net	(12		)	(37		)	(15		)	50			(14		)
Net cash provided by (used in) financing activities	653			1,284			1,067			(1,396		)	1,608
Net (decrease) increase in cash and cash equivalents	—			(1		)	3			—			2
Cash and cash equivalents at beginning of period	—			1			463			—			464
Cash and cash equivalents at end of period	$	—		$	—		$	466		$	—		$	466

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Six Months Ended June 30, 2014

	FCX			FM O&G LLC			Non-guarantor							Consolidated
	Issuer			Guarantor			Subsidiaries				Eliminations			FCX
Cash flow from operating activities:
Net income (loss)	$	992		$	360		$	1,674			$	(1,740	)	$	1,286
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	2			545			1,440				(8		)	1,979
Net losses on crude oil and natural gas derivative contracts	—			120			—				—			120
Net gain (loss) on early extinguishment of debt	1			(6		)	—				—			(5		)
Equity in (earnings) losses of consolidated subsidiaries	(1,152		)	(256		)	39				1,367			(2		)
Other, net	121			(12		)	(123		)		—			(14		)
Changes in working capital and other tax payments	(164		)	(2,165		)	1,552				—			(777		)
Net cash (used in) provided by operating activities	(200		)	(1,414		)	4,582				(381		)	2,587
Cash flow from investing activities:
Capital expenditures	—			(897		)	(2,665		)		—			(3,562		)
Acquisition of Deepwater GOM interests	—			—			(925		)		—			(925		)
Intercompany loans	1,318			1,629			—			—	(2,947		)	—
(Investments in) dividends from consolidated subsidiaries	(364		)	(96		)	1,079				(619		)	—
Net proceeds from sale of Eagle Ford shale assets	—			3,009			—				—			3,009
Other, net	—			(381		)	18				—			(363		)
Net cash provided by (used in) investing activities	954			3,264			(2,493		)		(3,566		)	(1,841		)
Cash flow from financing activities:
Proceeds from debt	890			—			358				—			1,248
Repayments of debt	(990		)	(224		)	(397		)		—			(1,611		)
Intercompany loans	—			(170		)	(2,777		)		2,947			—
Cash dividends and distributions paid, and contributions received	(653		)	(1,453		)	203				1,000			(903		)
Other, net	(1		)	(2		)	(4		)		—			(7		)
Net cash (used in) provided by financing activities	(754		)	(1,849		)	(2,617		)		3,947			(1,273		)
Net increase (decrease) in cash and cash equivalents	—			1			(528		)		—			(527		)
Cash and cash equivalents at beginning of period	—			—			1,985				—			1,985
Cash and cash equivalents at end of period	$	—		$	1		$	1,457			$	—		$	1,458

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Document and Entity Information Document - USD ($) $ in Billions	6 Months Ended
	Jun. 30, 2015	Jul. 31, 2015	Jun. 30, 2014
Document and Entity Information [Abstract]
Entity Registrant Name	FREEPORT-MCMORAN INC
Entity Central Index Key	0000831259
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 37.3
Entity Common Stock, Shares Outstanding		1,040,228,261
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2015

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New Accounting Standard (Unaudited)

6 Months Ended

Jun. 30, 2015

New Accounting Standards [Abstract]

New Accounting Standard

NEW ACCOUNTING STANDARDS

In April 2015, the Financial Accounting Standards Board issued an Accounting Standards Update (ASU) to simplify the presentation of debt issuance costs. This ASU requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. For public entities, this ASU is effective for annual periods beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption is permitted for financial statements that have not been previously issued. FCX adopted this ASU in first-quarter 2015 and retrospectively adjusted its previously issued financial statements. Upon adoption, FCX adjusted its December 31, 2014, balance sheet by decreasing other assets and long-term debt by $121 million for debt issuance costs related to corresponding debt balances. FCX elected to continue presenting debt issuance costs for its revolving credit facility as a deferred charge (asset) because of the volatility of its borrowings and repayments under the facility.

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Consolidated Statements of Comprehensive (Loss) Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Net (loss) income	$ (1,799)	$ 660	$ (4,205)	$ 1,286
Defined benefit plans:
Amortization of unrecognized amounts included in net periodic benefit costs	8	4	16	7
Foreign exchange gains (losses)	1	(3)	5	(3)
Other comprehensive income	9	1	21	4
Total comprehensive (loss) income	(1,790)	661	(4,184)	1,290
Total comprehensive income attributable to noncontrolling interests	(42)	(168)	(100)	(274)
Preferred dividends attributable to redeemable noncontrolling interest	(10)	(10)	(20)	(20)
Total comprehensive (loss) income attributable to common stockholders	$ (1,842)	$ 483	$ (4,304)	$ 996

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Debt and Equity Transactions (Unaudited)

6 Months Ended

Jun. 30, 2015

Debt and Equity Transactions [Abstract]

Debt and Equity Transactions

DEBT AND EQUITY TRANSACTIONS

Debt Transactions. At June 30, 2015, FCX had $20.9 billion in debt, which included additions for unamortized fair value adjustments of $225 million (primarily from the oil and gas acquisitions in 2013), and is net of reductions attributable to unamortized net discounts of $21 million and unamortized debt issuance costs of $116 million. Refer to Note 12 for discussion of a change in the presentation of debt issuance costs.

In February 2015, FCX's unsecured revolving credit facility and $4.0 billion bank term loan (Term Loan) were modified to amend the maximum total leverage ratio. In addition, the Term Loan amortization schedule was extended such that, as amended, the Term Loan’s scheduled payments total $205 million in 2016, $272 million in 2017, $1.0 billion in 2018, $313 million in 2019 and $1.3 billion in 2020, compared with the previous amortization schedule of $650 million in 2016, $200 million in 2017 and $2.2 billion in 2018.

At June 30, 2015, $985 million was outstanding and $42 million of letters of credit were issued under FCX's revolving credit facility, resulting in availability of approximately $3.0 billion, of which approximately $1.5 billion could be used for additional letters of credit.

At June 30, 2015, $1.3 billion was outstanding and no letters of credit were issued under Sociedad Minera Cerro Verde S.A.A.'s (Cerro Verde, FCX's mining subsidiary in Peru) credit facility, resulting in availability of $531 million. Cerro Verde's five-year, $1.8 billion senior unsecured credit facility is nonrecourse to FCX and the other shareholders of Cerro Verde.

In April 2014, FCX redeemed $210 million of the aggregate principal amount of FCX Oil & Gas Inc.'s (FM O&G, FCX's oil and gas subsidiary) outstanding 6.625% Senior Notes due 2021. In accordance with the terms of the senior notes, the redemption was funded with cash contributions to FM O&G by FCX in exchange for additional equity, which is eliminated in the consolidated financial statements. Holders of these senior notes received the principal amount together with the redemption premium and accrued and unpaid interest to the redemption date. As a result of the redemption, FCX recorded a gain on early extinguishment of debt of $6 million in second-quarter 2014.

Consolidated interest expense (excluding capitalized interest) totaled $215 million in second-quarter2015, $225 million in second-quarter2014, $425 million for the first six months of 2015 and $449 million for the first six months of 2014. Capitalized interest added to property, plant, equipment and mining development costs, net, totaled $47 million in second-quarter2015, $39 million in second-quarter2014, $92 million for the first six months of 2015 and $79 million for the first six months of 2014. Capitalized interest added to oil and gas properties not subject to amortization totaled $19 million in second-quarter2015, $22 million in second-quarter2014, $38 million for the first six months of 2015 and $45 million for the first six months of 2014.

Equity Transactions. On June 24, 2015, FCX's Board of Directors (the Board) declared a dividend of $0.1605 per share, which was paid on August 3, 2015, to common shareholders of record at the close of business on July 15, 2015. This common stock dividend consisted of $0.05 per share for FCX's regular quarterly dividend and $0.1105 per share as a one-time special dividend related to the settlement of the shareholder derivative litigation (refer to Note 9 for further discussion).

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Income Taxes (Unaudited)

6 Months Ended

Jun. 30, 2015

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

Variations in the relative proportions of jurisdictional income result in fluctuations to FCX's consolidated effective income tax rate. FCX’s consolidated effective income tax rate was 25 percent for the first six months of 2015 and 35 percent for the first six monthsof 2014. Geographic sources of FCX's (benefit from) provision for income taxes follow (in millions):

	Three Months Ended							Six Months Ended
	June 30,							June 30,
	2015				2014			2015				2014
U.S. operations	$	(829	)	a	$	149	b	$	(1,664	)	a	$	285	b
International operations	142				179			282				400
Total	$	(687	)		$	328		$	(1,382	)		$	685

a. As a result of the impairment to oil and gas properties, FCX recorded tax charges of $305 million for second-quarter2015 and $763 million for the first six months of 2015 to establish a valuation allowance primarily against U.S. federal alternative minimum tax credits. Excluding this charge, FCX's consolidated effective income tax rate was 38 percent for the first six months of 2015.

b. FCX recognized a $58 million charge for deferred taxes recorded in connection with the allocation of goodwill to the sale of Eagle Ford shale assets.

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Financial Instruments (Unaudited) (Tables)

6 Months Ended

Jun. 30, 2015

Financial Instruments [Abstract]

Unrealized gains (losses) for derivative financial instruments that are designated and qualify as fair value hedge transactions and for the related hedged item

A summary of gains (losses) recognized in revenues for derivative financial instruments related to commodity contracts that are designated and qualify as fair value hedge transactions, along with the unrealized gains (losses) on the related hedged item follows (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
Copper futures and swap contracts:
Unrealized gains (losses):
Derivative financial instruments	$	(4	)	$	12		$	2		$	—
Hedged item – firm sales commitments	4			(12		)	(2		)	—
Realized (losses) gains:
Matured derivative financial instruments	(1		)	(2		)	(11		)	(4		)

Schedule of Derivative Instruments

A summary of FCX’s embedded commodity derivatives at June 30, 2015, follows:

	Open Positions	Average Price Per Unit				Maturities Through
		Contract		Market
Embedded derivatives in provisional sales contracts:
Copper (millions of pounds)	572	$	2.68	$	2.58	November 2015
Gold (thousands of ounces)	229	1,189		1,174		September 2015
Embedded derivatives in provisional purchase contracts:
Copper (millions of pounds)	134	2.75		2.61		October 2015

At June 30, 2015, the outstanding 2015 crude oil option contracts, which settle monthly and cover approximately 15.5 million barrels over the remainder of 2015, follow:

		Daily Volumes (thousand barrels)	Average Strike Price (per barrel)a				Weighted-Average Deferred Premium  (per barrel)
2015 Period	Instrument Type		Floor		Floor Limit				Index
July - December	Put optionsb	84	$	90	$	70	$	6.89	Brent

a. The average strike prices do not reflect any premiums to purchase the put options.

b. If the index price is less than the per barrel floor, FCX receives the difference between the per barrel floor and the index price up to a maximum of $20 per barrel less the option premium. If the index price is at or above the per barrel floor, FCX pays the option premium and no cash settlement is received.

Realized and unrealized gains (losses) for derivative financial instruments that do not qualify as hedge transactions

A summary of the realized and unrealized (losses) gains recognized in (loss) income before income taxes and equity in affiliated companies’ net earnings for commodity contracts that do not qualify as hedge transactions, including embedded derivatives, follows (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
Embedded derivatives in provisional copper and gold
sales contractsa	$	(78	)	$	84		$	(150	)	$	(85	)
Crude oil optionsa	6			(68		)	58			(104		)
Natural gas swapsa	—			(2		)	—			(16		)
Copper forward contractsb	(6		)	4			(7		)	5

a. Amounts recorded in revenues. 

b. Amounts recorded in cost of sales as production and delivery costs.

Fair Values of Unsettled Derivative Financial Instruments

A summary of the fair values of unsettled commodity derivative financial instruments follows (in millions):

	June 30, 2015		December 31, 2014
Commodity Derivative Assets:
Derivatives not designated as hedging instruments:
Embedded derivatives in provisional copper and gold
sales/purchase contracts	$	21	$	15
Crude oil optionsa	174		316
Total derivative assets	$	195	$	331
Commodity Derivative Liabilities:
Derivatives designated as hedging instruments:
Copper futures and swap contractsb	$	5	$	7
Derivatives not designated as hedging instruments:
Embedded derivatives in provisional copper and gold
sales/purchase contracts	65		93
Copper forward contracts	1		—
Total derivative liabilities	$	71	$	100

a. Amounts are net of $106 million at June 30, 2015, and $210 million at December 31, 2014, for deferred premiums and accrued interest.

b. FCX paid $9 million to brokers at June 30, 2015, and $10 million at December 31, 2014, for margin requirements (recorded in other current assets).

A summary of these unsettled commodity contracts that are offset in the balance sheet follows (in millions):

	Assets				Liabilities
	June 30, 2015		December 31, 2014		June 30,  2015		December 31, 2014
Gross amounts recognized:
Commodity contracts:
Embedded derivatives in provisional
sales/purchase contracts	$	21	$	15	$	65	$	93
Crude oil derivatives	174		316		—		—
Copper derivatives	—		—		6		7
	195		331		71		100
Less gross amounts of offset:
Commodity contracts:
Embedded derivatives in provisional
sales/purchase contracts	1		1		1		1
Copper derivatives	—		—		—		—
	1		1		1		1
Net amounts presented in balance sheet:
Commodity contracts:
Embedded derivatives in provisional
sales/purchase contracts	20		14		64		92
Crude oil derivatives	174		316		—		—
Copper derivatives	—		—		6		7
	$	194	$	330	$	70	$	99
Balance sheet classification:
Trade accounts receivable	$	3	$	5	$	53	$	56
Other current assets	174		316		—		—
Accounts payable and accrued liabilities	17		9		17		43
	$	194	$	330	$	70	$	99

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Subsequent Events (Unaudited)

6 Months Ended

Jun. 30, 2015

Subsequent Events [Abstract]

Subsequent Events

SUBSEQUENT EVENTS

As reported in Note 13 of FCX's annual report on Form 10-K for the year ended December 31, 2014, PT-FI entered into a Memorandum of Understanding (MOU) with the Indonesian government in July 2014. Under the MOU, PT-FI provided a $115 million assurance bond to support its commitment for smelter development, agreed to increased royalty rates and agreed to pay export duties (which were set at 7.5 percent, declining to 5.0 percent when smelter development progress exceeds 7.5 percent and are eliminated when development progress exceeds 30 percent). The MOU also anticipated an amendment of the COW within six months to address other matters; however, no terms of the COW other than those relating to the smelter bond, increased royalties and export duties were changed. In January 2015, the MOU was extended to July 25, 2015, and it expired on that date. The increased royalty rates, export duties and smelter assurance bond remain in effect.

PT-FI is also required to apply for renewal of export permits at six-month intervals. On July 29, 2015, PT-FI's export permit was renewed through January 28, 2016. In connection with the renewal, export duties were reduced to 5.0 percent, as a result of smelter development progress.

FCX evaluated events after June 30, 2015, and through the date the consolidated financial statements were issued, and determined any events or transactions occurring during this period that would require recognition or disclosure are appropriately addressed in these consolidated financial statements.

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Contingencies and Commitments (Unaudited)

6 Months Ended

Jun. 30, 2015

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

CONTINGENCIES AND COMMITMENTS

Litigation. The following information includes a discussion of updates to previously reported legal proceedings included in Note 12 of FCX's annual report on Form 10-K for the year ended December 31, 2014, as updated in Note 8 of FCX's quarterly report on Form 10-Q for the quarterly period ended March 31, 2015.

Shareholder Litigation. On April 7, 2015, the Delaware Court of Chancery approved the settlement of FCX’s consolidated stockholder derivative litigation captioned In Re Freeport-McMoRan Copper & Gold Inc. Derivative Litigation, No. 8145-VCN, and awarded the plaintiffs legal fees and expenses. This settlement resolved all pending derivative claims against directors and officers of FCX challenging FCX's 2013 acquisitions of Plains Exploration & Production Company and McMoRan Exploration Co. During first-quarter 2015, insurers under FCX’s directors and officers liability insurance policies and other third parties funded an escrow account with the $125 million settlement amount, from which the proceeds, net of plaintiffs’ legal fees and expenses totaling $33 million, were released to FCX in May 2015. Upon the release of funds, FCX recognized a gain of $92 million in second-quarter 2015. As a result and in accordance with the approved settlement terms, FCX's Board declared a special dividend that was paid on August 3, 2015, together with the regular quarterly dividend paid on the same day (refer to Note 6 for further discussion).

Tax and Other Matters. There were no significant changes to the Cerro Verde royalty dispute or other Peruvian tax matters during the second quarter of 2015 (refer to Note 12 of FCX’s annual report on Form 10-K for the year ended December 31, 2014, for further discussion of these matters).

Indonesia Tax Matters. The following information includes a discussion of updates to previously reported Indonesia tax matters included in Note 12 of FCX’s annual report on Form 10-K for the year ended December 31, 2014, as updated in Note 8 of FCX's quarterly report on Form 10-Q for the quarterly period ended March 31, 2015.

PT-FI received assessments from the local regional tax authority in Papua, Indonesia, for additional taxes and penalties related to water rights tax payments for the period from January 2011 through June 2015. PT-FI has filed or will file objections to these assessments. In March 2015, the local government of Papua rejected PT-FI’s objections to the assessments related to the period from January 2011 through December 2014, and in April 2015, PT-FI filed appeals with the Indonesian tax court. The aggregate amount of all assessments received through August 3, 2015, including penalties, was 2.5 trillion Indonesian rupiah ($190 million based on exchange rates at June 30, 2015). Additional penalties, which could be significant, may be assessed depending on the outcome of the appeals process. No amounts have been accrued for these assessments as of June 30, 2015, because PT-FI believes its Contract of Work (COW) exempts it from these payments and that it has the right to contest these assessments in the tax court and ultimately the Indonesian Supreme Court.

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Financial Instruments (Unaudited)

6 Months Ended

Jun. 30, 2015

Financial Instruments [Abstract]

Financial Instruments

FINANCIAL INSTRUMENTS

FCX does not purchase, hold or sell derivative financial instruments unless there is an existing asset or obligation, or it anticipates a future activity that is likely to occur and will result in exposure to market risks, which FCX intends to offset or mitigate. FCX does not enter into any derivative financial instruments for speculative purposes, but has entered into derivative financial instruments in limited instances to achieve specific objectives. These objectives principally relate to managing risks associated with commodity price changes, foreign currency exchange rates and interest rates.

Commodity Contracts.  From time to time, FCX has entered into derivative contracts to hedge the market risk associated with fluctuations in the prices of commodities it purchases and sells. As a result of the acquisition of the oil and gas business in 2013, FCX assumed a variety of crude oil and natural gas commodity derivatives to hedge the exposure to the volatility of crude oil and natural gas commodity prices. Derivative financial instruments used by FCX to manage its risks do not contain credit risk-related contingent provisions. As of June 30, 2015, and December 31, 2014, FCX had no price protection contracts relating to its mine production. A discussion of FCX’s derivative contracts and programs follows.

Derivatives Designated as Hedging Instruments – Fair Value Hedges

Copper Futures and Swap Contracts. Some of FCX’s U.S. copper rod customers request a fixed market price instead of the Commodity Exchange Inc. (COMEX), a division of the New York Mercantile Exchange, average copper price in the month of shipment. FCX hedges this price exposure in a manner that allows it to receive the COMEX average price in the month of shipment while the customers pay the fixed price they requested. FCX accomplishes this by entering into copper futures or swap contracts. Hedging gains or losses from these copper futures and swap contracts are recorded in revenues. FCX did not have any significant gains or losses during the three-month or six-month periods ended June 30, 2015 and 2014, resulting from hedge ineffectiveness. At June 30, 2015, FCX held copper futures and swap contracts that qualified for hedge accounting for 51 million pounds at an average contract price of $2.71 per pound, with maturities through May 2017.

A summary of gains (losses) recognized in revenues for derivative financial instruments related to commodity contracts that are designated and qualify as fair value hedge transactions, along with the unrealized gains (losses) on the related hedged item follows (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
Copper futures and swap contracts:
Unrealized gains (losses):
Derivative financial instruments	$	(4	)	$	12		$	2		$	—
Hedged item – firm sales commitments	4			(12		)	(2		)	—
Realized (losses) gains:
Matured derivative financial instruments	(1		)	(2		)	(11		)	(4		)

Derivatives Not Designated as Hedging Instruments

Embedded Derivatives. As described in Note 1 to FCX's annual report on Form 10-K for the year ended December 31, 2014, under “Revenue Recognition,” certain FCX copper concentrate, copper cathode and gold sales contracts provide for provisional pricing primarily based on the London Metal Exchange (LME) copper price or the COMEX copper price and the London Bullion Market Association (London) gold price at the time of shipment as specified in the contract. Similarly, FCX purchases copper under contracts that provide for provisional pricing. FCX applies the normal purchases and normal sales scope exception in accordance with derivatives and hedge accounting guidance to the host sales agreements since the contracts do not allow for net settlement and always result in physical delivery. Sales and purchases with a provisional sales price contain an embedded derivative (i.e., the price settlement mechanism is settled after the time of delivery) that is required to be bifurcated from the host contract. The host contract is the sale or purchase of the metals contained in the concentrates or cathodes at the then-current LME or COMEX copper price or the London gold price as defined in the contract. Mark-to-market price fluctuations from these embedded derivatives are recorded through the settlement date and are reflected in revenues for sales contracts and in cost of sales as production and delivery costs for purchase contracts.

A summary of FCX’s embedded commodity derivatives at June 30, 2015, follows:

	Open Positions	Average Price Per Unit				Maturities Through
		Contract		Market
Embedded derivatives in provisional sales contracts:
Copper (millions of pounds)	572	$	2.68	$	2.58	November 2015
Gold (thousands of ounces)	229	1,189		1,174		September 2015
Embedded derivatives in provisional purchase contracts:
Copper (millions of pounds)	134	2.75		2.61		October 2015

Crude Oil Contracts. As a result of the acquisition of the oil and gas business, FCX has derivative contracts extending through 2015 that consist of crude oil options. These crude oil derivatives are not designated as hedging instruments and are recorded at fair value with the mark-to-market gains and losses recorded in revenues.

The crude oil options were entered into by the oil and gas business to protect the realized price of a portion of expected future sales in order to limit the effects of crude oil price decreases. At June 30, 2015, these contracts are composed of crude oil put spreads consisting of put options with a floor limit. The premiums associated with put options are deferred until the settlement period. At June 30, 2015, the deferred option premiums and accrued interest associated with the crude oil option contracts totaled $106 million, which was included as a component of the fair value of the crude oil options contracts. At June 30, 2015, the outstanding 2015 crude oil option contracts, which settle monthly and cover approximately 15.5 million barrels over the remainder of 2015, follow:

		Daily Volumes (thousand barrels)	Average Strike Price (per barrel)a				Weighted-Average Deferred Premium  (per barrel)
2015 Period	Instrument Type		Floor		Floor Limit				Index
July - December	Put optionsb	84	$	90	$	70	$	6.89	Brent

a. The average strike prices do not reflect any premiums to purchase the put options.

b. If the index price is less than the per barrel floor, FCX receives the difference between the per barrel floor and the index price up to a maximum of $20 per barrel less the option premium. If the index price is at or above the per barrel floor, FCX pays the option premium and no cash settlement is received.

Copper Forward Contracts. Atlantic Copper, FCX's wholly owned smelting and refining unit in Spain, enters into copper forward contracts designed to hedge its copper price risk whenever its physical purchases and sales pricing periods do not match. These economic hedge transactions are intended to hedge against changes in copper prices, with the mark-to-market hedging gains or losses recorded in cost of sales. At June 30, 2015, Atlantic Copper held net copper forward purchase contracts for 31 million pounds at an average contract price of $2.65 per pound, with maturities through August 2015.

Summary of (Losses) Gains. A summary of the realized and unrealized (losses) gains recognized in (loss) income before income taxes and equity in affiliated companies’ net earnings for commodity contracts that do not qualify as hedge transactions, including embedded derivatives, follows (in millions):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2015			2014			2015			2014
Embedded derivatives in provisional copper and gold
sales contractsa	$	(78	)	$	84		$	(150	)	$	(85	)
Crude oil optionsa	6			(68		)	58			(104		)
Natural gas swapsa	—			(2		)	—			(16		)
Copper forward contractsb	(6		)	4			(7		)	5

a. Amounts recorded in revenues. 

b. Amounts recorded in cost of sales as production and delivery costs.

Unsettled Derivative Financial Instruments

A summary of the fair values of unsettled commodity derivative financial instruments follows (in millions):

	June 30, 2015		December 31, 2014
Commodity Derivative Assets:
Derivatives not designated as hedging instruments:
Embedded derivatives in provisional copper and gold
sales/purchase contracts	$	21	$	15
Crude oil optionsa	174		316
Total derivative assets	$	195	$	331
Commodity Derivative Liabilities:
Derivatives designated as hedging instruments:
Copper futures and swap contractsb	$	5	$	7
Derivatives not designated as hedging instruments:
Embedded derivatives in provisional copper and gold
sales/purchase contracts	65		93
Copper forward contracts	1		—
Total derivative liabilities	$	71	$	100

a. Amounts are net of $106 million at June 30, 2015, and $210 million at December 31, 2014, for deferred premiums and accrued interest.

b. FCX paid $9 million to brokers at June 30, 2015, and $10 million at December 31, 2014, for margin requirements (recorded in other current assets).

FCX's commodity contracts have netting arrangements with counterparties with which the right of offset exists, and it is FCX's policy to offset balances by counterparty on the balance sheet. FCX's embedded derivatives on provisional sales/purchases are netted with the corresponding outstanding receivable/payable balances. A summary of these unsettled commodity contracts that are offset in the balance sheet follows (in millions):

	Assets				Liabilities
	June 30, 2015		December 31, 2014		June 30,  2015		December 31, 2014
Gross amounts recognized:
Commodity contracts:
Embedded derivatives in provisional
sales/purchase contracts	$	21	$	15	$	65	$	93
Crude oil derivatives	174		316		—		—
Copper derivatives	—		—		6		7
	195		331		71		100
Less gross amounts of offset:
Commodity contracts:
Embedded derivatives in provisional
sales/purchase contracts	1		1		1		1
Copper derivatives	—		—		—		—
	1		1		1		1
Net amounts presented in balance sheet:
Commodity contracts:
Embedded derivatives in provisional
sales/purchase contracts	20		14		64		92
Crude oil derivatives	174		316		—		—
Copper derivatives	—		—		6		7
	$	194	$	330	$	70	$	99
Balance sheet classification:
Trade accounts receivable	$	3	$	5	$	53	$	56
Other current assets	174		316		—		—
Accounts payable and accrued liabilities	17		9		17		43
	$	194	$	330	$	70	$	99

Credit Risk.  FCX is exposed to credit loss when financial institutions with which FCX has entered into derivative transactions (commodity, foreign exchange and interest rate swaps) are unable to pay. To minimize the risk of such losses, FCX uses counterparties that meet certain credit requirements and periodically reviews the creditworthiness of these counterparties. FCX does not anticipate that any of the counterparties it deals with will default on their obligations. As of June 30, 2015, the maximum amount of credit exposure associated with derivative transactions was $226 million.

Other Financial Instruments.  Other financial instruments include cash and cash equivalents, accounts receivable, restricted cash, investment securities, legally restricted funds, accounts payable and accrued liabilities, dividends payable and long-term debt. The carrying value for cash and cash equivalents (which included time deposits of $27 million at June 30, 2015, and $48 million at December 31, 2014), accounts receivable, restricted cash, accounts payable and accrued liabilities, and dividends payable approximates fair value because of their short-term nature and generally negligible credit losses (refer to Note 8 for the fair values of investment securities, legally restricted funds and long-term debt).

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Fair Value Measurement (Unaudited)

6 Months Ended

Jun. 30, 2015

Fair Value Disclosures [Abstract]

Fair Value Measurement

FAIR VALUE MEASUREMENT

Fair value accounting guidance includes a hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 inputs) and the lowest priority to unobservable inputs (Level 3 inputs).

FCX recognizes transfers between levels at the end of the reporting period. FCX did not have any significant transfers in or out of Level 1, 2 or 3 for second-quarter 2015. A summary of the carrying amount and fair value of FCX’s financial instruments, other than cash and cash equivalents, accounts receivable, restricted cash, accounts payable and accrued liabilities, and dividends payable (refer to Note 7), follows (in millions):

	At June 30, 2015
	Carrying		Fair Value
	Amount		Total		Level 1		Level 2		Level 3
Assets
Investment securities:a,b
U.S. core fixed income fund	$	23	$	23	$	—	$	23	$	—
Money market funds	22		22		22		—		—
Equity securities	3		3		3		—		—
Total	48		48		25		23		—
Legally restricted funds:a,b,c,d
U.S. core fixed income fund	51		51		—		51		—
Government bonds and notes	35		35		—		35		—
Corporate bonds	28		28		—		28		—
Government mortgage-backed securities	24		24		—		24		—
Asset-backed securities	14		14		—		14		—
Money market funds	9		9		9		—		—
Collateralized mortgage-backed securities	8		8		—		8		—
Municipal bonds	1		1		—		1		—
Total	170		170		9		161		—
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross asset position	21		21		—		21		—
Crude oil options	174		174		—		—		174
Total	195		195		—		21		174
Total assets			$	413	$	34	$	205	$	174
Liabilities
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross liability position	$	65	$	65	$	—	$	65	$	—
Copper futures and swap contracts	5		5		5		—		—
Copper forward contracts	1		1		—		1		—
Total	71		71		5		66		—
Long-term debt, including current portionf	20,902		20,191		—		20,191		—
Total liabilities			$	20,262	$	5	$	20,257	$	—

	At December 31, 2014
	Carrying		Fair Value
	Amount		Total		Level 1		Level 2		Level 3
Assets
Investment securities:a,b
U.S. core fixed income fund	$	23	$	23	$	—	$	23	$	—
Money market funds	20		20		20		—		—
Equity securities	3		3		3		—		—
Total	46		46		23		23		—
Legally restricted funds:a,b,c,d
U.S. core fixed income fund	52		52		—		52		—
Government bonds and notes	39		39		—		39		—
Corporate bonds	27		27		—		27		—
Government mortgage-backed securities	19		19		—		19		—
Asset-backed securities	17		17		—		17		—
Money market funds	11		11		11		—		—
Collateralized mortgage-backed securities	6		6		—		6		—
Municipal bonds	1		1		—		1		—
Total	172		172		11		161		—
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross asset position	15		15		—		15		—
Crude oil options	316		316		—		—		316
Total	331		331		—		15		316
Total assets			$	549	$	34	$	199	$	316
Liabilities
Derivatives:a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross liability position	$	93	$	93	$	—	$	93	$	—
Copper futures and swap contracts	7		7		6		1		—
Total	100		100		6		94		—
Long-term debt, including current portionf	18,849		18,735		—		18,735		—
Total liabilities			$	18,835	$	6	$	18,829	$	—

a. Recorded at fair value. 

b. Current portion included in other current assets and long-term portion included in other assets.

c. Excludes time deposits (which approximated fair value) included in other assets of $117 million at June 30, 2015, and $115 million at December 31, 2014, associated with an assurance bond to support PT Freeport Indonesia's (PT-FI) commitment for smelter development in Indonesia.

d. Excludes time deposits (which approximated fair value) included in other current assets of $10 million at June 30, 2015, and $8 million at December 31, 2014, associated with a reclamation guarantee at PT-FI. Also, excludes a time deposit of $9 million at December 31, 2014, associated with a customs audit assessment.

e. Refer to Note 7 for further discussion and balance sheet classifications. Crude oil options are net of $106 million at June 30, 2015, and $210 million at December 31, 2014, for deferred premiums and accrued interest.

f. Recorded at cost except for debt assumed in acquisitions, which were recorded at fair value at the respective acquisition dates.

Valuation Techniques

Money market funds are classified within Level 1 of the fair value hierarchy because they are valued using quoted market prices in active markets.

The U.S. core fixed income fund is valued at net asset value. The fund strategy seeks total return consisting of income and capital appreciation primarily by investing in a broad range of investment-grade debt securities, including U.S. government obligations, corporate bonds, mortgage-backed securities, asset-backed securities and money market instruments. There are no restrictions on redemptions (usually within one business day of notice) and, as such, this fund is classified within Level 2 of the fair value hierarchy.

Fixed income securities (government securities, corporate bonds, asset-backed securities, collateralized mortgage-backed securities and municipal bonds) are valued using a bid evaluation price or a mid-evaluation price. A bid evaluation price is an estimated price at which a dealer would pay for a security. A mid-evaluation price is the average of the estimated price at which a dealer would sell a security and the estimated price at which a dealer would pay for a security. These evaluations are based on quoted prices, if available, or models that use observable inputs and, as such, are classified within Level 2 of the fair value hierarchy.

Equity securities are valued at the closing price reported on the active market on which the individual securities are traded and, as such, are classified within Level 1 of the fair value hierarchy.

FCX’s embedded derivatives on provisional copper concentrate, copper cathode and gold purchases and sales are valued using quoted monthly LME or COMEX copper forward prices and the London gold forward price at each reporting date based on the month of maturity (refer to Note 7 for further discussion); however, FCX's contracts themselves are not traded on an exchange. As a result, these derivatives are classified within Level 2 of the fair value hierarchy.

FCX's derivative financial instruments for crude oil options are valued using an option pricing model, which uses various inputs including Intercontinental Exchange Holdings, Inc. crude oil prices, volatilities, interest rates and contract terms. Valuations are adjusted for credit quality, using the counterparties' credit quality for asset balances and FCX's credit quality for liability balances (which considers the impact of netting agreements on counterparty credit risk, including whether the position with the counterparty is a net asset or net liability). For asset balances, FCX uses the credit default swap value for counterparties when available or the spread between the risk-free interest rate and the yield rate on the counterparties' publicly traded debt for similar instruments. The crude oil options are classified within Level 3 of the fair value hierarchy because the inputs used in the valuation models are not observable for the full term of the instruments. The significant unobservable inputs used in the fair value measurement of the crude oil options are implied volatilities and deferred premiums. Significant increases (decreases) in implied volatilities in isolation would result in a significantly higher (lower) fair value measurement. The implied volatilities ranged from 28 percent to 41 percent, with a weighted average of 32 percent. The weighted-average cost of deferred premiums totals $6.89 per barrel at June 30, 2015. Refer to Note 7 for further discussion of these derivative financial instruments.

FCX’s derivative financial instruments for copper futures and swap contracts and copper forward contracts that are traded on the respective exchanges are classified within Level 1 of the fair value hierarchy because they are valued using quoted monthly COMEX or LME prices at each reporting date based on the month of maturity (refer to Note 7 for further discussion). Certain of these contracts are traded on the over-the-counter market and are classified within Level 2 of the fair value hierarchy based on COMEX and LME forward prices.

Long-term debt, including the current portion, is not actively traded and is valued using prices obtained from a readily available pricing source and, as such, is classified within Level 2 of the fair value hierarchy.

The techniques described above may produce a fair value calculation that may not be indicative of net realizable value or reflective of future fair values. Furthermore, while FCX believes its valuation techniques are appropriate and consistent with other market participants, the use of different techniques or assumptions to determine fair value of certain financial instruments could result in a different fair value measurement at the reporting date. There have been no changes in the techniques used at June 30, 2015.

A summary of the changes in the fair value of FCX's most significant Level 3 instruments, crude oil options, follows (in millions):

	Crude Oil
	Options
Fair value at December 31, 2014	$	316
Net realized gains	21
Net unrealized gains included in earnings related to assets and liabilities   still held at the end of the period	36			a
Net settlement receipts	(199		)	b
Fair value at June 30, 2015	$	174

a. Includes net unrealized gains of $37 million, partially offset by $1 million of interest expense associated with the deferred premiums.

b. Includes interest payments of $2 million.

XML

Business Segments (Unaudited)

6 Months Ended

Jun. 30, 2015

Segment Reporting [Abstract]

Business Segments

BUSINESS SEGMENTS

FCX has organized its mining operations into five primary divisions – North America copper mines, South America mining, Indonesia mining, Africa mining and Molybdenum mines. Notwithstanding this structure, FCX internally reports information on a mine-by-mine basis for its mining operations. Therefore, FCX concluded that its operating segments include individual mines or operations relative to its mining operations. For oil and gas operations, FCX determines its operating segments on a country-by-country basis. Operating segments that meet certain thresholds are reportable segments, which are separately disclosed in the following table.

Intersegment Sales. Intersegment sales between FCX’s mining operations are based on similar arms-length transactions with third parties at the time of the sale. Intersegment sales may not be reflective of the actual prices ultimately realized because of a variety of factors, including additional processing, timing of sales to unaffiliated customers and transportation premiums.

FCX defers recognizing profits on sales from its mines to other divisions, including Atlantic Copper (FCX's wholly owned smelter and refinery in Spain) and on 25 percent of PT-FI's sales to PT Smelting (FCX's 25 percent-owned smelter and refinery in Indonesia), until final sales to third parties occur. Quarterly variations in ore grades, the timing of intercompany shipments and changes in product prices result in variability in FCX's net deferred profits and quarterly earnings.

Allocations. FCX allocates certain operating costs, expenses and capital expenditures to its operating divisions and individual segments. However, not all costs and expenses applicable to an operation are allocated. U.S. federal and state income taxes are recorded and managed at the corporate level (included in corporate, other & eliminations), whereas foreign income taxes are recorded and managed at the applicable country level. In addition, most mining exploration and research activities are managed on a consolidated basis, and those costs along with some selling, general and administrative costs are not allocated to the operating divisions or individual segments. Accordingly, the following segment information reflects management determinations that may not be indicative of what the actual financial performance of each operating division or segment would be if it was an independent entity.

Financial Information by Business Segments

(In millions)	Mining Operations
	North America Copper Mines							South America							Indonesia				Africa
																											Atlantic			Other										Corporate,
																					Molyb-						Copper			Mining						U.S.				Other
			Other					Cerro			Other										denum				Rod &		Smelting			& Elimi-				Total		Oil & Gas				& Elimi-			FCX
	Morenci		Mines			Total		Verde			Minesa		Total		Grasberg				Tenke		Mines				Refining		& Refining			nations				Mining		Operationsb				nations			Total
Three Months Ended June 30, 2015
Revenues:
Unaffiliated customers	$	180	$	92		$	272	$	195		$	221	$	416	$	792		c	$	310	$	—			$	1,089	$	495		$	305		d	$	3,679	$	569		e	$	—		$	4,248
Intersegment	427		706			1,133		37			—		37		(2		)	f	41		102				8		5			(1,324		)		—		—				—			—
Production and delivery	386		576		g	962		165			150		315		455				190		84			g	1,088		468			(997		)	g	2,565		281				2			2,848
Depreciation, depletion and amortization	55		84			139		40			32		72		78				57		25				3		9			19				402		485				3			890
Impairment of oil and gas properties	—		—			—		—			—		—		—				—		—				—		—			—				—		2,686				—			2,686
Selling, general and administrative expenses	—		2			2		—			1		1		25				3		—				—		4			5				40		49				62			151
Mining exploration and research expenses	—		2			2		—			—		—		—				—		—				—		—			34				36		—				—			36
Environmental obligations and shutdown costs	—		—			—		—			—		—		—				—		—				—		—			11				11		—				—			11
Operating income (loss)	166		134			300		27			38		65		232				101		(7		)		6		19			(91		)		625		(2,932		)		(67		)	(2,374		)
Interest expense, net	—		1			1		—			—		—		—				—		—				—		2			39				42		41				66			149
Provision for (benefit from) income taxes	—		—			—		(5		)	11		6		95				27		—				—		—			—				128		—				(815		)	(687		)
Total assets at June 30, 2015	3,806		5,582			9,388		8,567			1,935		10,502		8,959				5,125		2,052				286		786			1,336				38,434		15,393				181			54,008
Capital expenditures	79		28			107		444			13		457		213				58		4				—		4			11				854		777				30			1,661
Three Months Ended June 30, 2014
Revenues:
Unaffiliated customers	$	52	$	55		$	107	$	421		$	524	$	945	$	523		c	$	386	$	—			$	1,234	$	623		$	468		d	$	4,286	$	1,236		e	$	—		$	5,522
Intersegment	474		888			1,362		23			63		86		—				32		170				8		6			(1,664		)		—		—				—			—
Production and delivery	312		558			870		195			335		530		511				198		81				1,233		618			(1,287		)		2,754		329				(1		)	3,082
Depreciation, depletion and amortization	43		85			128		43			52		95		54				63		24				3		10			17				394		616				3			1,013
Selling, general and administrative expenses	1		—			1		1			1		2		25				3		—				—		5			6				42		59				63			164
Mining exploration and research expenses	—		2			2		—			—		—		—				—		—				—		—			32				34		—				—			34
Environmental obligations and shutdown costs	—		—			—		—			—		—		—				—		—				—		—			76				76		—				—			76
Operating income (loss)	170		298			468		205			199		404		(67		)		154		65				6		(4		)	(40		)		986		232				(65		)	1,153
Interest expense, net	—		1			1		—			—		—		—				—		—				—		3			18				22		74				68			164
Provision for (benefit from) income taxes	—		—			—		73			67		140		(33		)		33		—				—		—			—				140		—				188			328
Total assets at June 30, 2014	3,675		5,822			9,497		6,876			3,791		10,667		7,972				4,952		2,095				299		882			1,127				37,491		25,293				1,119			63,903
Capital expenditures	289		35			324		391			25		416		243				29		14				1		5			17				1,049		903				(2		)	1,950

a. Second-quarter 2014 includes the results of the Candelaria and Ojos del Salado mining operations, which were sold in November 2014.

b. Second-quarter 2014 includes the results from Eagle Ford, which was sold in June 2014.

c. Includes PT-FI’s sales to PT Smelting totaling $293 million in second-quarter2015 and $540 million in second-quarter2014.

d. Includes revenues from FCX's molybdenum sales company, which includes sales of molybdenum produced by the Molybdenum mines and by certain of the North and South America copper mines.

e. Includes net mark-to-market gains (losses) associated with crude oil and natural gas derivative contracts totaling $6 million in second-quarter2015 and $(70) million in second-quarter2014.

f. Amounts include net reductions for provisional pricing adjustments to prior period open sales. There were no intersegment sales from Grasberg in second-quarter 2015.

g. Includes LCM inventory adjustments totaling $11 million at other North America copper mines, $3 million at Molybdenum mines and $45 million at other mining & eliminations (see Note 4).

(In millions)	Mining Operations
	North America Copper Mines									South America								Indonesia				Africa
																														Atlantic			Other											Corporate,
																								Molyb-						Copper			Mining							U.S.				Other
			Other							Cerro		Other												denum				Rod &		Smelting			& Elimi-				Total			Oil & Gas				& Elimi-			FCX
	Morenci		Mines				Total			Verde		Minesa				Total		Grasberg				Tenke		Mines				Refining		& Refining			nations				Mining			Operationsb				nations			Total
Six Months Ended June 30, 2015
Revenues:
Unaffiliated customers	$	286	$	207			$	493		$	443	$	452			$	895	$	1,413		c	$	692	$	—			$	2,151	$	1,035		$	653		d	$	7,332		$	1,069		e	$	—		$	8,401
Intersegment	877		1,370				2,247			51		(7		)	f	44		(16		)	f	69		215				15		11			(2,585		)		—			—				—			—
Production and delivery	760		1,145			g	1,905			363		297				660		894				425		167			g	2,151		987			(1,998		)	g	5,191			564				5			5,760
Depreciation, depletion and amortization	106		166				272			77		70				147		148				130		51				5		19			35				807			1,015				7			1,829
Impairment of oil and gas properties	—		—				—			—		—				—		—				—		—				—		—			—				—			5,790				—			5,790
Selling, general and administrative expenses	1		2				3			1		1				2		50				6		—				—		9			11				81			103				121			305
Mining exploration and research expenses	—		5				5			—		—				—		—				—		—				—		—			64				69			—				—			69
Environmental obligations and shutdown costs	—		—				—			—		—				—		—				—		—				—		—			24				24			—				—			24
Net gain on sales of assets	—		(39		)		(39		)	—		—				—		—				—		—				—		—			—				(39		)	—				—			(39		)
Operating income (loss)	296		298				594			53		77				130		305				200		(3		)		10		31			(68		)		1,199			(6,403		)		(133		)	(5,337		)
Interest expense, net	1		1				2			1		—				1		—				—		—				—		5			79				87			78				130			295
Provision for (benefit from) income taxes	—		—				—			—		30				30		124				53		—				—		—			—				207			—				(1,589		)	(1,382		)
Capital expenditures	163		51				214			875		27				902		438				97		7				1		8			27				1,694			1,795				39			3,528
Six Months Ended June 30, 2014
Revenues:
Unaffiliated customers	$	75	$	116			$	191		$	701	$	946			$	1,647	$	985		c	$	692	$	—			$	2,380	$	1,211		$	904		d	$	8,010		$	2,497		e	$	—		$	10,507
Intersegment	918		1,646				2,564			87		195				282		8				53		296				16		11			(3,230		)		—			—				—			—
Production and delivery	595		1,061				1,656			360		646				1,006		894				350		157				2,381		1,206			(2,470		)		5,180			640				(1		)	5,819
Depreciation, depletion and amortization	77		158				235			79		103				182		102				114		46				5		20			36				740			1,232				7			1,979
Selling, general and administrative expenses	1		1				2			2		2				4		46				6		—				—		9			13				80			116				103			299
Mining exploration and research expenses	—		4				4			—		—				—		—				—		—				—		—			60				64			—				—			64
Environmental obligations and shutdown costs	—		—				—			—		—				—		—				—		—				—		—			82				82			—				—			82
Operating income (loss)	320		538				858			347		390				737		(49		)		275		93				10		(13		)	(47		)		1,864			509				(109		)	2,264
Interest expense, net	1		1				2			—		—				—		—				—		—				—		7			36				45			150				130			325
Provision for (benefit from) income taxes	—		—				—			130		137				267		(15		)		57		—				—		—			—				309			—				376			685
Capital expenditures	533		94				627			791		48				839		479				60		33				2		6			27				2,073			1,484				5			3,562

a. The first six months of 2014 include the results of the Candelaria and Ojos del Salado mining operations, which were sold in November 2014.

b. The first six months of 2014 include the results from Eagle Ford, which was sold in June 2014.

c. Includes PT-FI’s sales to PT Smelting totaling $643 million for the first six months of 2015 and $913 million for the first six months of 2014.

d. Includes revenues from FCX's molybdenum sales company, which includes sales of molybdenum produced by the Molybdenum mines and by certain of the North and South America copper mines.

e. Includes net mark-to-market gains (losses) associated with crude oil and natural gas derivative contracts totaling $58 million for the first six months2015 and $(120) million for the first six months of 2014.

f. Amounts include net reductions for provisional pricing adjustments to prior period open sales. There were no intersegment sales from El Abra or Grasberg for the first six months of 2015.

g. Includes LCM inventory adjustments totaling $11 million at other North America copper mines, $3 million at Molybdenum mines and $49 million at other mining & eliminations (see Note 4).

XML

Financial Instruments (Unaudited) (Details) - Commodity Contract [Member] - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Fair Value Hedging [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative financial instruments		$ (4)	$ 12	$ 2	$ 0
Hedged item – firm sales commitments		4	(12)	(2)	0
Matured derivative financial instruments		(1)	(2)	(11)	(4)
Derivatives not designated as hedging instruments [Member] | Embedded derivatives in provisional sales contracts [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized and unrealized gains (losses)	[1]	(78)	84	(150)	(85)
Derivatives not designated as hedging instruments [Member] | Copper forward contracts [Member] | Amounts recorded in Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized and unrealized gains (losses)	[2]	(6)	4	(7)	5
Derivatives not designated as hedging instruments [Member] | Plains Exploration & Production Company [Member] | Crude Oil Options [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized and unrealized gains (losses)	[1]	6	(68)	58	(104)
Derivatives not designated as hedging instruments [Member] | Plains Exploration & Production Company [Member] | Natural gas swaps [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Realized and unrealized gains (losses)	[1]	$ 0	$ (2)	$ 0	$ (16)

[1] Amounts recorded in revenues.

[2] Amounts recorded in cost of sales as production and delivery costs.

XML

Inventories, Including Long-Term Mill and Leach Stockpiles (Unaudited) (Tables)

6 Months Ended

Jun. 30, 2015

Inventories, Including Long Term Mill and Leach Stockpiles [Abstract]

Components of inventories

The components of inventories follow (in millions):

	June 30, 2015		December 31, 2014
Current inventories:
Mill stockpiles	$	130	$	86
Leach stockpiles	1,803		1,828
Total current mill and leach stockpiles	$	1,933	$	1,914
Total materials and supplies, neta	$	2,014	$	1,886
Raw materials (primarily concentrates)	$	306	$	288
Work-in-process	155		174
Finished goods	1,023		1,099
Total product inventories	$	1,484	$	1,561
Long-term inventories:
Mill stockpiles	$	361	$	360
Leach stockpiles	1,916		1,819
Total long-term mill and leach stockpilesb	$	2,277	$	2,179

a. Materials and supplies inventory was net of obsolescence reserves totaling $25 million at June 30, 2015, and $20 million at December 31, 2014.

b. Estimated metals in stockpiles not expected to be recovered within the next 12 months.

XML

Guarantor Financial Statements (Unaudited) (Tables)

6 Months Ended

Jun. 30, 2015

Guarantor Financial Statements [Abstract]

Condensed Consolidating Balance Sheets [Table Text Block]

CONDENSED CONSOLIDATING BALANCE SHEET

June 30, 2015

	FCX			FM O&G LLC		Non-guarantor					Consolidated
	Issuer			Guarantor		Subsidiaries		Eliminations			FCX
ASSETS
Current assets	$	257		$	2,900	$	9,665	$	(4,125	)	$	8,697
Property, plant, equipment and mining development costs, net	20			51		27,024		—			27,095
Oil and gas properties, net - full cost method:
Subject to amortization, less accumulated amortization	—			1,507		3,142		—			4,649
Not subject to amortization	—			2,649		6,659		4			9,312
Investments in consolidated subsidiaries	24,153			2,216		4,019		(30,388		)	—
Other assets	9,991			4,703		4,179		(14,618		)	4,255
Total assets	$	34,421		$	14,026	$	54,688	$	(49,127	)	$	54,008
LIABILITIES AND EQUITY
Current liabilities	$	3,106		$	433	$	5,325	$	(4,125	)	$	4,739
Long-term debt, less current portion	15,841			5,181		10,221		(11,132		)	20,111
Deferred income taxes	1,613		a	—		3,257		—			4,870
Environmental and asset retirement obligations, less current portion	—			307		3,409		—			3,716
Other liabilities	56			3,361		1,829		(3,486		)	1,760
Total liabilities	20,616			9,282		24,041		(18,743		)	35,196
Redeemable noncontrolling interest	—			—		757		—			757
Equity:
Stockholders' equity	13,805			4,744		26,173		(30,917		)	13,805
Noncontrolling interests	—			—		3,717		533			4,250
Total equity	13,805			4,744		29,890		(30,384		)	18,055
Total liabilities and equity	$	34,421		$	14,026	$	54,688	$	(49,127	)	$	54,008

a. All U.S. related deferred income taxes are recorded at the parent company.

CONDENSED CONSOLIDATING BALANCE SHEET

December 31, 2014

	FCX			FM O&G LLC		Non-guarantor					Consolidated
	Issuer			Guarantor		Subsidiaries		Eliminations			FCX
ASSETS
Current assets	$	323		$	2,635	$	8,659	$	(2,572	)	$	9,045
Property, plant, equipment and mining development costs, net	22			46		26,152		—			26,220
Oil and gas properties, net - full cost method:
Subject to amortization, less accumulated amortization	—			3,296		5,907		(16		)	9,187
Not subject to amortization	—			2,447		7,640		—			10,087
Investments in consolidated subsidiaries	28,765			6,460		10,246		(45,471		)	—
Other assets	8,914			3,947		4,061		(12,787		)	4,135
Total assets	$	38,024		$	18,831	$	62,665	$	(60,846	)	$	58,674
LIABILITIES AND EQUITY
Current liabilities	$	1,592		$	560	$	5,592	$	(2,572	)	$	5,172
Long-term debt, less current portion	14,930			3,874		8,879		(9,312		)	18,371
Deferred income taxes	3,161		a	—		3,237		—			6,398
Environmental and asset retirement obligations, less current portion	—			302		3,345		—			3,647
Other liabilities	54			3,372		1,910		(3,475		)	1,861
Total liabilities	19,737			8,108		22,963		(15,359		)	35,449
Redeemable noncontrolling interest	—			—		751		—			751
Equity:
Stockholders' equity	18,287			10,723		35,268		(45,991		)	18,287
Noncontrolling interests	—			—		3,683		504			4,187
Total equity	18,287			10,723		38,951		(45,487		)	22,474
Total liabilities and equity	$	38,024		$	18,831	$	62,665	$	(60,846	)	$	58,674

a. All U.S. related deferred income taxes are recorded at the parent company.

Condensed Consolidating Statements of Income [Table Text Block]

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE (LOSS) INCOME

Three Months Ended June 30, 2015
	FCX			FM O&G LLC				Non-guarantor							Consolidated
	Issuer			Guarantor				Subsidiaries				Eliminations			FCX
Revenues	$	—		$	169			$	4,079			$	—		$	4,248
Total costs and expenses	19			1,217			a	5,383			a	3			6,622
Operating (loss) income	(19		)	(1,048		)		(1,304		)		(3		)	(2,374		)
Interest expense, net	(121		)	(2		)		(67		)		41			(149		)
Other income (expense), net	127			—				(56		)		(34		)	37
(Loss) income before income taxes and equity in affiliated companies' net (losses) earnings	(13		)	(1,050		)		(1,427		)		4			(2,486		)
(Provision for) benefit from income taxes	(265		)	374				580				(2		)	687
Equity in affiliated companies' net (losses) earnings	(1,573		)	(1,920		)		(2,972		)		6,465			—
Net (loss) income	(1,851		)	(2,596		)		(3,819		)		6,467			(1,799		)
Net income and preferred dividends attributable to noncontrolling interests	—			—				(38		)		(14		)	(52		)
Net (loss) income attributable to common stockholders	$	(1,851	)	$	(2,596	)		$	(3,857	)		$	6,453		$	(1,851	)
Other comprehensive income (loss)	9			—				9				(9		)	9
Total comprehensive (loss) income	$	(1,842	)	$	(2,596	)		$	(3,848	)		$	6,444		$	(1,842	)

a. Includes charges totaling $1.0 billion at the FM O&G LLC guarantor and $1.7 billion at the non-guarantor subsidiaries related to ceiling test impairment of FCX's oil and gas properties pursuant to full cost accounting rules.

Six Months Ended June 30, 2015
	FCX			FM O&G LLC				Non-guarantor							Consolidated
	Issuer			Guarantor				Subsidiaries				Eliminations			FCX
Revenues	$	—		$	350			$	8,051			$	—		$	8,401
Total costs and expenses	35			2,535			a	11,181			a	(13		)	13,738
Operating (loss) income	(35		)	(2,185		)		(3,130		)		13			(5,337		)
Interest expense, net	(236		)	(6		)		(124		)		71			(295		)
Other income (expense), net	156			—				(48		)		(64		)	44
(Loss) income before income taxes and equity in affiliated companies' net (losses) earnings	(115		)	(2,191		)		(3,302		)		20			(5,588		)
(Provision for) benefit from income taxes	(686		)	790				1,286				(8		)	1,382
Equity in affiliated companies' net (losses) earnings	(3,524		)	(4,279		)		(6,502		)		14,306			1
Net (loss) income	(4,325		)	(5,680		)		(8,518		)		14,318			(4,205		)
Net income and preferred dividends attributable to noncontrolling interests	—			—				(94		)		(26		)	(120		)
Net (loss) income attributable to common stockholders	$	(4,325	)	$	(5,680	)		$	(8,612	)		$	14,292		$	(4,325	)
Other comprehensive income (loss)	21			—				21				(21		)	21
Total comprehensive (loss) income	$	(4,304	)	$	(5,680	)		$	(8,591	)		$	14,271		$	(4,304	)

a. Includes charges totaling $2.1 billion at the FM O&G LLC guarantor and $3.7 billion at the non-guarantor subsidiaries related to ceiling test impairment of FCX's oil and gas properties pursuant to full cost accounting rules.

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

Three Months Ended June 30, 2014
	FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Revenues	$	—		$	570		$	4,952		$	—		$	5,522
Total costs and expenses	21			489			3,865			(6		)	4,369
Operating (loss) income	(21		)	81			1,087			6			1,153
Interest expense, net	(87		)	(44		)	(51		)	18			(164		)
Net (loss) gain on early extinguishment of debt	(1		)	6			—			—			5
Other income (expense), net	17			1			(8		)	(18		)	(8		)
(Loss) income before income taxes and equity in affiliated companies' net earnings (losses)	(92		)	44			1,028			6			986
Benefit from (provision for) income taxes	26			26			(378		)	(2		)	(328		)
Equity in affiliated companies' net earnings (losses)	548			126			154			(826		)	2
Net income (loss)	482			196			804			(822		)	660
Net income and preferred dividends attributable to noncontrolling interests	—			—			(180		)	2			(178		)
Net income (loss) attributable to common stockholders	$	482		$	196		$	624		$	(820	)	$	482
Other comprehensive income (loss)	1			—			1			(1		)	1
Total comprehensive income (loss)	$	483		$	196		$	625		$	(821	)	$	483

Six Months Ended June 30, 2014
	FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Revenues	$	—		$	1,214		$	9,293		$	—		$	10,507
Total costs and expenses	32			1,015			7,204			(8		)	8,243
Operating (loss) income	(32		)	199			2,089			8			2,264
Interest expense, net	(169		)	(85		)	(109		)	38			(325		)
Net (loss) gain on early extinguishment of debt	(1		)	6			—			—			5
Other income (expense), net	37			1			25			(38		)	25
(Loss) income before income taxes and equity in affiliated companies' net earnings (losses)	(165		)	121			2,005			8			1,969
Benefit from (provision for) income taxes	5			(17		)	(670		)	(3		)	(685		)
Equity in affiliated companies' net earnings (losses)	1,152			256			339			(1,745		)	2
Net income (loss)	992			360			1,674			(1,740		)	1,286
Net income and preferred dividends attributable to noncontrolling interests	—			—			(291		)	(3		)	(294		)
Net income (loss) attributable to common stockholders	$	992		$	360		$	1,383		$	(1,743	)	$	992
Other comprehensive income (loss)	4			—			4			(4		)	4
Total comprehensive income (loss)	$	996		$	360		$	1,387		$	(1,747	)	$	996

Condensed Consolidating Statements of Cash Flows [Table Text Block]

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Six Months Ended June 30, 2015

	FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Cash flow from operating activities:
Net (loss) income	$	(4,325	)	$	(5,680	)	$	(8,518	)	$	14,318		$	(4,205	)
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	2			223			1,638			(34		)	1,829
Impairment of oil and gas properties	—			2,052			3,717			21			5,790
Net gains on crude oil derivative contracts	—			(58		)	—			—			(58		)
Equity in losses (earnings) of consolidated subsidiaries	3,524			4,279			6,502			(14,306		)	(1		)
Other, net	(1,431		)	9			43			—			(1,379		)
Changes in working capital and other tax payments	2,222			(550		)	(1,870		)	8			(190		)
Net cash (used in) provided by operating activities	(8		)	275			1,512			7			1,786
Cash flow from investing activities:
Capital expenditures	—			(734		)	(2,787		)	(7		)	(3,528		)
Intercompany loans	(1,073		)	(794		)	—			1,867			—
Dividends from (investments in) consolidated subsidiaries	438			(31		)	74			(481		)	—
Other, net	(10		)	(1		)	137			10			136
Net cash (used in) provided by investing activities	(645		)	(1,560		)	(2,576		)	1,389			(3,392		)
Cash flow from financing activities:
Proceeds from debt	2,735			—			1,687			—			4,422
Repayments of debt	(1,690		)	—			(670		)	—			(2,360		)
Intercompany loans	—			1,321			546			(1,867		)	—
Cash dividends and distributions paid, and contributions received	(380		)	—			(481		)	421			(440		)
Other, net	(12		)	(37		)	(15		)	50			(14		)
Net cash provided by (used in) financing activities	653			1,284			1,067			(1,396		)	1,608
Net (decrease) increase in cash and cash equivalents	—			(1		)	3			—			2
Cash and cash equivalents at beginning of period	—			1			463			—			464
Cash and cash equivalents at end of period	$	—		$	—		$	466		$	—		$	466

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Six Months Ended June 30, 2014

	FCX			FM O&G LLC			Non-guarantor							Consolidated
	Issuer			Guarantor			Subsidiaries				Eliminations			FCX
Cash flow from operating activities:
Net income (loss)	$	992		$	360		$	1,674			$	(1,740	)	$	1,286
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	2			545			1,440				(8		)	1,979
Net losses on crude oil and natural gas derivative contracts	—			120			—				—			120
Net gain (loss) on early extinguishment of debt	1			(6		)	—				—			(5		)
Equity in (earnings) losses of consolidated subsidiaries	(1,152		)	(256		)	39				1,367			(2		)
Other, net	121			(12		)	(123		)		—			(14		)
Changes in working capital and other tax payments	(164		)	(2,165		)	1,552				—			(777		)
Net cash (used in) provided by operating activities	(200		)	(1,414		)	4,582				(381		)	2,587
Cash flow from investing activities:
Capital expenditures	—			(897		)	(2,665		)		—			(3,562		)
Acquisition of Deepwater GOM interests	—			—			(925		)		—			(925		)
Intercompany loans	1,318			1,629			—			—	(2,947		)	—
(Investments in) dividends from consolidated subsidiaries	(364		)	(96		)	1,079				(619		)	—
Net proceeds from sale of Eagle Ford shale assets	—			3,009			—				—			3,009
Other, net	—			(381		)	18				—			(363		)
Net cash provided by (used in) investing activities	954			3,264			(2,493		)		(3,566		)	(1,841		)
Cash flow from financing activities:
Proceeds from debt	890			—			358				—			1,248
Repayments of debt	(990		)	(224		)	(397		)		—			(1,611		)
Intercompany loans	—			(170		)	(2,777		)		2,947			—
Cash dividends and distributions paid, and contributions received	(653		)	(1,453		)	203				1,000			(903		)
Other, net	(1		)	(2		)	(4		)		—			(7		)
Net cash (used in) provided by financing activities	(754		)	(1,849		)	(2,617		)		3,947			(1,273		)
Net increase (decrease) in cash and cash equivalents	—			1			(528		)		—			(527		)
Cash and cash equivalents at beginning of period	—			—			1,985				—			1,985
Cash and cash equivalents at end of period	$	—		$	1		$	1,457			$	—		$	1,458

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Contingencies and Commitments (Unaudited) (Details) $ in Millions, IDR in Trillions	3 Months Ended		6 Months Ended
	Jun. 30, 2015 USD ($)	Jun. 30, 2014 USD ($)	Jun. 30, 2015 USD ($)	Jun. 30, 2014 USD ($)	Jun. 30, 2015 IDR
Loss Contingencies [Line Items]
Escrow Deposit	$ 125		$ 125
Legal Fees	33
Insurance and other third-party recoveries	$ 92	$ 0	92	$ 0
Dividends Payable, Date to be Paid	Aug. 03, 2015
PT Freeport Indonesia [Member]
Loss Contingencies [Line Items]
Assessment By Foreign Government Of Alleged Obligations	$ 190		$ 190
Assessment By Foreign Government of Alleged Obligations, Expressed in Foreign Currency | IDR					IDR 2.5

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Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash flow from operating activities:
Net (loss) income	$ (4,205)	$ 1,286
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation, depletion and amortization	1,829	1,979
Impairment of oil and gas properties	5,790	0
Lower of cost or market inventory adjustments	63	0
Net gain on sale of assets	(39)	0
Net (gains) losses on crude oil and natural gas derivative contracts	(58)	120
Net charges for environmental and asset retirement obligations, including accretion	109	97
Payments for environmental and asset retirement obligations	(81)	(96)
Net gain on early extinguishment of debt	0	(5)
Deferred income taxes	(1,432)	37
Increase in long-term mill and leach stockpiles	(104)	(131)
Other, net	104	77
Changes in working capital and other tax payments, excluding amounts from acquisitions and disposition:
Accounts receivable	493	(243)
Inventories	8	(230)
Other current assets	(1)	35
Accounts payable and accrued liabilities	(205)	(186)
Accrued income taxes and changes in other tax payments	(485)	(153)
Net cash provided by operating activities	1,786	2,587
Capital expenditures:
North America copper mines	(214)	(627)
South America	(902)	(839)
Indonesia	(438)	(479)
Africa	(97)	(60)
Molybdenum mines	(7)	(33)
United States oil and gas operations	(1,795)	(1,484)
Other	(75)	(40)
Acquisition of Deepwater Gulf of Mexico interests	0	(925)
Net proceeds from sale of Eagle Ford shale assets	0	3,009
Other, net	136	(363)
Net cash used in investing activities	(3,392)	(1,841)
Cash flow from financing activities:
Proceeds from debt	4,422	1,248
Repayments of debt	(2,360)	(1,611)
Cash dividends and distributions paid:
Common stock	(380)	(653)
Noncontrolling interests	(60)	(250)
Stock-based awards net (payments) proceeds, including excess tax benefit	(7)	3
Debt financing costs and other, net	(7)	(10)
Net cash provided by (used in) financing activities	1,608	(1,273)
Net increase (decrease) in cash and cash equivalents	2	(527)
Cash and cash equivalents at beginning of year	464	1,985
Cash and cash equivalents at end of period	$ 466	$ 1,458

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Inventories, Including Long-Term Mill and Leach Stockpiles (Unaudited)

6 Months Ended

Jun. 30, 2015

Inventories, Including Long Term Mill and Leach Stockpiles [Abstract]

Inventories, Including Long-Term Mill and Leach Stockpiles

INVENTORIES, INCLUDING LONG-TERM MILL AND LEACH STOCKPILES

The components of inventories follow (in millions):

	June 30, 2015		December 31, 2014
Current inventories:
Mill stockpiles	$	130	$	86
Leach stockpiles	1,803		1,828
Total current mill and leach stockpiles	$	1,933	$	1,914
Total materials and supplies, neta	$	2,014	$	1,886
Raw materials (primarily concentrates)	$	306	$	288
Work-in-process	155		174
Finished goods	1,023		1,099
Total product inventories	$	1,484	$	1,561
Long-term inventories:
Mill stockpiles	$	361	$	360
Leach stockpiles	1,916		1,819
Total long-term mill and leach stockpilesb	$	2,277	$	2,179

a. Materials and supplies inventory was net of obsolescence reserves totaling $25 million at June 30, 2015, and $20 million at December 31, 2014.

b. Estimated metals in stockpiles not expected to be recovered within the next 12 months.

FCX recorded charges for lower of cost or market (LCM) inventory adjustments of $59 million ($48 million for molybdenum inventories and $11 million for copper inventories) for second-quarter 2015 and $63 million ($52 million for molybdenum inventories and $11 million for copper inventories) for the first six months of 2015, primarily because of lower molybdenum and copper prices.

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General Information (Unaudited) (Details) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2015 USD ($)	Mar. 31, 2015 $ / bbl	Jun. 30, 2014 USD ($)	Jun. 30, 2015 USD ($) $ / bbl	Jun. 30, 2014 USD ($)
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Fair Value Inputs, Discount Rate				10.00%
Impairment of oil and gas properties	$ (2,686)		$ 0	$ (5,790)	$ 0
Crude Oil [Member]
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]
Average Sales Prices | $ / bbl		82.72		71.68

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Financial Instruments (Unaudited) Other Financial Instruments (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014	Dec. 31, 2013
Cash and Cash Equivalents [Line Items]
Credit Derivative, Maximum Exposure, Undiscounted	$ 226
Cash and cash equivalents	466	$ 464	$ 1,458	$ 1,985
Time Deposits [Member]
Cash and Cash Equivalents [Line Items]
Cash and cash equivalents	$ 27	$ 48

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Earnings Per Share (Unaudited) (Tables)

6 Months Ended

Jun. 30, 2015

Earnings Per Share [Abstract]

Reconciliation of net income and weighted-average shares of common stock outstanding

A reconciliation of net (loss) income and weighted-average shares of common stock outstanding for purposes of calculating basic and diluted net (loss) income per share follows (in millions, except per share amounts):

	Three Months Ended								Six Months Ended
	June 30,								June 30,
	2015				2014				2015				2014
Net (loss) income	$	(1,799	)		$	660			$	(4,205	)		$	1,286
Net income attributable to noncontrolling interests	(42		)		(168		)		(100		)		(274		)
Preferred dividends on redeemable noncontrolling interest	(10		)		(10		)		(20		)		(20		)
Undistributed earnings allocable to participating securities	(3		)		(2		)		(3		)		(3		)
Net (loss) income allocable to common stockholders	$	(1,854	)		$	480			$	(4,328	)		$	989
Basic weighted-average shares of common stock outstanding	1,040				1,039				1,040				1,039
Add shares issuable upon exercise or vesting of dilutive stock options and RSUs	—			a	6			a	—			a	6			a
Diluted weighted-average shares of common stock outstanding	1,040				1,045				1,040				1,045
Basic net (loss) income per share attributable to common stockholders	$	(1.78	)		$	0.46			$	(4.16	)		$	0.95
Diluted net (loss) income per share attributable to common stockholders	$	(1.78	)		$	0.46			$	(4.16	)		$	0.95

a. Excludes approximately four million shares of common stock for both the quarter and six months ended June 30, 2015, and three million shares of common stock for both the quarter and six months ended June 30, 2014, associated with outstanding stock options with exercise prices less than the average market price of FCX's common stock and RSUs that were anti-dilutive.