

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 ~~September 30, 2014~~March 31, 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 ~~October 31, 2014~~April 30, 2015, there were issued and outstanding ~~1,039,118,147~~1,040,044,809 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 ~~Income~~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	3126

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	3227

Item 3. Quantitative and Qualitative Disclosures About Market Risk	9069

Item 4. Controls and Procedures	9069

Part II. Other Information	9069

Item 1. Legal Proceedings	9069

Item 1A. Risk Factors	9069

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	9270

Item 4. Mine Safety Disclosure	92

~~Item 5. Other Information~~	9370

Item 6. Exhibits	9670

Signature	9671

Exhibit Index	E-1

Table of Contents


Part I.	FINANCIAL INFORMATION


Item 1.	Financial Statements.

FREEPORT-McMoRan INC.

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited)


	September 30, 2014			December 31, 2013			March 31, 2015			December 31, 2014
	(In millions)						(In millions)
ASSETS
Current assets:
Cash and cash equivalents	$	658		$	1,985		$	549		$	464
Trade accounts receivable	1,514			1,728			995			953
Other accounts receivable	793			834			1,401			1,610
Inventories:
Materials and supplies, net							1,919			1,886
Mill and leach stockpiles	1,967			1,705			1,877			1,914
Materials and supplies, net	1,943			1,730
Product	1,579			1,583			1,442			1,561
Other current assets	577			407			671			657
Total current assets	9,031			9,972			8,854			9,045
Property, plant, equipment and mining development costs, net	26,304			24,042			26,595			26,220
Oil and gas properties - full cost method
Oil and gas properties, net - full cost method
Subject to amortization, less accumulated amortization	11,306			12,472			6,713			9,187
Not subject to amortization	11,031			10,887			9,665			10,087
Long-term mill and leach stockpiles	2,569			2,386			2,261			2,179
Goodwill	1,717			1,916
Other assets	2,018			1,798			1,977			1,956
Total assets	$	63,976		$	63,473		$	56,065		$	58,674

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$	3,784		$	3,708		$	3,111		$	3,653
Current portion of debt	1,762			312			558			478
Accrued income taxes							364			410
Current portion of environmental and asset retirement obligations							317			296
Dividends payable	334			333			60			335
Current portion of environmental and asset retirement obligations	310			236
Accrued income taxes	153			184
Total current liabilities	6,343			4,773			4,410			5,172
Long-term debt, less current portion	17,975			20,394			19,754			18,371
Deferred income taxes	7,559			7,410			5,625			6,398
Environmental and asset retirement obligations, less current portion	3,654			3,259			3,678			3,647
Other liabilities	1,730			1,690			1,812			1,861
Total liabilities	37,261			37,526			35,279			35,449

Redeemable noncontrolling interest	749			716			755			751

Equity:
FCX stockholders’ equity:
Stockholders’ equity:
Common stock	117			117			117			117
Capital in excess of par value	22,248			22,161			22,307			22,281
Retained earnings	3,306			2,742
(Accumulated deficit) retained earnings							(2,398		)	128
Accumulated other comprehensive loss	(394		)	(405		)	(532		)	(544		)
Common stock held in treasury	(3,686		)	(3,681		)	(3,701		)	(3,695		)
Total FCX stockholders’ equity	21,591			20,934
Total stockholders’ equity							15,793			18,287
Noncontrolling interests	4,375			4,297			4,238			4,187
Total equity	25,966			25,231			20,031			22,474
Total liabilities and equity	$	63,976		$	63,473		$	56,065		$	58,674

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

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FREEPORT-McMoRan INC.

CONSOLIDATED STATEMENTS OF ~~INCOME~~OPERATIONS (Unaudited)


	Three Months Ended						Nine Months Ended						Three Months Ended
	September 30,						September 30,						March 31,
	2014			2013			2014			2013			2015			2014
	(In millions, except per share amounts)												(In millions, except per share amounts)
Revenues	$	5,696		$	6,165		$	16,203		$	15,036		$	4,153		$	4,985
Cost of sales:
Production and delivery	3,152			3,332			8,971			8,904			2,912			2,737
Depreciation, depletion and amortization	945			919			2,924			1,778			939			966
Impairment of oil and gas properties	308			—			308			—			3,104			—
Total cost of sales	4,405			4,251			12,203			10,682			6,955			3,703
Selling, general and administrative expenses	158			158			457			457			154			135
Mining exploration and research expenses	29			57			93			173			33			30
Environmental obligations and shutdown costs	18			(8		)	100			23			13			6
Net gain on sales of assets	(46		)	—			(46		)	—
Net gain on sale of assets													(39		)	—
Total costs and expenses	4,564			4,458			12,807			11,335			7,116			3,874
Operating income	1,132			1,707			3,396			3,701
Operating (loss) income													(2,963		)	1,111
Interest expense, net	(158		)	(162		)	(483		)	(351		)	(146		)	(161		)
Net gain (loss) on early extinguishment of debt	58			—			63			(45		)
Gain on investment in McMoRan Exploration Co.	—			—			—			128
Other income, net	23			3			48			13			7			33
Income before income taxes and equity in affiliated companies' net (losses) earnings	1,055			1,548			3,024			3,446
Provision for income taxes	(349		)	(499		)	(1,034		)	(967		)
Equity in affiliated companies’ net (losses) earnings	(2		)	(1		)	—			3
Net income	704			1,048			1,990			2,482
(Loss) income before income taxes and equity in affiliated companies' net earnings													(3,102		)	983
Benefit from (provision for) income taxes													695			(357		)
Equity in affiliated companies’ net earnings													1			—
Net (loss) income													(2,406		)	626
Net income attributable to noncontrolling interests	(142		)	(218		)	(416		)	(519		)	(58		)	(106		)
Preferred dividends attributable to redeemable noncontrolling interest	(10		)	(9		)	(30		)	(12		)	(10		)	(10		)
Net income attributable to FCX common stockholders	$	552		$	821		$	1,544		$	1,951
Net (loss) income attributable to common stockholders													$	(2,474	)	$	510

Net income per share attributable to FCX common stockholders:
Net (loss) income per share attributable to common stockholders:
Basic	$	0.53		$	0.79		$	1.48		$	1.97		$	(2.38	)	$	0.49
Diluted	$	0.53		$	0.79		$	1.47		$	1.96		$	(2.38	)	$	0.49

Weighted-average common shares outstanding:
Basic	1,039			1,038			1,039			989			1,040			1,038
Diluted	1,046			1,043			1,045			993			1,040			1,044

Dividends declared per share of common stock	$	0.3125		$	0.3125		$	0.9375		$	1.9375		$	0.05		$	0.3125

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

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FREEPORT-McMoRan INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME (Unaudited)


	Three Months Ended						Nine Months Ended						Three Months Ended
	September 30,						September 30,						March 31,
	2014			2013			2014			2013			2015			2014
	(In millions)												(In millions)
Net income	$	704		$	1,048		$	1,990		$	2,482
Net (loss) income													$	(2,406	)	$	626

Other comprehensive income, net of taxes:
Defined benefit plans:
Amortization of unrecognized amounts included in net periodic benefit costs	5			6			12			18			8			3
Foreign exchange losses	2			—			(1		)	—
Translation adjustments and unrealized gains (losses) on securities	—			4			—			3
Foreign exchange gains													4			—
Other comprehensive income	7			10			11			21			12			3

Total comprehensive income	711			1,058			2,001			2,503
Total comprehensive (loss) income													(2,394		)	629
Total comprehensive income attributable to noncontrolling interests	(142		)	(217		)	(416		)	(518		)	(58		)	(106		)
Preferred dividends attributable to redeemable noncontrolling interest	(10		)	(9		)	(30		)	(12		)	(10		)	(10		)
Total comprehensive income attributable to FCX common stockholders	$	559		$	832		$	1,555		$	1,973
Total comprehensive (loss) income attributable to common stockholders													$	(2,462	)	$	513

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

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FREEPORT-McMoRan INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)


	Nine Months Ended						Three Months Ended
	September 30,						March 31,
	2014			2013			2015			2014
	(In millions)						(In millions)
Cash flow from operating activities:
Net income	$	1,990		$	2,482
Adjustments to reconcile net income to net cash provided by operating activities:
Net (loss) income							$	(2,406	)	$	626
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation, depletion and amortization	2,924			1,778			939			966
Impairment of oil and gas properties	308			—			3,104			—
Net losses on crude oil and natural gas derivative contracts	56			205
Gain on investment in McMoRan Exploration Co. (MMR)	—			(128		)
Net gain on sale of assets							(39		)	—
Net (gains) losses on crude oil and natural gas derivative contracts							(52		)	50
Net charges for environmental and asset retirement obligations, including accretion	146			98			53			46
Payments for environmental and asset retirement obligations	(134		)	(166		)	(42		)	(45		)
Net (gain) loss on early extinguishment of debt	(63		)	45
Net gain on sales of assets	(46		)	—
Deferred income taxes	107			169			(709		)	90
Increase in long-term mill and leach stockpiles	(182		)	(348		)	(82		)	(86		)
Other, net	106			97			37			(33		)
Decreases (increases) in working capital and changes in other tax payments, excluding amounts from acquisitions and dispositions:
Decreases (increases) in working capital and changes in other tax payments, excluding amounts from disposition:
Accounts receivable	200			51			316			179
Inventories	(267		)	(66		)	165			(180		)
Other current assets	(26		)	162			(42		)	(34		)
Accounts payable and accrued liabilities	(379		)	(596		)	(402		)	(362		)
Accrued income taxes and other tax payments	(227		)	(40		)	(123		)	(16		)
Net cash provided by operating activities	4,513			3,743			717			1,201

Cash flow from investing activities:
Capital expenditures:
North America copper mines	(815		)	(795		)	(107		)	(303		)
South America	(1,278		)	(734		)	(445		)	(423		)
Indonesia	(722		)	(720		)	(225		)	(236		)
Africa	(100		)	(155		)	(39		)	(31		)
Molybdenum mines	(45		)	(128		)	(3		)	(19		)
U.S. oil and gas operations	(2,392		)	(928		)
United States oil and gas operations							(1,018		)	(579		)
Other	(63		)	(163		)	(30		)	(21		)
Acquisition of Deepwater Gulf of Mexico interests	(1,421		)	—
Acquisition of Plains Exploration & Production Company, net of cash acquired	—			(3,465		)
Acquisition of MMR, net of cash acquired	—			(1,628		)
Acquisition of cobalt chemical business, net of cash acquired	—			(348		)
Net proceeds from sale of Eagle Ford shale assets	2,971			—
Other, net	221			(24		)	127			7
Net cash used in investing activities	(3,644		)	(9,088		)	(1,740		)	(1,605		)

Cash flow from financing activities:
Proceeds from debt	3,346			11,229			2,273			1,149
Repayments of debt	(4,196		)	(4,816		)	(802		)	(987		)
Redemption of MMR preferred stock	—			(227		)
Cash dividends and distributions paid:
Common stock	(979		)	(1,957		)	(327		)	(326		)
Noncontrolling interests	(365		)	(157		)	(23		)	(77		)
Contributions from noncontrolling interests	24			—
Stock-based awards net proceeds (payments), including excess tax benefit	7			(100		)
Stock-based awards net (payments) proceeds, including excess tax benefit							(6		)	3
Debt financing costs and other, net	(33		)	(113		)	(7		)	(1		)
Net cash (used in) provided by financing activities	(2,196		)	3,859
Net cash provided by (used in) financing activities							1,108			(239		)

Net decrease in cash and cash equivalents	(1,327		)	(1,486		)
Net increase (decrease) in cash and cash equivalents							85			(643		)
Cash and cash equivalents at beginning of year	1,985			3,705			464			1,985
Cash and cash equivalents at end of period	$	658		$	2,219		$	549		$	1,342

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

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FREEPORT-McMoRan INC.

CONSOLIDATED STATEMENT OF EQUITY (Unaudited)


	FCX Stockholders’ Equity																																	Stockholders’ Equity
	Common Stock								Retained Earnings				Accumu- lated Other Compre- hensive Loss				Common Stock Held in Treasury						Total FCX Stock-holders' 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			Number of Shares			At Par Value				Capital in Excess of Par Value						Number of Shares									At Cost				Non- controlling Interests							Total Equity
	Number of Shares			Retained Earnings				Accumu- lated Other Compre- hensive Loss				Number of Shares				Total FCX Stock-holders' Equity										Retained Earnings(Accum-ulated Deficit)				Number of Shares		Accumu- lated Other Compre- hensive Loss	At Par Value			Total Stock-holders' Equity							Number of Shares									At Cost				Non- controlling Interests							Total Equity
	(In millions)																												(In millions)
Balance at December 31, 2013	1,165	At Par Value				$	117						$	22,161				$	2,742		Non- controlling Interests			$	(405			)	127		$		(3,681	)	$			20,934		$	4,297		$	25,231
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	2	—					13				—				—				—			—						13					—				13			1			—				1				—			—				—			—				1				—		1
Stock-based compensation	—	—			75					—				—				—			—				75				—				75			—			—				28				—				—			—			—				28				7				35
Reserve of tax benefit for stock-based awards																																		—			—				(2		)		—				—				—		—				(2		)		—				(2		)
Tender of shares for stock-based awards	—	—			—				—				—				—		(5		)		(5		)		—				(5		)	—			—				—				—				—				—		(6		)		(6		)		—				(6		)
Dividends on common stock	—	—			—				(980		)		—				—		—				(980		)		—				(980		)	—			—				—				(52		)		—				—		—				(52		)		—				(52		)
Dividends to noncontrolling interests	—	—			—				—				—				—		—				—				(344		)		(344		)	—			—				—				—				—				—		—				—				(15		)		(15		)
Noncontrolling interests' share of contributed capital in subsidiary	—	—			(1		)		—				—				—		—				(1		)		6				5			—			—				(1		)		—				—				—		—				(1		)		1				—
Net income attributable to FCX common stockholders	—	—			—				1,544				—				—		—				1,544				—				1,544
Net loss attributable to common stockholders																																		—			—				—				(2,474		)		—				—		—				(2,474		)		—				(2,474		)
Net income attributable to noncontrolling interests	—	—			—				—				—				—		—				—				416				416			—			—				—				—				—				—		—				—				58				58
Other comprehensive income	—	—			—				—				11				—		—				11				—				11			—			—				—				—				12				—		—				12				—				12
Balance at September 30, 2014	1,167	$	117		$	22,248			$	3,306			$	(394	)		127		$	(3,686	)		$	21,591			$	4,375			$	25,966
Balance at March 31, 2015																																		1,168			$	117			$	22,307			$	(2,398	)		$	(532	)		128		$	(3,701	)		$	15,793			$	4,238			$	20,031

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

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FREEPORT-McMoRan INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)

NOTE 1. GENERAL INFORMATION

~~Effective July 14, 2014, Freeport-McMoRan Copper & Gold Inc. changed its name to Freeport-McMoRan Inc. (FCX) to simplify the corporate name and better reflect FCX's expanded portfolio of assets.~~ 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 ~~FCX's~~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, ~~2013.~~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 ~~certain adjustments associated with~~ the ~~acquisitions of Plains Exploration & Production Company (PXP) and McMoRan Exploration Co. (MMR), collectively known as FCX Oil & Gas Inc. (FM O&G),~~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 three-month ~~and nine-month periods~~period ended ~~September 30, 2014~~March 31, 2015, are not necessarily indicative of the results that may be expected for the year ending December 31, ~~2014~~2015.

~~As further discussed in Note 2, FCX completed its acquisitions of PXP on~~ ~~May 31, 2013, and MMR on~~ ~~June 3, 2013. The results included in these financial statements for the nine months ended September 30, 2013, include PXP~~'~~s results beginning June 1, 2013, and MMR's results beginning June 4, 2013.~~

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 and amortization, 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 ~~and natural gas~~ 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 ~~September 30, 2014~~March 31, 2015, the net capitalized costs with respect to FCX's proved U.S. oil and gas properties exceeded the related ceiling; therefore, an impairment charge of ~~$308 million~~$3.1 billion was recorded in ~~third-quarter 2014,~~first-quarter 2015, primarily because of ~~higher capitalized costs and~~ the lower twelve-month average of the first-day-of-the-month historical reference oil price and higher capitalized costs at ~~September 30, 2014~~March 31, 2015. 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 $82.72 per barrel at March 31, 2015 (the twelve-month average was $94.99 per barrel at December 31, 2014). ~~During October 2014,~~Because the ceiling limitation uses a twelve-month historical average price, if WTI oil prices ~~declined from~~remain below the ~~third-quarter average. Continuation~~twelve-month average of ~~recent~~$82.72 per barrel, the ceiling limitation will decrease, resulting in potentially significant additional ceiling test impairments of FCX's oil ~~price declines,~~and gas properties during the remainder of 2015. In addition, increases in capitalized costs subject to amortization, ~~and~~negative reserve revisions or other factors ~~may~~could result in ~~future~~ additional ~~ceiling test~~ impairments.

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 $62 million of deferred tax expense recorded through September 30, 2014, 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 oil and gas interests, as discussed below. The remaining proceeds were used to repay debt.

~~Table of Contents~~

~~Deepwater Gulf of Mexico (GOM) Acquisitions.~~ 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~~ ~~$919 million~~. Based on preliminary valuations, and including transaction costs and estimated asset retirement costs, FCX recorded capitalized costs for oil and gas properties subject to amortization of $460 million and costs not subject to amortization of $476 million. The Deepwater GOM acquisition was funded by the like-kind exchange escrow.

~~Additionally, on~~ ~~September 8, 2014~~, FCX completed the acquisition of additional Deepwater GOM interests for $496 million, including an interest in the Vito oil discovery in the Mississippi Canyon area and a significant lease position in the Vito basin area. Based on preliminary valuations, and including purchase price adjustments and transaction costs, FCX recorded capitalized costs for oil and gas properties not subject to amortization of ~~$509 million. This acquisition was funded in part with the remaining~~ ~~$414 million~~ ~~of funds from the like-kind exchange escrow.~~

~~PXP and MMR Acquisitions.The second-quarter 2013 acquisitions of PXP and MMR added a portfolio of oil and gas assets to FCX~~'~~s global mining business, creating a U.S.-based natural resources company. The acquisitions have been accounted for under the acquisition method, with FCX as the acquirer.~~

During second-quarter 2014, FCX finalized the purchase price allocations, which resulted in a net increase of $20 million to oil and gas properties, an increase of $22 million to goodwill and a net decrease of $42 million to deferred income tax assets.

~~For further discussion of the PXP and MMR acquisitions and the related financing, refer to Notes 2 and 8 in FCX's annual report on Form 10-K for the year ended December 31, 2013.~~

~~Unaudited Pro Forma Consolidated Financial Information.~~ The following unaudited pro forma financial information has been prepared to reflect the acquisitions of PXP and MMR. The unaudited pro forma financial information combines the historical statements of income of FCX, PXP and MMR for the nine months ended September 30, 2013, giving effect to the mergers as if they had occurred on January 1, 2012. The historical consolidated financial information has been adjusted to reflect factually supportable items that are directly attributable to the acquisitions.

Nine Months
Ended
September 30, 2013
(in millions, except per share amounts)

Revenues $ 17,190
Operating income 4,617
Net income from continuing operations 2,683
Net income attributable to FCX common stockholders 2,134

Net income per share attributable to FCX common stockholders:
Basic $ 2.05
Diluted 2.04

The unaudited pro forma consolidated information for the nine months ended September 30, 2013, has been prepared for illustrative purposes only and is not intended to be indicative of the results of operations that actually would have occurred, or the results of operations expected in future periods, had the events reflected herein occurred on the date indicated. The most significant pro forma adjustments to net income from continuing operations for the nine months ended September 30, 2013, were to exclude $519 million of acquisition-related costs, the net tax benefit of $183 million of acquisition-related adjustments and the $128 million gain on the investment in MMR. Additionally, for the nine months ended September 30, 2013, the pro forma consolidated information excluded a $77 million gain on the sale of MMR oil and gas properties because of the application of the full cost method of accounting.

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~~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 ~~FCX~~ 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.

~~The following table sets forth the computation~~

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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 for the three months ended March 31 follows (in millions, except per share amounts):


	Three Months Ended							Nine Months Ended							Three Months Ended
	September 30,							September 30,							March 31,
	2014				2013			2014				2013			2015				2014
Net income	$	704			$	1,048		$	1,990			$	2,482
Net (loss) income															$	(2,406	)		$	626
Net income attributable to noncontrolling interests	(142		)		(218		)	(416		)		(519		)	(58		)		(106		)
Preferred dividends on redeemable noncontrolling interest	(10		)		(9		)	(30		)		(12		)	(10		)		(10		)
Undistributed earnings allocable to participating securities	(2		)		—			(4		)		—			(3		)		(1		)
Net income allocable to FCX common stockholders	$	550			$	821		$	1,540			$	1,951
Net (loss) income allocable to common stockholders															$	(2,477	)		$	509

Basic weighted-average shares of common stock outstanding	1,039				1,038			1,039				989			1,040				1,038
Add shares issuable upon exercise or vesting of dilutive stock options and RSUs	7			^a	5			6			^a	4			—			^a	6			^a
Diluted weighted-average shares of common stock outstanding	1,046				1,043			1,045				993			1,040				1,044

Basic net income per share attributable to FCX common stockholders	$	0.53			$	0.79		$	1.48			$	1.97
Diluted net income per share attributable to FCX common stockholders	$	0.53			$	0.79		$	1.47			$	1.96
Basic net (loss) income per share attributable to common stockholders															$	(2.38	)		$	0.49
Diluted net (loss) income per share attributable to common stockholders															$	(2.38	)		$	0.49

~~Excluded~~Excludes shares of common stock totaling approximately three million for first-quarter 2015 and two million for first-quarter 2014 associated with outstanding stock options with exercise prices less than the average market price of FCX's common stock and RSU's that were ~~anti-dilutive totaled approximately 5 million for~~ ~~third-quarter~~ ~~2014 and 3 million for the nine months ended September 30, 2014.~~

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 2540 million ~~with a weighted-average exercise price of~~ ~~$42.34~~ ~~per option~~ for ~~third-quarter~~first-quarter ~~2014, 28 million with a weighted-average exercise price of $41.42 per option for the nine months ended~~ ~~September 30, 2014~~, ~~34 million~~ ~~with a weighted-average exercise price of~~ ~~$40.11~~ ~~per option for~~ ~~third-quarter2013~~2015 and 3230 million ~~with a weighted-average exercise price of $40.63 per option~~ for ~~the nine months ended~~ ~~September 30, 2013~~first-quarter2014.

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NOTE 4.3. INVENTORIES, INCLUDING LONG-TERM MILL AND LEACH STOCKPILES

The components of inventories follow (in millions):


	September 30, 2014		December 31, 2013		March 31, 2015		December 31, 2014
Current inventories:
Raw materials (primarily concentrates)	$	335	$	238
Work-in-process^a	129		199
Finished goods^b	1,115		1,146
Total product inventories	$	1,579	$	1,583

Mill stockpiles	$	126	$	91	$	101	$	86
Leach stockpiles	1,841		1,614		1,776		1,828
Total current mill and leach stockpiles	$	1,967	$	1,705	$	1,877	$	1,914

Total materials and supplies, net^c	$	1,943	$	1,730
Total materials and supplies, net^a					$	1,919	$	1,886

Raw materials (primarily concentrates)					$	272	$	288
Work-in-process					158		174
Finished goods					1,012		1,099
Total product inventories					$	1,442	$	1,561

Long-term inventories:
Mill stockpiles	$	787	$	698	$	346	$	360
Leach stockpiles	1,782		1,688		1,915		1,819
Total long-term mill and leach stockpiles^d	$	2,569	$	2,386
Total long-term mill and leach stockpiles^b					$	2,261	$	2,179


a.	~~FCX's mining operations also have work-in-process inventories that are reflected as mill and leach stockpiles.~~


b.	~~Primarily included molybdenum concentrates; copper concentrates, anodes, cathodes and rod; and various cobalt products.~~


c.	Materials and supplies inventory was net of obsolescence reserves totaling ~~$22~~$21 million at ~~September 30, 2014~~March 31, 2015, and ~~$24~~$20 million at December 31, ~~2013~~2014.


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

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NOTE 5.4. INCOME TAXES

Variations in the relative proportions of jurisdictional income result in fluctuations to ~~FCX’s~~FCX's consolidated effective income tax rate. Geographic sources of FCX's (benefit from) provision for income taxes follow (in millions):


	Three Months Ended						Nine Months Ended						Three Months Ended
	September 30,						September 30,						March 31,
	2014			2013			2014			2013			2015			2014
U.S. operations	$	38		$	104	^a	$	323	^b	$	85	^a	$	(835	)	$	136
International operations	311		^c	395			711		^c	882			140			221
Total	$	349		$	499		$	1,034		$	967		$	(695	)	$	357

As a result of second-quarter 2013 oil and gas acquisitions, FCX recognized a net tax benefit of $183 million, consisting of income tax benefits of $190 million associated with net reductions in FCX's valuation allowances and $69 million related to the release of the deferred tax liability on PXP's investment in MMR common stock; partially offset by income tax expense of $76 million associated with the write off of deferred tax assets related to environmental liabilities.


b.	~~Included a $62 million charge for deferred taxes recorded in connection with the allocation of goodwill to the sale of the Eagle Ford shale assets.~~


c.	~~Included a $54 million charge related to changes in Chilean tax rules.~~

FCX’s consolidated effective income tax rate was 3422 percent for ~~the first nine months of~~first-quarter ~~2014~~2015 and 3336 percent for ~~the first nine months of~~first-quarter ~~2013~~2014~~, excluding~~. During first-quarter 2015, as a result of the ~~net benefit~~impairment to oil and gas properties, FCX recorded a tax charge of ~~$183~~$458 million ~~for acquisition-related adjustments.~~to establish a valuation allowance primarily against U.S. federal alternative minimum tax credits. The valuation allowance was recorded because it is no longer more likely than not that the related benefits of all deferred tax assets will be realized.

NOTE 6.5. DEBT AND EQUITY TRANSACTIONS

~~In September 2014,~~At March 31, 2015, FCX ~~announced the planned redemption of the $400 millionoutstanding aggregate principal amount of its 8.625% Senior Notes due 2019. OnOctober 15, 2014, the redemption date, these senior notes~~ had ~~a book value of $441 million,~~$20.3 billion in debt, which included ~~purchase accounting~~additions for unamortized fair value adjustments of ~~$41 million. Holders~~$233 million (primarily from the oil and gas acquisitions in 2013), and net of ~~these senior notes received~~reductions attributable to unamortized net discounts of $21 million and unamortized debt issuance costs of $122 million. Refer to Note 11 for discussion of a change in the ~~principal amount together with the redemption premium and accrued and unpaid interest to the redemption date. As a result of this redemption, FCX will report a gain on early extinguishment~~presentation of debt ~~of $24 million in fourth-quarter 2014.~~

~~Table of Contents~~

~~In July 2014, FCX redeemed~~ ~~$1.7 billionof the aggregate principal amount of outstanding senior notes, which included~~ ~~$263 million~~ ~~for the 6.125% Senior Notes due 2019,~~ ~~$525 million~~ ~~for the 6½% Senior Notes due 2020,~~ ~~$350 million~~ ~~for the 6.75% Senior Notes due 2022 and~~ ~~$525 million~~ for the 6.875% Senior Notes due 2023. At the redemption date, these senior notes had a book value of $1.8 billion, which included purchase accounting fair value adjustments of $167 million. In accordance with the terms of these senior notes, the redemptions were 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 these redemptions, FCX recorded a gain on early extinguishment of debt of ~~$58 million~~ ~~in third-quarter 2014.~~issuance costs.

In ~~May 2014, FCX, PT Freeport Indonesia (PT-FI) and Freeport-McMoRan Oil & Gas LLC (FM O&G LLC, a wholly owned subsidiary of FM O&G and the successor entity of PXP) amended the senior unsecured~~ ~~$3.0 billion~~February 2015, FCX's revolving credit facility and $4.0 billion unsecured bank term loan (Term Loan) were modified to ~~extend~~amend the ~~maturity date one year to~~ 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.

~~May~~At March 31, ~~2019, and increase the aggregate principal amount from~~2015, $~~3.0 billion~~ to ~~$4.0 billion, with~~ ~~$500~~985 million ~~available to PT-FI. FCX, PT-FI~~was outstanding and ~~FM O&G LLC had entered into the~~ $~~3.0 billion~~42 million ~~revolving credit facility on~~ ~~May 31, 2013~~ ~~(upon completion of the acquisition of PXP). At September 30, 2014, FCX had borrowings of $1.1 billion and $45 million~~ of letters of credit were issued under ~~the~~FCX's revolving credit facility, resulting in availability of approximately ~~$2.9~~$3.0 billion, of which ~~$1.5~~$1.5 billion could be used for additional letters of credit.

In April 2014, FCX redeemed $210 million of the aggregate principal amount of the 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.

In March 2014, Sociedad Minera Cerro Verde S.A.A. (Cerro Verde, FCX's mining subsidiary in Peru) entered into a five-year, $1.8 billion senior unsecured credit facility that is nonrecourse to FCX and the other shareholders of Cerro Verde. ~~The~~During first-quarter 2015, Cerro Verde borrowed an additional $422 million under its credit facility allows for term loan borrowings up to the full amount of the facility, less any amounts issued and outstanding under a $500 million letter of credit sublimit. Interest on amounts drawn under the term loan is based on London Interbank Offered Rate (~~LIBOR~~) plus a spread (currently 1.90 percent) based on Cerro Verde’s total net debt to earnings before interest, taxes, depreciation and amortization (EBITDA) ratio as defined in the agreement. Amounts may be drawn or letters of credit may be issued over a two-year period to fund a portion of Cerro Verde’s expansion project and for Cerro Verde's general corporate purposes. The credit facility amortizes in three installments in amounts necessary for the aggregate borrowings and outstanding letters of credit not to exceed 85 percent of the $1.8 billion commitment on September 30, 2017, 70 percent onfacility. At March 31, ~~2018, and 35 percent on September 30, 2018, with~~2015, the ~~remaining balance due on the maturity date of March 10, 2019. At September 30, 2014, there were~~ no ~~borrowings~~outstanding principal amount was $847 million and no letters of credit were issued under Cerro Verde’s credit facility.

FCX recorded a loss on early extinguishment of debt of $45 million in first-quarter 2013 for financing costs incurred for the terminated $9.5 billion acquisition bridge loan facility, which was entered into in December 2012 to provide interim financing for FCX's second-quarter 2013 acquisitions of PXP and MMR.

Consolidated interest expense (excluding capitalized interest) totaled ~~$212~~$210 million in ~~third-quarter 2014, $223~~first-quarter 2015 and $224 million in ~~third-quarter 2013, $661 million for the first nine months of 2014 and $465 million for the first nine months of 2013.~~first-quarter 2014. Capitalized interest ~~included in~~added to property, plant, equipment and mining development costs, net, totaled $3445 million in ~~third-quarter 2014,~~first-quarter 2015 and $2640 million in ~~third-quarter 2013,~~ ~~$113 million~~ ~~for the first~~ ~~nine~~ ~~months of 2014 and~~ ~~$68 million~~ ~~for the~~ ~~nine~~ ~~months of 2013.~~first-quarter 2014. Capitalized interest ~~included in~~added to oil and gas properties not subject to amortization totaled $2019 million in ~~third-quarter 2014,~~first-quarter 2015 and $3523 million in ~~third-quarter 2013,~~ ~~$65 million~~ ~~for the first~~ ~~nine~~ ~~months of 2014 and~~ ~~$46 million~~ ~~for the four months from June 1, 2013, to September 30, 2013.~~first-quarter 2014.

On ~~September~~March 24, ~~2014,~~2015, FCX's Board of Directors (the Board) declared a quarterly dividend of ~~$0.3125~~$0.05 per share, which was paid on ~~November 3, 2014,~~May 1, 2015, to common shareholders of record at the close of business on ~~October~~April 15, ~~2014.~~

~~In connection with~~2015. This quarterly dividend was reduced from the ~~second-quarter 2013 acquisition~~previous quarterly rate of ~~PXP, FCX issued 91 million shares~~$0.3125 per share in response to the impact of ~~its common stock.~~lower commodity prices.

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NOTE 7.6. 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 ~~PXP,~~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 ~~September 30, 2014,~~March 31, 2015, and December 31, ~~2013,~~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, ~~(NYMEX),~~ 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 nine-month~~three-month periods ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014, resulting from hedge ineffectiveness. At ~~September 30, 2014~~March 31, 2015, FCX held copper futures and swap contracts that qualified for hedge accounting for 5455 million pounds at an average contract price of $~~3.09~~2.75 per pound, with maturities through December ~~2015~~2016.

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						Nine Months Ended						Three Months Ended
	September 30,						September 30,						March 31,
	2014			2013			2014			2013			2015			2014
Copper futures and swap contracts:
Unrealized gains (losses):
Derivative financial instruments	$	(10	)	$	16		$	(10	)	$	(2	)	$	6		$	(12	)
Hedged item – firm sales commitments	10			(16		)	10			2			(6		)	12

Realized gains (losses):
Realized (losses) gains:
Matured derivative financial instruments	1			(3		)	(3		)	(17		)	(10		)	2

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, ~~2013,~~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.

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A summary of FCX’s embedded commodity derivatives at ~~September 30, 2014~~March 31, 2015, follows:


	Open Positions	Average Price Per Unit				Maturities Through	Open Positions	Average Price Per Unit				Maturities Through
	Open Positions	Contract		Market		Maturities Through	Open Positions	Contract		Market		Maturities Through
Embedded derivatives in provisional sales contracts:
Copper (millions of pounds)	554	$	3.14	$	3.03	February 2015	577	$	2.75	$	2.74	September 2015
Gold (thousands of ounces)	301	1,259		1,214		January 2015	155	1,195		1,183		July 2015
Embedded derivatives in provisional purchase contracts:
Copper (millions of pounds)	98	3.16		3.03		January 2015	126	2.68		2.75		July 2015

Crude Oil ~~and Natural Gas~~ Contracts. As a result of the acquisition of ~~PXP,~~the oil and gas business, FCX has derivative contracts ~~for 2014 and~~extending through 2015 that consist of crude oil ~~options and natural gas swaps.~~options. These crude oil ~~and natural gas~~ 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 ~~PXP~~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 ~~September 30, 2014,~~March 31, 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 ~~September 30, 2014,~~March 31, 2015, the deferred option premiums and accrued interest associated with the crude oil option contracts totaled $~~269~~159 million, which was included as a ~~reduction~~component of the fair value of the crude oil options contracts. At ~~September 30, 2014~~March 31, 2015, the outstanding 2015 crude oil option contracts, which settle monthly and cover approximately 1023 million barrels inover the ~~fourth quarter~~remainder of ~~2014 and approximately 31 million barrels in~~ 2015, follow:

Average Strike Price (per barrel)^a

Period Instrument Type Daily Volumes (thousand barrels) Floor Floor Limit
Average Deferred Premium
(per barrel)
Index

2014
Oct - Dec
Put options^b
75
$ 90
$ 70
$ 5.74
Brent
Oct - Dec
Put options^b
30
95
75
6.09
Brent
Oct - Dec
Put options^b
5
100
80
7.11
Brent

2015
Jan - Dec
Put options^b
84
90
70
6.89
Brent

Daily Volumes (thousand barrels)

Average Strike Price (per barrel)^a

Weighted-Average Deferred Premium

(per barrel)

2015 Period

Instrument Type

Floor

Floor Limit

Index

April - December

Put options^b

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.

In addition, at September 30, 2014, outstanding natural gas swaps with a weighted-average fixed swap price of $4.09 per million British thermal units (MMBtu) cover approximately 9 million MMBtu of natural gas, with maturities through December 2014 (on daily volumes of 100,000 MMBtu). If the Henry Hub index price is less than the fixed price, FCX receives the difference between the fixed price and the Henry Hub index price. FCX pays the difference between the index price and the fixed price if the Henry Hub index price is greater than the fixed price.

Copper Forward Contracts. Atlantic Copper, FCX's wholly owned smelting and refining unit in Spain, enters into copper forward ~~copper~~ 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 ~~September 30, 2014~~March 31, 2015, Atlantic Copper held net copper forward ~~copper~~ purchase contracts for 4636 million pounds at an average contract price of $~~3.12~~2.68 per pound, with maturities through ~~November 2014~~May 2015.

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Summary of ~~Gains~~ (Losses). Gains. A summary of the realized and unrealized (losses) gains ~~(losses)~~ 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						Nine Months Ended						Three Months Ended
	September 30,						September 30,						March 31,
	2014			2013			2014			2013			2015			2014
Embedded derivatives in provisional copper and gold
sales contracts^a	$	(99	)	$	141		$	(184	)	$	(147	)	$	(72	)	$	(169	)
Crude oil options and swaps^a	57			(173		)	(47		)	(227		)
Crude oil options^a													52			(36		)
Natural gas swaps^a	7			3			(9		)	22			—			(14		)
Copper forward contracts^b	(4		)	—			1			3			(1		)	1


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):


	September 30, 2014		December 31, 2013		March 31, 2015		December 31, 2014
Commodity Derivative Assets:
Derivatives designated as hedging instruments:
Copper futures and swap contracts^a	$	1	$	6	$	4	$	—
Derivatives not designated as hedging instruments:
Embedded derivatives in provisional copper and gold
sales/purchase contracts	12		63		46		15
Crude oil options^b					268		316
Copper forward contracts					3		—
Total derivative assets	$	13	$	69	$	321	$	331

Commodity Derivative Liabilities:
Derivatives designated as hedging instruments:
Copper futures and swap contracts^a	$	5	$	—	$	5	$	7
Derivatives not designated as hedging instruments:
Embedded derivatives in provisional copper and gold
sales/purchase contracts	75		16		60		93
Crude oil options^b	182		309
Natural gas swaps	—		4
Copper forward contracts	4		1
Total derivative liabilities	$	266	$	330	$	65	$	100


a.	FCX paid $65 million to brokers at ~~September 30, 2014~~March 31, 2015, and $1$10 million at December 31, ~~2013~~2014, for margin requirements (recorded in other current assets).


b.	~~Included~~Amounts are net of $~~269~~159 million at ~~September 30, 2014~~March 31, 2015, and ~~$444~~$210 million at December 31, ~~2013~~2014, for deferred premiums and accrued interest.

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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				Assets				Liabilities
	September 30, 2014		December 31, 2013		September 30, 2014		December 31, 2013		March 31, 2015		December 31, 2014		March 31, 2015		December 31, 2014

Gross amounts recognized:
Commodity contracts:
Embedded derivatives on provisional
Embedded derivatives in provisional
sales/purchase contracts	$	12	$	63	$	75	$	16	$	46	$	15	$	60	$	93
Crude oil and natural gas derivatives	—		—		182		313
Crude oil derivatives									268		316		—		—
Copper derivatives	1		6		9		1		7		—		5		7
	13		69		266		330		321		331		65		100

Less gross amounts of offset:
Commodity contracts:
Embedded derivatives on provisional
Embedded derivatives in provisional
sales/purchase contracts	—		10		—		10		9		1		9		1
Crude oil and natural gas derivatives	—		—		—		—
Copper derivatives	1		—		1		—		5		—		5		—
	1		10		1		10		14		1		14		1

Net amounts presented in balance sheet:
Commodity contracts:
Embedded derivatives on provisional
Embedded derivatives in provisional
sales/purchase contracts	12		53		75		6		37		14		51		92
Crude oil and natural gas derivatives	—		—		182		313
Crude oil derivatives									268		316		—		—
Copper derivatives	—		6		8		1		2		—		—		7
	$	12	$	59	$	265	$	320	$	307	$	330	$	51	$	99

Balance sheet classification:
Trade accounts receivable	$	1	$	53	$	60	$	—	$	32	$	5	$	22	$	56
Other current assets	—		6		—		—		270		316		—		—
Accounts payable and accrued liabilities	11		—		169		205		5		9		29		43
Other liabilities	—		—		36		115
	$	12	$	59	$	265	$	320	$	307	$	330	$	51	$	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 ~~September 30, 2014~~March 31, 2015, the maximum amount of credit exposure associated with derivative transactions was $12333 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 ~~$72~~$17 million at ~~September 30, 2014~~March 31, 2015, and ~~$211~~$48 million at December 31, ~~2013)~~2014), accounts receivable, 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 87 for the fair values of investment securities, legally restricted funds and long-term debt).

~~In addition,~~FCX has non-detachable warrants, which are considered to be embedded derivative instruments, associated with FM O&G's Plains Offshore Operations Inc. (Plains Offshore) 8% Convertible Preferred Stock (Preferred Stock) (refer to Note 8 ~~for the fair value of these instruments).~~

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NOTE 8.7. 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 ~~third~~first-quarter ~~2014~~2015 ~~or for the first nine months of 2014.~~

. 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)6), follows (in millions):


	At September 30, 2014										At March 31, 2015
	Carrying		Fair Value								Carrying		Fair Value
	Amount		Total		Level 1		Level 2		Level 3		Amount		Total		Level 1		Level 2		Level 3
Assets
Investment securities:^a,b,c
U.S. core fixed income fund	$	22	$	22	$	—	$	22	$	—	$	23	$	23	$	—	$	23	$	—
Money market funds	20		20		20		—		—		22		22		22		—		—
Equity securities	4		4		4		—		—		3		3		3		—		—
Total	46		46		24		22		—		48		48		25		23		—

Legally restricted funds:^a,b,d
U.S. core fixed income fund	50		50		—		50		—		52		52		—		52		—
Government bonds and notes	35		35		—		35		—		39		39		—		39		—
Government mortgage-backed securities	33		33		—		33		—		29		29		—		29		—
Corporate bonds	26		26		—		26		—		28		28		—		28		—
Asset-backed securities	16		16		—		16		—		16		16		—		16		—
Money market funds	8		8		8		—		—		10		10		10		—		—
Municipal bonds	1		1		—		1		—		1		1		—		1		—
Total	169		169		8		161		—		175		175		10		165		—

Derivatives:^a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross asset position	12		12		—		12		—		46		46		—		46		—
Crude oil options											268		268		—		—		268
Copper futures and swap contracts	1		1		1		—		—		4		4		4		—		—
Copper forward contracts											3		3		2		1		—
Total	13		13		1		12		—		321		321		6		47		268

Total assets			$	228	$	33	$	195	$	—			$	544	$	41	$	235	$	268

Liabilities
Derivatives:^a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross liability position	$	75	$	75	$	—	$	75	$	—	$	60	$	60	$	—	$	60	$	—
Crude oil options	182		182		—		—		182
Copper futures and swap contracts	5		5		5		—		—		5		5		4		1		—
Copper forward contracts	4		4		2		2		—
Total	266		266		7		77		182		65		65		4		61		—

Long-term debt, including current portion^f	19,737		19,882		—		19,882		—		20,312		19,866		—		19,866		—

Total liabilities			$	20,148	$	7	$	19,959	$	182			$	19,931	$	4	$	19,927	$	—

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	At December 31, 2013										At December 31, 2014
	Carrying		Fair Value								Carrying		Fair Value
	Amount		Total		Level 1		Level 2		Level 3		Amount		Total		Level 1		Level 2		Level 3
Assets
Investment securities:^a,b
Investment securities:^a,b,c
U.S. core fixed income fund	$	21	$	21	$	—	$	21	$	—	$	23	$	23	$	—	$	23	$	—
Money market funds	18		18		18		—		—		20		20		20		—		—
Equity securities	5		5		5		—		—		3		3		3		—		—
Total	44		44		23		21		—		46		46		23		23		—

Legally restricted funds:^a,b,d
U.S. core fixed income fund	48		48		—		48		—		52		52		—		52		—
Government bonds and notes											39		39		—		39		—
Corporate bonds											27		27		—		27		—
Government mortgage-backed securities	34		34		—		34		—		25		25		—		25		—
Corporate bonds	28		28		—		28		—
Government bonds and notes	28		28		—		28		—
Asset-backed securities											17		17		—		17		—
Money market funds	28		28		28		—		—		11		11		11		—		—
Asset-backed securities	15		15		—		15		—
Municipal bonds	1		1		—		1		—		1		1		—		1		—
Total	182		182		28		154		—		172		172		11		161		—

Derivatives:^a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross asset position	63		63		—		63		—		15		15		—		15		—
Copper futures and swap contracts	6		6		5		1		—
Crude oil options											316		316		—		—		316
Total	69		69		5		64		—		331		331		—		15		316

Total assets			$	295	$	56	$	239	$	—			$	549	$	34	$	199	$	316

Liabilities
Derivatives:^a
Derivatives:^a,e
Embedded derivatives in provisional sales/purchase
contracts in a gross liability position^e	$	16	$	16	$	—	$	16	$	—
Crude oil options^e	309		309		—		—		309
Natural gas swaps^e	4		4		—		4		—
Copper forward contracts^e	1		1		1		—		—
Plains Offshore warrants^g	2		2		—		—		2
contracts in a gross liability position											$	93	$	93	$	—	$	93	$	—
Copper futures and swap contracts											7		7		6		1		—
Total	332		332		1		20		311		100		100		6		94		—

Long-term debt, including current portion^f	20,706		20,487		—		20,487		—		18,849		18,735		—		18,735		—

Total liabilities			$	20,819	$	1	$	20,507	$	311			$	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.

~~Excluded~~ ~~$115 million~~ ofExcludes time deposits of $116 million (which approximated fair value) included in other assets at ~~September 30,~~March 31, 2015, and $115 million at December 31, 2014, ~~(included in other assets),~~ associated with an assurance bond to support ~~PTFI's~~PT Freeport Indonesia's (PT-FI) commitment for smelter development in ~~Indonesia (refer to Note 9 for further discussion).~~Indonesia.

~~Excluded~~Excludes time deposits of $18 million (which approximated fair value) ~~of $9 million at~~ ~~September 30, 2014~~ ~~(included~~included in other current ~~assets)~~assets at March 31, 2015, and $17 million at December 31, 2014, associated with a customs audit assessment and a reclamation guarantee at ~~PT-FI, and $15~~PT-FI. Also, excludes $115 million (which approximated fair value) included in other current assets ~~and $210 million in other assets~~ at ~~December~~March 31, ~~2013,~~2015, associated with a restricted escrow account for the ~~Cerro Verde royalty dispute.~~shareholder derivative litigation (refer to Note 8).


e.	Refer to Note 76 for further discussion and balance sheet classifications. Crude oil options are net of $~~269~~159 million at ~~September 30, 2014~~March 31, 2015, and ~~$444~~$210 million at December 31, ~~2013,~~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.


g.	~~Included in other liabilities.~~

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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.

Fixed income securities (U.S. core fixed income funds, government securities, corporate bonds, asset-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 ~~have critical inputs of~~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;~~maturity (refer to Note 6 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 ~~IntercontinentalExchange,~~Intercontinental Exchange Holdings, Inc. crude oil prices, volatilities, ~~interest rates and contract terms. FCX~~'~~s derivative financial instruments for natural gas swaps are valued using a pricing model that has various inputs including NYMEX price quotations,~~ 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 2014 natural gas swaps are classified within Level 2 of the fair value hierarchy because the inputs used in the valuation models are directly or indirectly observable for substantially the full term of the instruments. The 2014 and 2015 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 substantially 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 1731 percent to 3356 percent, with a weighted average of 2138 percent. The weighted-average cost of deferred premiums ~~ranged from~~totals $~~5.15~~6.89 per barrel to ~~$7.22~~ ~~per barrel, with a weighted average of~~ ~~$6.64~~ ~~per barrel.~~at March 31, 2015. Refer to Note 76 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 76 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.

The fair value of warrants associated with the Plains Offshore Preferred Stock was determined with an option pricing model that used unobservable inputs. The inputs used in the valuation model are the estimated fair value of the underlying Plains Offshore common stock, expected exercise price, expected term, expected volatility and risk-free interest rate. The assumptions used in the valuation model are highly subjective because the common stock of Plains Offshore is not publicly traded. As a result, these warrants are classified within Level 3 of the fair value hierarchy.

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.

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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 ~~September 30, 2014~~March 31, 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 Plains Offshore
Options Warrants
Fair value at December 31, 2013 $ (309 ) $ (2 )
Net realized losses (21 )
^a
—

Net unrealized (losses) gains included in earnings related to assets and liabilities still held at the end of the period (29 )
^b
2
^c
Settlement payments 177
—

Fair value at September 30, 2014 $ (182 ) $ —



	Crude Oil
	Options
Fair value at December 31, 2014	$	316
Net realized gains	3			^a
Net unrealized gains included in earnings related to assets and liabilities still held at the end of the period	48
Net settlement receipts	(99		)	^b
Fair value at March 31, 2015	$	268


a.	~~Included~~Includes net realized ~~losses~~gains of ~~$20~~$4 million, ~~recorded in revenues and~~partially offset by $1 million of interest expense associated with the deferred premiums.


b.	~~Included net unrealized losses~~ Includes interest payments of ~~$28~~$1 million ~~recorded in revenues and $1 million of interest expense associated with the deferred premiums.~~


c.	~~Recorded in other income, net.~~.

NOTE 9.8. CONTINGENCIES AND COMMITMENTS

Litigation. ~~During third-quarter 2014, there were no significant developments in~~The following information includes a discussion of updates to previously reported legal proceedings included in Note 12 of ~~FCX’s~~FCX's annual report on Form 10-K for the year ended December 31, ~~2013~~2014.

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, ~~as updated~~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 funded an escrow account with the $115 million settlement amount, from which the proceeds, net of plaintiffs’ legal fees and expenses, are expected to be released to FCX in ~~Note 9~~May 2015. Upon the release of ~~FCX's quarterly report on Form 10-Q~~funds, FCX expects to recognize a gain in second-quarter 2015 for the ~~quarter ended March 31, 2014.~~amount of the net proceeds. As a result and in accordance with the approved settlement terms, FCX expects the Board to declare a special dividend of approximately $115 million ($0.11 per share) that would be payable in early August 2015, corresponding with the timing of FCX’s next regular quarterly dividend.

Tax and Other Matters. ~~Cerro Verde Royalty Dispute.~~There were no significant changes to the Cerro Verde royalty dispute or other Peruvian tax matters during the first ~~nine months~~quarter of ~~2014~~2015 (refer to Note 12 of FCX’s annual report on Form 10-K for the year ended December 31, ~~2013~~2014, for further discussion of ~~this matter)~~these matters).

Indonesia Tax Matters. AsThe 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, ~~2013,~~ 2014.

PT-FI ~~has~~ received assessments from the ~~Indonesian~~local regional tax ~~authorities~~authority in Papua, Indonesia, for additional taxes and ~~interest~~penalties related to ~~various audit exceptions~~water rights tax payments for the ~~years 2005, 2006, 2007, 2008 and 2011.~~period from January 2011 through January 2015. PT-FI has filed objections to these assessments. In March 2015, the local government of Papua rejected PT-FI’s objections to the assessments ~~because it believes it has properly determined~~related to the period from January 2011 through December 2014, and ~~paid its taxes.~~

~~Required estimated income tax payments for 2012 significantly exceeded PT-FI’s 2012 reported income tax liability, which resulted~~ in a ~~$303 million~~ ~~overpayment (included in other accounts receivable in the condensed consolidated balance sheets at December 31, 2013). During second-quarter 2014,~~April 2015, PT-FI filed appeals with the Indonesian tax ~~authorities issued tax assessments for 2012 of~~ ~~$137 million~~ ~~and other offsets of~~ ~~$15 million, and refunded the balance of~~ ~~$151 million~~ ~~(before foreign exchange adjustments). PT-FI expects to file objections and use other means available under Indonesian tax laws and regulations to recover all overpayments that remain in dispute.~~

court. As of ~~September 30, 2014,~~March 31, 2015, the aggregate amount of these assessments, including penalties, was 2.3 trillion Indonesian rupiah ($177 million based on exchange rates at March 31, 2015). No amounts have been accrued for these assessments as of March 31, 2015, because PT-FI ~~had~~ ~~$392 million~~ ~~included in other assets for amounts paid on disputed tax assessments, which it~~ believes ~~are collectable.~~

~~Mining Contract - Indonesia.~~ ~~On July 25, 2014, PT-FI entered into a Memorandum of Understanding (MOU) with the Indonesian government under which PT-FI and the government agreed to negotiate an amended~~its Contract of Work ~~(COW)~~exempts it from these payments. PT-FI may be required to ~~address provisions related to~~record a charge in second-quarter 2015 for all or a portion of the ~~size of PT-FI’s concession area, royalties and taxes, domestic processing and refining, divestment, local content, and continuation of operations post-2021.~~assessments.

Under the MOU, provisions to be addressed in the negotiation of an amended COW include provisions for the development of new copper smelting and refining capacity in Indonesia, which will take into consideration an equitable sharing of costs between PT-FI (and any partners in the project) and the Indonesian government through fiscal incentives, provisions for divestment to the Indonesian government and/or Indonesian nationals of up to a 30 percent interest (an additional 20.64 percent interest) in PT-FI at fair value, and continuation of operations from 2022 through 2041. The MOU provides that negotiations for an amended COW will take into consideration PT-FI’s need for assurance of legal and fiscal terms post-2021 for PT-FI to continue with its large-scale investment program

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~~for the development of its underground reserves. PT-FI is engaged in discussions with the Indonesian government regarding an amended COW.~~

Effective with the signing of the MOU, PT-FI provided a $115 million assurance bond to support its commitment for smelter development, agreed to increase royalties to 4.0 percent for copper and 3.75 percent for gold from the previous rates of 3.5 percent for copper and 1.0 percent for gold, and to pay export duties set forth in a new regulation. The Indonesian government revised its January 2014 regulations (as discussed in Note 13 of FCX’s annual report on Form 10-K for the year ended December 31, 2013) regarding export duties to incorporate reduced rates for copper concentrate exports for companies engaged in smelter development. The revised regulations provide for duties on copper concentrate exports during smelter development initially at 7.5 percent, declining to 5.0 percent when development progress exceeds 7.5 percent and is eliminated when development progress exceeds 30 percent. In addition, PT-FI is required to apply for renewal of export permits at six-month intervals, with the next renewal date in January 2015.

~~Under the MOU, no terms of the COW other than those relating to the export duties, smelter bond and royalties described previously will be changed until the completion of an amended COW.~~

NOTE ~~10.~~9. BUSINESS SEGMENTS

FCX has organized its operations into six primary divisions – North America copper mines, South America mining, Indonesia mining, Africa mining, Molybdenum mines and U.S. oil ~~and~~& gas operations. 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. ~~FCX's U.S. oil and gas operations reflect the results of FM O&G beginning June 1, 2013.~~ Operating segments that meet certain thresholds are reportable segments, which are separately disclosed ~~separately~~ in the following ~~tables.~~

On November 3, 2014, FCX completed the sale of its 80 percent ownership interests in the Candelaria mine, a separately reported segment, and the Ojos del Salado mine, reported as a component of other South America mines. Refer to Note 13 for further discussion.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 ~~mining operations~~mines to other divisions, including Atlantic Copper and on 25 percent of PT-FI's sales to PT Smelting, 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																																													Mining Operations
	North America Copper Mines								South America								Indonesia			Africa																										North America Copper Mines								South America								Indonesia				Africa
																										Atlantic			Other											Corporate,																																Atlantic			Other										Corporate,
																						Molyb-				Copper			Mining							U.S.				Other																												Molyb-				Copper			Mining						U.S.				Other
			Other						Cerro		Candel-		Other									denum		Rod &		Smelting			& Elimi-				Total			Oil & Gas				& Elimi-			FCX						Other					Cerro		Other												denum		Rod &		Smelting			& Elimi-				Total		Oil & Gas				& Elimi-				FCX
	Morenci		Mines			Total			Verde		aria		Mines		Total		Grasberg			Tenke		Mines		Refining		& Refining			nations				Mining			Operations				nations			Total			Morenci			Mines			Total		Verde		Mines^a				Total		Grasberg				Tenke		Mines		Refining		& Refining			nations				Mining		Operations^b				nations				Total
Three Months Ended September 30, 2014
Three Months Ended March 31, 2015
Revenues:
Unaffiliated customers	$	140	$	79		$	219		$	295	$	141	$	300	$	736	$	1,086	^a	$	379	$	—	$	1,219	$	597		$	470		^b	$	4,706		$	990		^c	$	—		$	5,696		$	106		$	115		$	221	$	248	$	231			$	479	$	621		^c	$	382	$	—	$	1,062	$	540		$	348		^d	$	3,653	$	500		^e	$	—			$	4,153
Intersegment	428		843			1,271			63		48		—		111		167			49		173		8		4			(1,783		)		—			—				—			—			450			664			1,114		14		(7		)	^f	7		(14		)	^f	28		113		7		6			(1,261		)		—		—				—				—
Production and delivery	341		561			902			178		142		151		471		700			206		86		1,220		578			(1,283		)		2,880			273				(1		)	3,152			374			569			943		198		147				345		439				235		83		1,063		519			(1,001		)		2,626		283				3				2,912
Depreciation, depletion and amortization	51		82			133			41		14		47		102		92			58		25		2		11			15				438			504				3			945			51			82			133		37		38				75		70				73		26		2		10			16				405		530				4				939
Impairment of oil and gas properties	—		—			—			—		—		—		—		—			—		—		—		—			—				—			308				—			308			—			—			—		—		—				—		—				—		—		—		—			—				—		3,104				—				3,104
Selling, general and administrative expenses	—		1			1			—		—		1		1		27			3		—		—		4			7				43			55				60			158			1			—			1		1		—				1		25				3		—		—		5			6				41		54				59				154
Mining exploration and research expenses	—		2			2			—		—		—		—		—			—		—		—		—			27				29			—				—			29			—			3			3		—		—				—		—				—		—		—		—			30				33		—				—				33
Environmental obligations and shutdown costs	—		(5		)	(5		)	—		—		—		—		—			—		—		—		—			23				18			—				—			18			—			—			—		—		—				—		—				—		—		—		—			13				13		—				—				13
Net gain on sales of assets	—		(14		)	(14		)	—		—		—		—		—			—		—		—		—			(32		)		(46		)	—				—			(46		)
Net gain on sale of assets																																											—				(39	)		(39	)		—		—		—				—		—				—		—		—		—			(39		)		—		—				(39		)
Operating income (loss)	176		295			471			139		33		101		273		434			161		62		5		8			(70		)		1,344			(150		)		(62		)	1,132			130			164			294		26		39				65		73				99		4		4		12			23				574		(3,471		)		(66		)		(2,963		)

Interest expense, net	1		—			1			1		—		—		1		—			—		—		—		3			19				24			51				83			158			1			—			1		1		—				1		—				—		—		—		3			40				45		37				64				146
Provision for (benefit from) income taxes	—		—			—			47		4		91		142		181			36		—		—		—			—				359			—				(10		)	349			—			—			—		5		19				24		29				26		—		—		—			—				79		—				(774		)		(695		)
Total assets at September 30, 2014	3,689		5,742			9,431			7,030		1,511		2,210		10,751		8,537			5,010		2,089		282		948			1,025				38,073			25,328				575			63,976
Total assets at March 31, 2015																																											3,802				5,646			9,448			7,991		1,970		9,961				8,882		5,108				2,075		314		809		1,379			37,976				17,887		202				56,065
Capital expenditures	158		30			188			416		7		16		439		243			40		12		1		3			11				937			908				8			1,853			84			23			107		431		14				445		225				39		3		1		4			16				840		1,018				9				1,867

Three Months Ended September 30, 2013
Three Months Ended March 31, 2014
Revenues:
Unaffiliated customers	$	100	$	145		$	245		$	434	$	318	$	300	$	1,052	$	1,108	^a	$	406	$	—	$	1,247	$	514		$	417		^b	$	4,989		$	1,176		^c	$	—		$	6,165		$	23		$	61		$	84	$	280	$	422			$	702	$	462		^c	$	306	$	—	$	1,146	$	588		$	436		^d	$	3,724	$	1,261		^e	$	—			$	4,985
Intersegment	375		681			1,056			27		60		—		87		3			14		121		6		2			(1,289		)		—			—				—			—			444			758			1,202		64		132				196		8				21		126		8		5			(1,566		)		—		—				—				—
Production and delivery	287		520			807			175		163		156		494		617			190		82		1,245		523			(916		)		3,042			288				2			3,332			283			503			786		165		311				476		383				152		76		1,148		588			(1,183		)		2,426		311				—				2,737
Depreciation, depletion and amortization	35		67			102			35		19		31		85		60			64		21		2		10			9				353			563				3			919			34			73			107		36		51				87		48				51		22		2		10			19				346		616				4				966
Selling, general and administrative expenses	—		1			1			—		1		1		2		29			3		—		—		5			5				45			51				62			158			—			1			1		1		1				2		21				3		—		—		4			7				38		57				40				135
Mining exploration and research expenses	—		2			2			—		—		—		—		1			—		—		—		—			52				55			—				2			57			—			2			2		—		—				—		—				—		—		—		—			28				30		—				—				30
Environmental obligations and shutdown costs	—		5			5			—		—		—		—		—			—		—		—		—			(13		)		(8		)	—				—			(8		)	—			—			—		—		—				—		—				—		—		—		—			6				6		—				—				6
Operating income (loss)	153		231			384			251		195		112		558		404			163		18		6		(22		)	(9		)		1,502			274				(69		)	1,707			150			240			390		142		191				333		18				121		28		4		(9		)	(7		)		878		277				(44		)		1,111

Interest expense, net	—		—			—			—		—		—		—		—			—		—		—		4			20				24			74				64			162			1			—			1		—		—				—		—				—		—		—		4			18				23		76				62				161
Provision for income taxes	—		—			—			92		67		35		194		173			33		—		—		—			—				400			—				99			499			—			—			—		57		70				127		18				24		—		—		—			—				169		—				188				357
Total assets at September 30, 2013	2,915		5,734			8,649			6,440		1,612		2,478		10,530		7,399			4,862		2,094		308		691			1,267				35,800			26,347				451			62,598
Total assets at March 31, 2014																																											3,412				5,827			9,239			6,730		4,059		10,789				7,466		4,904				2,101		289		951		1,119			36,858				26,385		489				63,732
Capital expenditures	172		80			252			224		23		17		264		209			52		46		1		20			51				895			738				12			1,645			244			59			303		400		23				423		236				31		19		1		1			10				1,024		579				9				1,612


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


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


c.	~~Included~~Includes PT-FI’s sales to PT Smelting totaling $~~628~~350 million in ~~third-quarter~~first-quarter ~~2014~~2015 and $~~458~~373 million in ~~third-quarter~~first-quarter ~~2013~~2014.


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


c.e.	~~Included~~ Includes net mark-to-market gains (losses) associated with crude oil and natural gas derivative contracts totaling ~~$64~~$52 million in ~~third-quarter 2014~~first-quarter2015 and ~~$(170)~~$(50) million in ~~third-quarter 2013.~~

~~Table of Contents~~

(In millions) Mining Operations
North America Copper Mines South America Indonesia Africa
Atlantic Other Corporate,
Molyb- Copper Mining U.S. Other
Other Cerro Candel- Other denum Rod & Smelting & Elimi- Total Oil & Gas & Elimi- FCX
Morenci Mines Total Verde aria Mines Total Grasberg Tenke Mines Refining & Refining nations Mining Operations nations Total
Nine Months Ended September 30, 2014
Revenues:
Unaffiliated customers $ 215
$ 195
$ 410
$ 996
$ 482
$ 905
$ 2,383
$ 2,071
^a
$ 1,071
$ —
$ 3,599
$ 1,808
$ 1,374
^b
$ 12,716
$ 3,487
^c
$ —
$ 16,203
Intersegment 1,346
2,489
3,835
150
238
5
393
175
102
469
24
15
(5,013 ) —
—
—
—
Production and delivery 936
1,622
2,558
538
456
483
1,477
1,594
556
243
3,601
1,784
(3,753 ) 8,060
913
(2 ) 8,971
Depreciation, depletion and amortization 128
240
368
120
49
115
284
194
172
71
7
31
51
1,178
1,736
10
2,924
Impairment of oil and gas properties —
—
—
—
—
—
—
—
—
—
—
—
—
—
308
—
308
Selling, general and administrative expenses 1
2
3
2
1
2
5
73
9
—
—
13
20
123
171
163
457
Mining exploration and research expenses —
6
6
—
—
—
—
—
—
—
—
—
87
93
—
—
93
Environmental obligations and shutdown costs —
(5 ) (5 ) —
—
—
—
—
—
—
—
—
105
100
—
—
100
Net gain on sales of assets —
(14 ) (14 ) —
—
—
—
—
—
—
—
—
(32 ) (46 ) —
—
(46 )
Operating income (loss) 496
833
1,329
486
214
310
1,010
385
436
155
15
(5 ) (117 ) 3,208
359
(171 ) 3,396

Interest expense, net 2
1
3
1
—
—
1
—
—
—
—
10
55
69
201
213
483
Provision for income taxes —
—
—
177
72
160
409
166
93
—
—
—
—
668
—
366
1,034
Capital expenditures 691
124
815
1,207
29
42
1,278
722
100
45
3
9
38
3,010
2,392
13
5,415

Nine Months Ended September 30, 2013
Revenues:
Unaffiliated customers $ 218
$ 266
$ 484
$ 1,035
$ 709
$ 922
$ 2,666
$ 2,443
^a
$ 1,199
$ —
$ 3,842
$ 1,730
$ 1,157
^b
$ 13,521
$ 1,512
^c
$ 3
$ 15,036
Intersegment 1,255
2,256
3,511
222
216
—
438
190
24
408
20
12
(4,603 ) —
—
—
—
Production and delivery 885
1,574
2,459
535
504
446
1,485
1,743
560
240
3,835
1,726
(3,531 ) 8,517
377
10
8,904
Depreciation, depletion and amortization 105
207
312
105
44
93
242
173
179
62
7
32
31
1,038
732
8
1,778
Selling, general and administrative expenses 1
3
4
2
2
1
5
82
9
—
—
14
23
137
65
255
457
Mining exploration and research expenses —
3
3
—
—
—
—
1
—
—
—
—
161
165
—
8
173
Environmental obligations and shutdown costs —
(1 ) (1 ) —
—
—
—
—
—
—
—
—
24
23
—
—
23
Operating income (loss) 482
736
1,218
615
375
382
1,372
634
475
106
20
(30 ) (154 ) 3,641
338
(278 ) 3,701

Interest expense, net 3
1
4
2
—
—
2
12
2
—
—
12
60
92
100
159
351
Provision for income taxes —
—
—
215
131
126
472
289
99
—
—
—
—
860
—
107
^d
967
Capital expenditures 529
266
795
596
91
47
734
720
155
128
3
39
91
2,665
928
30
3,623


a.	~~Included PT-FI’s sales to PT Smelting totaling $1.5 billion for the first nine months of~~ first-quarter2014 ~~and $1.2 billion for the first nine months of~~ ~~2013~~.


b.f.	~~Included revenues~~Amounts include net reductions for provisional pricing adjustments to prior period open sales. There were no intersegment sales from ~~FCX's molybdenum sales company, which included sales of molybdenum produced by the Molybdenum mines and by certain of the North and South America copper mines.~~El Abra or Grasberg in first-quarter 2015.

Included net mark-to-market losses associated with crude oil and natural gas derivative contracts totaling $56 million for the first nine months of 2014 and $205 million for the period from June 1, 2013 to September 30, 2013.


d.	~~Included $183 million of net benefits resulting from second-quarter 2013 oil and gas acquisitions.~~

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Table of Contents

NOTE ~~11.~~10. GUARANTOR FINANCIAL STATEMENTS

~~In March 2013, FCX completed~~All of the ~~sale of~~ ~~$6.5 billion~~ ~~of senior notes. These notes, along with FCX's~~ senior notes ~~sold in February 2012,~~issued by FCX are fully and unconditionally guaranteed on a senior basis jointly and severally by FMFreeport-McMoRan Oil & Gas LLC (FM O&G ~~LLC,~~LLC), as guarantor, which is a 100 percent owned subsidiary of FMFCX Oil & Gas Inc. (FM O&G&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. In the future, 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~~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 ~~September 30, 2014~~March 31, 2015, and December 31, ~~2013,~~2014, and the related condensed consolidating statements of comprehensive (loss) income ~~for the three~~ and~~nine~~ ~~months ended~~ ~~September 30, 2014~~ ~~and 2013, and condensed consolidating statements of~~ cash flows for the ~~nine~~three months ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014 (in millions), which should be read in conjunction with FCX's notes to the consolidated financial statements.

CONDENSED CONSOLIDATING BALANCE SHEET

~~September 30, 2014~~March 31, 2015


	FCX			FM O&G LLC		Non-guarantor					Consolidated		FCX			FM O&G LLC		Non-guarantor					Consolidated
	Issuer			Guarantor		Subsidiaries		Eliminations			FCX		Issuer			Guarantor		Subsidiaries		Eliminations			FCX
ASSETS
Current assets:
Cash and cash equivalents	$	—		$	1	$	657	$	—		$	658
Accounts receivable	348			1,814		2,187		(2,042		)	2,307
Other current assets	104			73		5,889		—			6,066
Total current assets	452			1,888		8,733		(2,042		)	9,031
Current assets													$	288		$	3,623	$	8,257	$	(3,314	)	$	8,854
Property, plant, equipment and mining development costs, net	23			45		26,236		—			26,304		21			48		26,526		—			26,595
Oil and gas properties, net - full cost method:
Subject to amortization, less accumulated amortization	—			4,235		6,727		344			11,306		—			2,309		4,404		—			6,713
Not subject to amortization	—			2,346		8,685		—			11,031		—			2,553		7,112		—			9,665
Investments in consolidated subsidiaries	33,908			10,492		13,063		(57,463		)	—		25,828			4,117		7,005		(36,950		)	—
Goodwill	—			217		1,500		—			1,717
Other assets	6,512			3,913		4,439		(10,277		)	4,587		9,814			4,276		4,160		(14,012		)	4,238
Total assets	$	40,895		$	23,136	$	69,383	$	(69,438	)	$	63,976	$	35,951		$	16,926	$	57,464	$	(54,276	)	$	56,065

LIABILITIES AND EQUITY
Current liabilities	$	1,664		$	985	$	5,294	$	(1,600	)	$	6,343	$	1,819		$	400	$	5,505	$	(3,314	)	$	4,410
Long-term debt, less current portion	13,355			5,301		6,562		(7,243		)	17,975		15,900			4,771		9,625		(10,542		)	19,754
Deferred income taxes	4,233		^a	—		3,326		—			7,559		2,390		^a	—		3,235		—			5,625
Environmental and asset retirement obligations, less current portion	—			302		3,352		—			3,654		—			303		3,375		—			3,678
Other liabilities	52			3,403		1,751		(3,476		)	1,730		49			3,359		1,874		(3,470		)	1,812
Total liabilities	19,304			9,991		20,285		(12,319		)	37,261		20,158			8,833		23,614		(17,326		)	35,279

Redeemable noncontrolling interest	—			—		749		—			749		—			—		755		—			755

Equity:
Stockholders' equity	21,591			13,145		44,460		(57,605		)	21,591		15,793			8,093		29,376		(37,469		)	15,793
Noncontrolling interests	—			—		3,889		486			4,375		—			—		3,719		519			4,238
Total equity	21,591			13,145		48,349		(57,119		)	25,966		15,793			8,093		33,095		(36,950		)	20,031
Total liabilities and equity	$	40,895		$	23,136	$	69,383	$	(69,438	)	$	63,976	$	35,951		$	16,926	$	57,464	$	(54,276	)	$	56,065


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

2421

Table of Contents

CONDENSED CONSOLIDATING BALANCE SHEET

December 31, ~~2013~~2014


	FCX			FM O&G LLC		Non-guarantor					Consolidated		FCX			FM O&G LLC		Non-guarantor					Consolidated
	Issuer			Guarantor		Subsidiaries		Eliminations			FCX		Issuer			Guarantor		Subsidiaries		Eliminations			FCX
ASSETS
Current assets:
Cash and cash equivalents	$	—		$	—	$	1,985	$	—		$	1,985
Accounts receivable	855			659		2,258		(1,210		)	2,562
Other current assets	114			38		5,273		—			5,425
Total current assets	969			697		9,516		(1,210		)	9,972
Current assets													$	323		$	2,635	$	8,659	$	(2,572	)	$	9,045
Property, plant, equipment and mining development costs, net	27			43		23,972		—			24,042		22			46		26,152		—			26,220
Oil and gas properties, net - full cost method:
Subject to amortization, less accumulated amortization	—			6,207		6,265		—			12,472		—			3,296		5,907		(16		)	9,187
Not subject to amortization	—			2,649		8,238		—			10,887		—			2,447		7,640		—			10,087
Investments in consolidated subsidiaries	31,162			9,712		12,468		(53,342		)	—		28,765			6,460		10,246		(45,471		)	—
Goodwill	—			437		1,479		—			1,916
Other assets	7,126			4,640		4,128		(11,710		)	4,184		8,914			3,947		4,061		(12,787		)	4,135
Total assets	$	39,284		$	24,385	$	66,066	$	(66,262	)	$	63,473	$	38,024		$	18,831	$	62,665	$	(60,846	)	$	58,674

LIABILITIES AND EQUITY
Current liabilities	$	1,003		$	758	$	4,222	$	(1,210	)	$	4,773	$	1,592		$	560	$	5,592	$	(2,572	)	$	5,172
Long-term debt, less current portion	13,184			7,199		8,056		(8,045		)	20,394		14,930			3,874		8,879		(9,312		)	18,371
Deferred income taxes	4,137		^a	—		3,273		—			7,410		3,161		^a	—		3,237		—			6,398
Environmental and asset retirement obligations, less current portion	—			301		2,958		—			3,259		—			302		3,345		—			3,647
Other liabilities	26			3,436		1,893		(3,665		)	1,690		54			3,372		1,910		(3,475		)	1,861
Total liabilities	18,350			11,694		20,402		(12,920		)	37,526		19,737			8,108		22,963		(15,359		)	35,449

Redeemable noncontrolling interest	—			—		716		—			716		—			—		751		—			751

Equity:
Stockholders' equity	20,934			12,691		41,100		(53,791		)	20,934		18,287			10,723		35,268		(45,991		)	18,287
Noncontrolling interests	—			—		3,848		449			4,297		—			—		3,683		504			4,187
Total equity	20,934			12,691		44,948		(53,342		)	25,231		18,287			10,723		38,951		(45,487		)	22,474
Total liabilities and equity	$	39,284		$	24,385	$	66,066	$	(66,262	)	$	63,473	$	38,024		$	18,831	$	62,665	$	(60,846	)	$	58,674


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

2522

Table of Contents

CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE (LOSS) INCOME

~~Three and Nine Months Ended~~ ~~September 30, 2014~~

Three Months Ended September 30, 2014
FCX FM O&G LLC Non-guarantor Consolidated
Issuer Guarantor Subsidiaries Eliminations FCX
Revenues $ —
$ 370
$ 5,326
$ —
$ 5,696
Total costs and expenses 12
916
3,966
(330 ) 4,564
Operating (loss) income (12 ) (546 ) 1,360
330
1,132
Interest expense, net (99 ) (38 ) (37 ) 16
(158 )
Net gain on early extinguishment of debt —
58
—
—
58
Other income (expense), net 15
—
24
(16 ) 23
Benefit from (provision for) income taxes 46
(104 ) (166 ) (125 ) (349 )
Equity in affiliated companies' net earnings (losses) 602
381
(111 ) (874 ) (2 )
Net income (loss) 552
(249 ) 1,070
(669 ) 704
Net income and preferred dividends attributable to noncontrolling interests —
—
(130 ) (22 ) (152 )
Net income (loss) attributable to FCX common stockholders $ 552
$ (249 ) $ 940
$ (691 ) $ 552

Other comprehensive income —
—
7
—
7
Total comprehensive income (loss) $ 552
$ (249 ) $ 947
$ (691 ) $ 559

Nine Months Ended September 30, 2014
FCX FM O&G LLC Non-guarantor Consolidated
Issuer Guarantor Subsidiaries Eliminations FCX
Revenues $ —
$ 1,584
$ 14,619
$ —
$ 16,203
Total costs and expenses 44
1,931
11,170
(338 ) 12,807
Operating (loss) income (44 ) (347 ) 3,449
338
3,396
Interest expense, net (268 ) (123 ) (146 ) 54
(483 )
Net (loss) gain on early extinguishment of debt (1 ) 64
—
—
63
Other income (expense), net 52
1
49
(54 ) 48
Benefit from (provision for) income taxes 51
(121 ) (836 ) (128 ) (1,034 )
Equity in affiliated companies' net earnings (losses) 1,754
637
228
(2,619 ) —
Net income (loss) 1,544
111
2,744
(2,409 ) 1,990
Net income and preferred dividends attributable to noncontrolling interests —
—
(421 ) (25 ) (446 )
Net income (loss) attributable to FCX common stockholders $ 1,544
$ 111
$ 2,323
$ (2,434 ) $ 1,544

Other comprehensive income —
—
11
—
11
Total comprehensive income (loss) $ 1,544
$ 111
$ 2,334
$ (2,434 ) $ 1,555



Three Months Ended March 31, 2015
	FCX			FM O&G LLC				Non-guarantor							Consolidated
	Issuer			Guarantor				Subsidiaries				Eliminations			FCX
Revenues	$	—		$	181			$	3,972			$	—		$	4,153
Total costs and expenses	16			1,318			^a	5,798			^a	(16		)	7,116
Operating (loss) income	(16		)	(1,137		)		(1,826		)		16			(2,963		)
Interest expense, net	(115		)	(4		)		(57		)		30			(146		)
Other income (expense), net	29			—				8				(30		)	7
(Loss) income before income taxes and equity in affiliated companies' net (losses) earnings	(102		)	(1,141		)		(1,875		)		16			(3,102		)
(Provision for) benefit from income taxes	(421		)	1,157				(35		)		(6		)	695
Equity in affiliated companies' net (losses) earnings	(1,951		)	(2,359		)		(3,530		)		7,841			1
Net (loss) income	(2,474		)	(2,343		)		(5,440		)		7,851			(2,406		)
Net income and preferred dividends attributable to noncontrolling interests	—			—				(56		)		(12		)	(68		)
Net (loss) income attributable to common stockholders	$	(2,474	)	$	(2,343	)		$	(5,496	)		$	7,839		$	(2,474	)

Other comprehensive income (loss)	12			—				12				(12		)	12
Total comprehensive (loss) income	$	(2,462	)	$	(2,343	)		$	(5,484	)		$	7,827		$	(2,462	)


a.	Includes impairment charges totaling $1.1 billion at the FM O&G LLC guarantor and $2.0 billion at the non-guarantor subsidiaries related to ceiling test impairment charges for FCX's oil and gas properties pursuant to full cost accounting rules.

~~Table of Contents~~

~~CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE INCOME~~

~~Three and Nine Months Ended September 30, 2013~~


Three Months Ended September 30, 2013
Three Months Ended March 31, 2014
	FCX			FM O&G LLC			Non-guarantor						Consolidated			FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX			Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Revenues	$	—		$	512		$	5,653		$	—		$	6,165		$	—		$	644		$	4,341		$	—		$	4,985
Total costs and expenses	11			452			3,995			—			4,458			11			526			3,339			(2		)	3,874
Operating (loss) income	(11		)	60			1,658			—			1,707			(11		)	118			1,002			2			1,111
Interest expense, net	(94		)	(51		)	(40		)	23			(162		)	(82		)	(41		)	(58		)	20			(161		)
Other income (expense), net	24			—			2			(23		)	3			20			—			33			(20		)	33
Benefit from (provision for) income taxes	35			(5		)	(529		)	—			(499		)
(Loss) income before income taxes and equity in affiliated companies' net earnings (losses)																(73		)	77			977			2			983
Provision for income taxes																(21		)	(43		)	(292		)	(1		)	(357		)
Equity in affiliated companies' net earnings (losses)	867			187			47			(1,102		)	(1		)	604			130			185			(919		)	—
Net income (loss)	821			191			1,138			(1,102		)	1,048			510			164			870			(918		)	626
Net income and preferred dividends attributable to noncontrolling interests	—			—			(202		)	(25		)	(227		)	—			—			(111		)	(5		)	(116		)
Net income (loss) attributable to FCX common stockholders	$	821		$	191		$	936		$	(1,127	)	$	821
Net income (loss) attributable to common stockholders																$	510		$	164		$	759		$	(923	)	$	510

Other comprehensive income	—			—			11			—			11
Other comprehensive income (loss)																3			—			3			(3		)	3
Total comprehensive income (loss)	$	821		$	191		$	947		$	(1,127	)	$	832		$	513		$	164		$	762		$	(926	)	$	513

Nine Months Ended September 30, 2013
FCX FM O&G LLC Non-guarantor Consolidated
Issuer Guarantor Subsidiaries Eliminations FCX
Revenues $ —
$ 674
$ 14,362
$ —
$ 15,036
Total costs and expenses 106
587
10,642
—
11,335
Operating (loss) income (106 ) 87
3,720
—
3,701
Interest expense, net (222 ) (63 ) (104 ) 38
(351 )
Loss on early extinguishment of debt (45 ) —
—
—
(45 )
Gain on investment in MMR 128
—
—
—
128
Other income (expense), net 39
—
12
(38 ) 13
Benefit from (provision for) income taxes 61
(10 ) (1,018 ) —
(967 )
Equity in affiliated companies' net earnings (losses) 2,096
207
1
(2,301 ) 3
Net income (loss) 1,951
221
2,611
(2,301 ) 2,482
Net income and preferred dividends attributable to noncontrolling interests —
—
(494 ) (37 ) (531 )
Net income (loss) attributable to FCX common stockholders $ 1,951
$ 221
$ 2,117
$ (2,338 ) $ 1,951

Other comprehensive income —
—
22
—
22
Total comprehensive income (loss) $ 1,951
$ 221
$ 2,139
$ (2,338 ) $ 1,973

2723

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CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

~~Nine~~Three Months Ended ~~September 30, 2014~~March 31, 2015


	FCX			FM O&G LLC			Non-guarantor						Consolidated			FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX			Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Cash flow from operating activities:
Net income (loss)	$	1,544		$	111		$	2,744		$	(2,409	)	$	1,990
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Net (loss) income																$	(2,474	)	$	(2,343	)	$	(5,440	)	$	7,851		$	(2,406	)
Adjustments to reconcile net (loss) income to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	3			673			2,269			(21		)	2,924			1			119			835			(16		)	939
Impairment of oil and gas properties	—			625			—			(317		)	308			—			1,062			2,042			—			3,104
Net losses on crude oil and natural gas derivative contracts	—			56			—			—			56
Net loss (gain) on early extinguishment of debt	1			(64		)	—			—			(63		)
Equity in (earnings) losses of consolidated subsidiaries	(1,754		)	(637		)	4			2,387			—
Net gains on crude oil derivative contracts																—			(52		)	—			—			(52		)
Equity in losses (earnings) of consolidated subsidiaries																1,951			2,359			3,530			(7,841		)	(1		)
Other, net	87			(17		)	(73		)	—			(3		)	(701		)	6			(86		)	—			(781		)
(Increases) decreases in working capital and changes in other tax payments, excluding amounts from dispositions	(217		)	(1,166		)	684			—			(699		)
Decreases (increases) in working capital and changes in other tax payments																1,171			(1,321		)	58			6			(86		)
Net cash (used in) provided by operating activities	(336		)	(419		)	5,628			(360		)	4,513			(52		)	(170		)	939			—			717

Cash flow from investing activities:
Capital expenditures	—			(1,771		)	(3,644		)	—			(5,415		)	—			(302		)	(1,565		)	—			(1,867		)
Acquisition of Deepwater GOM interests	—			—			(1,421		)	—			(1,421		)
Intercompany loans	1,151			734			—			(1,885		)	—			(905		)	(400		)	—			1,305			—
Investment in consolidated subsidiary	(959		)	(97		)	(696		)	1,752			—
Net proceeds from sale of Eagle Ford shale assets	—			2,971			—			—			2,971
Dividends from (investments in) consolidated subsidiaries																310			(14		)	32			(328		)	—
Other, net	—			32			189			—			221			—			—			127			—			127
Net cash provided by (used in) investing activities	192			1,869			(5,572		)	(133		)	(3,644		)
Net cash (used in) provided by investing activities																(595		)	(716		)	(1,406		)	977			(1,740		)

Cash flow from financing activities:
Proceeds from debt	2,806			—			540			—			3,346			1,515			—			758			—			2,273
Repayments of debt	(1,686		)	(1,996		)	(514		)	—			(4,196		)	(530		)	—			(272		)	—			(802		)
Intercompany loans	—			213			(2,098		)	1,885			—			—			903			402			(1,305		)	—
Cash dividends and distributions paid, and contributions received	(979		)	336			691			(1,392		)	(1,344		)	(327		)	—			(319		)	296			(350		)
Other, net	3			(2		)	(3		)	—			(2		)	(11		)	(18		)	(16		)	32			(13		)
Net cash provided by (used in) financing activities	144			(1,449		)	(1,384		)	493			(2,196		)	647			885			553			(977		)	1,108

Net increase (decrease) in cash and cash equivalents	—			1			(1,328		)	—			(1,327		)
Net (decrease) increase in cash and cash equivalents																—			(1		)	86			—			85
Cash and cash equivalents at beginning of period	—			—			1,985			—			1,985			—			1			463			—			464
Cash and cash equivalents at end of period	$	—		$	1		$	657		$	—		$	658		$	—		$	—		$	549		$	—		$	549

2824

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CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

~~Nine~~Three Months Ended ~~September 30, 2013~~March 31, 2014


	FCX			FM O&G LLC				Non-guarantor							Consolidated			FCX			FM O&G LLC			Non-guarantor							Consolidated
	Issuer			Guarantor				Subsidiaries				Eliminations			FCX			Issuer			Guarantor			Subsidiaries				Eliminations			FCX
Cash flow from operating activities:
Net income (loss)	$	1,951		$	221			$	2,611			$	(2,301	)	$	2,482		$	510		$	164		$	870			$	(918	)	$	626
Adjustments to reconcile net income (loss) to net cash (used in) provided by operating activities:
Depreciation, depletion and amortization	3			341				1,434				—			1,778			1			285			682				(2		)	966
Net losses on crude oil and natural gas derivative contracts	—			205				—				—			205			—			50			—				—			50
Net loss on early extinguishment of debt	45			—				—				—			45
Gain on investment in MMR	(128		)	—				—				—			(128		)
Equity in (earnings) losses of consolidated subsidiaries	(2,096		)	(207		)		2				2,301			—			(604		)	(130		)	(185		)		919			—
Other, net	8			(15		)		(143		)		—			(150		)	134			(9		)	(140		)		(13		)	(28		)
Decreases (increases) in working capital and changes in other tax payments, excluding amounts from acquisitions	112			518				(1,119		)		—			(489		)
(Increases) decreases in working capital and changes in other tax payments																		(234		)	339			(518		)		—			(413		)
Net cash (used in) provided by operating activities	(105		)	1,063				2,785				—			3,743			(193		)	699			709				(14		)	1,201

Cash flow from investing activities:
Capital expenditures	—			(621		)		(3,002		)		—			(3,623		)	—			(335		)	(1,277		)		—			(1,612		)
Acquisitions, net of cash acquired	(5,437		)	—				(4		)		—			(5,441		)
Intercompany loans	793			—				(1,095		)	—	302			—			190			(43		)	—			—	(147		)	—
Dividends from consolidated subsidiary	321			—			—	—				(321		)	—
Dividends from (investments in) consolidated subsidiaries																		212			(96		)	(430		)		314			—
Other, net	14			32				(70		)		—			(24		)	—			4			3				—			7
Net cash (used in) provided by investing activities	(4,309		)	(589		)		(4,171		)		(19		)	(9,088		)
Net cash provided by (used in) investing activities																		402			(470		)	(1,704		)		167			(1,605		)

Cash flow from financing activities:
Proceeds from debt	11,085			—				144				—			11,229			895			—			254				—			1,149
Repayments of debt and redemption of MMR preferred stock	(4,501		)	(416		)		(126		)		—			(5,043		)
Repayments of debt																		(780		)	—			(207		)		—			(987		)
Intercompany loans	—			(56		)		358				(302		)	—			—			(213		)	66				147			—
Cash dividends and distributions paid	(1,957		)	—				(478		)		321			(2,114		)
Cash dividends and distributions paid, and contributions received																		(326		)	(14		)	237				(300		)	(403		)
Other, net	(213		)	—				—				—			(213		)	2			—			—				—			2
Net cash provided by (used in) financing activities	4,414			(472		)		(102		)		19			3,859
Net cash (used in) provided by financing activities																		(209		)	(227		)	350				(153		)	(239		)

Net increase (decrease) in cash and cash equivalents	—			2				(1,488		)		—			(1,486		)	—			2			(645		)		—			(643		)
Cash and cash equivalents at beginning of period	—			—				3,705				—			3,705			—			—			1,985				—			1,985
Cash and cash equivalents at end of period	$	—		$	2			$	2,217			$	—		$	2,219		$	—		$	2		$	1,340			$	—		$	1,342

NOTE ~~12.~~11. NEW ACCOUNTING STANDARDS

In ~~May 2014,~~April 2015, the Financial Accounting Standards Board ~~(FASB)~~ issued an Accounting Standards Update (ASU)~~, which outlines a single comprehensive model and supersedes most~~ to simplify the presentation of the current revenue recognition guidance. For public entities, this ASU is effective for annual reporting periods beginning after December 15, 2016, and interim periods within that reporting period. Early adoption is not permitted. FCX is evaluating this new guidance, but does not expect it to have a significant impact on its current revenue recognition policies.

~~In April 2014, FASB issued an ASU, which revises the guidance for reporting discontinued operations.~~debt issuance costs. This ASU ~~amends~~requires that debt issuance costs related to a recognized debt liability be presented in the ~~definition~~balance sheet as a direct deduction from the carrying amount of ~~a discontinued operation and requires additional disclosures about disposal transactions~~ that ~~do not meet the definition of a discontinued operation.~~debt liability, consistent with debt discounts. For public entities, this ASU is effective for annual periods beginning ~~on or~~ after December 15, ~~2014,~~2015, and interim periods within ~~that year.~~those fiscal years. Early adoption is permitted ~~but only~~ for ~~disposals (or classifications as held for sale)~~financial statements that have not been ~~reported in financial statements~~ previously ~~issued or available for issuance.~~issued. FCX adopted this ASU in the first quarter of ~~2014.~~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.

~~Table of Contents~~

NOTE ~~13.~~12. SUBSEQUENT EVENTS

~~Candelaria and Ojos del Salado Disposition.~~ On ~~November 3, 2014, FCX completed the sale of its~~ ~~80 percent~~ ~~ownership interests in the Candelaria and Ojos del Salado copper mining operations and supporting infrastructure (Candelaria/Ojos) located in Chile to Lundin Mining Corporation for~~ ~~$1.8 billion~~ ~~in cash, before closing adjustments, and contingent consideration of up to~~ ~~$200 million~~. Contingent consideration is calculated as five percent of net copper revenues in any annual period over the next five years when the average realized copper price exceeds $4.00 per pound. Excluding contingent consideration, after-tax net proceeds approximated $1.5 billion, and FCX expects to record a gain of approximately $680 million (approximately $450 million after tax) associated with this transaction. The transaction has an effective date of June 30, 2014. FCX expects to use the proceeds from this transaction to repay indebtedness.

~~The sale of Candelaria/Ojos does not meet the criteria for classification as a discontinued operation.~~

~~The following table provides the major classes of assets and liabilities associated with Candelaria/Ojos at September 30, 2014 (in millions):~~

Current assets $ 449
Long-term assets 1,160
Current liabilities 138
Long-term liabilities 92

~~The following table provides net income before income taxes and net income attributable to FCX associated with Candelaria/Ojos (in millions):~~

Nine Months Ended
September 30,
2014 2013
Net income before income taxes $ 236
$ 391
Net income attributable to FCX 132
199

~~Other.~~ FCX evaluated events after ~~September 30, 2014~~March 31, 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.

3025

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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 ~~September 30, 2014~~March 31, 2015, and the related consolidated statements of operations, comprehensive (loss) income and ~~comprehensive income for the three- and~~ ~~nine-month periods ended~~ ~~September 30, 2014~~ ~~and~~ ~~2013, the consolidated statements of~~ cash flows for the ~~nine-month~~three-month periods ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014, and the consolidated statement of equity for the ~~nine~~three-month period ended ~~September 30, 2014~~March 31, 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, ~~2013~~2014, and the related consolidated statements of ~~income,~~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, ~~2014.~~2015. In our opinion, the accompanying condensed consolidated balance sheet of Freeport-McMoRan Inc. as of December 31, ~~2013~~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

~~November 7, 2014~~May 8, 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, ~~2013~~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 ~~and future results could differ materially from those anticipated in forward-looking statements~~ (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, ~~in the U.S.,~~ including reserves in the Deepwater Gulf of Mexico (GOM), onshore and offshore California, in the Haynesville shale play in Louisiana, in the Madden area in ~~central~~Central Wyoming, and an industry-leading position in the emerging Inboard Lower Tertiary/Cretaceous natural gas trend in the shallow waters of the GOM and onshore in South Louisiana.

~~In November 2014, we completed the sale of our~~ ~~80 percent~~ ~~ownership interests in the Candelaria and Ojos del Salado copper mining operations and supporting infrastructure (Candelaria/Ojos) to Lundin Mining Corporation (Lundin) for~~ ~~$1.8 billion~~ ~~in cash and contingent consideration of up to~~ ~~$0.2 billion. Excluding contingent consideration, after-tax net proceeds from the transaction approximated $1.5 billion. Refer to Note 13 for further discussion.~~

As further discussed in Note 2, we completed the sale of our Eagle Ford shale assets for $3.1 billion (before closing adjustments) in June 2014, and acquired additional interests in the Deepwater GOM totaling $1.4 billion. Refer to "Operations - Oil and Gas" for further discussion.

Our results for ~~third-quarter 2014,~~first-quarter 2015, compared with ~~third-quarter~~first-quarter ~~2013~~2014, reflect lower oil volumes and lower commodity price realizations, ~~for copper, gold and oil,~~ partly offset by higher copper and gold sales volumes. ~~Our results~~Results for ~~the first nine months of~~ ~~2014, compared with the first nine months of~~ ~~2013~~, reflect lower copper volumes and price realizations for copper and gold, partly offset by higher gold sales volumes and a full nine months of results from FCX Oil & Gas Inc. (FM O&G). The third quarter and first nine months of ~~2014~~first-quarter 2015 were also significantly impacted by ~~a ceiling-test~~net charges of $3.1 billion ($2.4 billion to net loss attributable to common stockholders) related to the impairment ~~charge for~~of our oil and gas properties pursuant to full cost accounting rules ~~(refer~~and the related tax charge to ~~Note 1), which was partly offset by net noncash mark-to-market gains on oil and gas derivative contracts.~~establish a deferred tax valuation allowance. Refer to “Consolidated Results” for further discussion of our consolidated financial results for the three~~- and nine-month~~-month periods ended ~~September 30, 2014~~March 31, 2015 and ~~2013~~2014.

At ~~September 30, 2014~~March 31, 2015, we had $~~0.7~~0.5 billion in consolidated cash and cash equivalents and $~~19.7~~20.3 billion in total debt. ~~During third-quarter 2014, we redeemed~~ ~~$1.7 billion~~ aggregate principal amount of senior notes with an average interest rate of 6.6 percent. Additionally, on October 15, 2014, we redeemed the $400 million aggregate principal amount of our 8.625% Senior Notes. We ~~continue~~have taken actions to ~~target significant reductions in debt by the end of 2016 using cash flows generated above~~reduce or defer capital expenditures and other ~~cash requirements~~costs and ~~potentially, net proceeds from asset sales. Refer~~are evaluating funding alternatives to ~~Note~~ 6advance growth projects in our oil and ~~"Capital Resources~~gas business, including consideration of a sale of public equity for a minority interest in our oil and ~~Liquidity"~~gas business. Additional capital cost reductions, potential additional divestitures or monetizations and other actions will be pursued as required to maintain a strong balance sheet while preserving a strong resource position and portfolio of assets with attractive long-term growth prospects. We have a broad set of natural resource assets that provide many alternatives for ~~further discussion.~~future actions to enhance our financial flexibility.

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OUTLOOK

We view the long-term outlook for our business positively, supported by limitations on supplies of copper ~~and oil~~ 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. The outlook for each of these measures follows.

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Sales Volumes. Following are our projected consolidated sales volumes for the year ~~2014~~2015:



Copper (millions of recoverable pounds):
North America copper mines	~~1,670~~1,935
South America mining	~~1,090~~935	^a
Indonesia mining	~~710~~885
Africa mining	~~445~~455
	~~3,915~~4,210
Gold (thousands of recoverable ounces):
~~Indonesia mining~~	~~1,150~~
~~North and South America mining~~	70	^a
	~~1,220~~1,300
Molybdenum (millions of recoverable pounds)	95	^ba
Oil Equivalents (million BOE or MMBOE)	~~56.2~~52.3


a.	~~Excludes estimated fourth-quarter 2014 production from the Candelaria and Ojos del Salado mines (totaling 80 million pounds of copper and 25 thousand ounces of gold).~~


b.	Projected molybdenum sales include 50 million pounds produced by our Molybdenum mines and 45 million pounds produced by our North and South America copper mines.

Consolidated sales for ~~fourth-quarter~~second-quarter ~~2014~~2015 are expected to approximate ~~1.0 billion~~960 million pounds of copper, ~~350~~300 thousand ounces of gold, 2125 million pounds of molybdenum and ~~11.5~~12.9 MMBOE. Projected sales volumes are dependent on a number of factors, including operational performance and other factors. Projected 2015 copper sales are approximately 60 million pounds less than the estimate provided in our annual report on Form 10-K for the year ended December 31, 2014, primarily reflecting reduced mining rates in Indonesia; projected 2015 oil and gas sales are 3.2 MMBOE lower than the estimate provided in our annual report on Form 10-K for the year ended December 31, 2014, primarily reflecting the timing of the Lucius ramp-up and the timing of maintenance activites in the Deepwater GOM. 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 $~~1,250~~1,200 per ounce of gold and $108 per pound of molybdenum for the remainder of ~~fourth-quarter2014~~2015, 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 be lower in the second half of 2015 and average $~~1.52~~1.53 per pound of copper for the year ~~2014~~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 remainder of ~~fourth-quarter2014~~2015 on consolidated unit net cash costs would approximate ~~$0.01~~$0.015 per pound for each $50 per ounce change in the average price of gold and ~~$0.005~~$0.015 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.

Oil and Gas Cash Production Costs per BOE. Based on current sales volume and cost estimates for the remainder of ~~fourth-quarter2014~~2015, oil and gas cash production costs are expected to approximate $2119 per BOE for the year ~~2014~~ ~~and $24 per BOE for fourth-quarter~~ ~~2014~~2015. ~~Fourth-quarter 2014 unit cost estimates reflect downtime for maintenance affecting production rates at Marlin in the Deepwater GOM.~~ 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, ~~our~~ sales volumes, production costs, income taxes, other working capital changes and other factors. Based on current sales volume and cost estimates, and assuming average prices of $~~3.00~~2.75 per pound of copper, $~~1,250~~1,200 per ounce of gold, $108 per pound of molybdenum and $9065 per barrel of Brent crude oil for the remainder of ~~fourth-quarter2014~~2015, consolidated operating cash flows are estimated to approximate $~~5.8~~4.4 billion for the year ~~2014~~2015 ~~(net of~~ ~~$0.4 billion~~ ~~of working capital uses and changes in other tax payments)~~. Projected consolidated operating cash flows for the year ~~2014~~2015 also reflect an estimated ~~taxes~~tax benefit of $~~1.6~~0.4 billion (refer to “Consolidated Results – ~~Provision~~

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~~for~~ Income Taxes” for further discussion of our projected consolidated effective annual tax rate for ~~2014~~2015). The impact of price changes during the remainder of ~~fourth-quarter2014~~2015 on operating cash flows would approximate $90250 million for each $0.10 per pound change in the average price of copper, $1530 million for each $50 per ounce change in the average price of gold, ~~and~~ $1895 million for each $2 per pound change in the average price of ~~molybdenum. For~~molybdenum and $80 million for each $5 per barrel change in the average Brent crude oil a $5 per barrel increase above $90 per barrel in fourth-quarter 2014 would improve 2014 operating cash flows by approximately $20 million. After giving effect to derivative contracts, which provide price protection between approximately $70 and $90 per barrel, a $5 per barrel decrease below $90 per barrel in fourth-quarter 2014 would not reduce 2014 operating cash flows.price.

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MARKETS

Metals. World prices for copper, gold and molybdenum can fluctuate significantly. During the period from January ~~2004~~2005 through ~~September 2014~~April 2015, the London Metal Exchange (LME) spot copper price varied from a low of $~~1.06~~1.26 per pound in ~~2004~~2008 to a record high of $4.60 per pound in ~~2011,~~2011; the London Bullion Market Association (London) PM gold price fluctuated from a low of $~~375~~411 per ounce in ~~2004~~2005 to a record high of $1,895 per ounce in ~~2011,~~2011; and the Metals Week Molybdenum Dealer Oxide weekly average price ranged from a low of $~~7.35~~7.83 per pound in ~~2004~~2009 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, ~~2013~~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 ~~2004~~2005 through ~~October 2014~~April 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 ~~and~~ fiscal policy decisions in Europe, China and the U.S. ~~During the first nine months of~~ ~~2014~~,Since mid-2014, copper prices have declined because of concerns about slowing growth rates in China, a stronger U.S. dollar and ~~an outlook for higher near-term supplies.~~a broad-based decline in commodity prices, led by a sharp decline in oil prices. Copper prices remain under pressure as a result of slowing Chinese economic growth, a strong U.S. dollar and broad-based weakness in commodity prices, but remain supported by supply-side constraints. During first-quarter ~~third-quarter2014~~2015, LME spot copper prices ranged from a low of $~~3.06~~2.45 per pound to a high of $~~3.26~~2.86 per pound, averaged $~~3.17~~2.64 per pound and closed at $~~3.06~~2.74 per pound on ~~September~~March 31, 2015. Since hitting a year-to-date low of $2.45 per pound on January 29, 2015, copper prices have improved. LME spot copper prices closed at $2.83 per pound on April 30, ~~2014~~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.~~environment attributable to difficulty in replacing exiting large mines' output with new production sources. Future copper

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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. ~~LME spot copper prices closed at~~ ~~$3.10~~ ~~per pound on~~ ~~October 31, 2014~~.

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This graph presents London PM gold prices from January ~~2004~~2005 through ~~October 2014~~April 2015. An improving economic outlook and positive equity performance contributed to lower demand for gold in ~~2013~~2014 and ~~the first nine months of 2014,~~early 2015, resulting in generally lower prices. During ~~third-quarter~~first-quarter ~~2014~~2015, London PM gold prices ranged from a low of $~~1,214~~1,147 per ounce to a high of $~~1,340~~1,296 per ounce, averaged $~~1,282~~1,218 per ounce and closed at $~~1,217~~1,187 per ounce on ~~September 30, 2014~~March 31, 2015. Gold prices closed at $~~1,164~~1,180 per ounce on ~~October 31, 2014~~April 30, 2015.

This graph presents the Metals Week Molybdenum Dealer Oxide weekly average prices from January ~~2004~~2005 through ~~October 2014~~April 2015. Molybdenum prices improved during the first ~~nine months~~half of 2014, resulting from improved demand in the metallurgical ~~sector.~~sector, but have since declined because of weaker demand from European steel and stainless steel producers. During ~~third-quarter~~first-quarter ~~2014~~2015, the weekly average price of molybdenum ranged from a low of $~~11.21~~7.62 per pound to a high of $~~13.28~~9.35 per pound, averaged $~~12.77~~8.49 per pound and was $~~11.21~~8.47 on ~~September 30,~~

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~~2014~~March 31, 2015. The Metals Week Molybdenum Dealer Oxide weekly average price was $~~9.38~~7.80 per pound on ~~October 31, 2014~~April 30, 2015.

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Oil and Gas. Market prices for crude oil and natural gas can fluctuate significantly. During the period from January ~~2004~~2005 through ~~October 2014~~April 2015, the Brent crude oil price ranged from a low of $~~28.83~~36.61 per barrel ~~in 2004~~ 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 1A1A. of our annual report on Form 10-K for the year ended December 31, ~~2013~~2014.

This graph presents Brent crude oil prices and NYMEX natural gas contract prices from January ~~2004~~2005 through ~~October 2014~~April 2015. ~~During third-quarter 2014~~Crude oil prices reached a record high in July 2008 as economic growth in emerging economies and ~~through October 2014,~~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 ~~been under pressure from~~significantly declined associated with global oversupply primarily attributable to U.S. shale production and increased Brazilian and Libyan output, coupled with weak economic data in Europe and slowing Chinese demand. During ~~third-quarter 2014,~~first-quarter 2015, Brent crude oil prices ranged from a low of ~~$94.67~~$46.59 per barrel to a high of ~~$112.29~~$62.58 per barrel, averaged ~~$103.50~~$55.19 per barrel and were ~~$94.67~~$55.11 per barrel on ~~September 30, 2014.~~March 31, 2015. The Brent crude oil ~~prices declined during October 2014 and were $85.86~~price was $66.78 per barrel on ~~October 31, 2014.~~April 30, 2015.

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CONSOLIDATED RESULTS


	Three Months Ended						Nine Months Ended						Three Months Ended
	September 30,						September 30,						March 31,
	2014			2013			2014			2013^a			2015				2014^a
SUMMARY FINANCIAL DATA	(in millions, except per share amounts)												(in millions, except per share amounts)
Revenues^b	$	5,696	^c,d	$	6,165	^c,d	$	16,203	^c,d	$	15,036	^c,d	$	4,153		^c,d	$	4,985	^c,d
Operating income^b	$	1,132	^c,d,e,f,g	$	1,707	^c,d,g	$	3,396	^c,d,e,f,g	$	3,701	^c,d,g,h
Net income attributable to common stockholdersⁱ	$	552	^{c,d,e,f,g,j,k}	$	821	^c,d,g	$	1,544	^{c,d,e,f,g,j,k}	$	1,951	^c,d,g,h,j,l
Diluted net income per share attributable to common stockholders	$	0.53	^{c,d,e,f,g,j,k}	$	0.79	^c,d,g	$	1.47	^{c,d,e,f,g,j,k}	$	1.96	^c,d,g,h,j,l
Operating (loss) income^b													$	(2,963	)	^c,d,e,f	$	1,111	^c,d,g
Net (loss) income attributable to common stockholders^h													$	(2,474	)	^c,d,e,f,i	$	510	^c,d,g
Diluted net (loss) income per share attributable to common stockholders													$	(2.38	)	^c,d,e,f,i	$	0.49	^c,d,g
Diluted weighted-average common shares outstanding	1,046			1,043			1,045			993			1,040				1,044
Operating cash flows^m	$	1,926		$	1,878		$	4,513		$	3,743
Operating cash flows^j													$	717			$	1,201
Capital expenditures	$	1,853		$	1,645		$	5,415		$	3,623		$	1,867			$	1,612
At September 30:
At March 31:
Cash and cash equivalents	$	658		$	2,219		$	658		$	2,219		$	549			$	1,342
Total debt, including current portion	$	19,737		$	21,123		$	19,737		$	21,123		$	20,312			$	20,739


a.	Includes the results of ~~FM O&G beginning~~the Candelaria and Ojos del Salado mines that were sold in November 2014, and the Eagle Ford properties that were sold in June ~~1, 2013.~~2014.

b.As further detailed in Note ~~10,~~9, following is a summary of revenues and operating income (loss) by operating division (in millions):


	Three Months Ended						Nine Months Ended						Three Months Ended
	September 30,						September 30,						March 31,
Revenues	2014			2013			2014			2013			2015			2014
North America copper mines	$	1,490		$	1,301		$	4,245		$	3,995		$	1,335		$	1,286
South America mining	847			1,139			2,776			3,104			486			898
Indonesia mining	1,253			1,111			2,246			2,633			607			470
Africa mining	428			420			1,173			1,223			410			327
Molybdenum mines	173			121			469			408			113			126
Rod & Refining	1,227			1,253			3,623			3,862			1,069			1,154
Atlantic Copper Smelting & Refining	601			516			1,823			1,742			546			593
U.S. oil & gas operations	990			1,176			3,487			1,512			500			1,261
Other mining, corporate, other & eliminations	(1,313		)	(872		)	(3,639		)	(3,443		)	(913		)	(1,130		)
Total FCX revenues	$	5,696		$	6,165		$	16,203		$	15,036
Total revenues													$	4,153		$	4,985

Operating income (loss)
North America copper mines	$	471		$	384		$	1,329		$	1,218		$	294		$	390
South America mining	273			558			1,010			1,372			65			333
Indonesia mining	434			404			385			634			73			18
Africa mining	161			163			436			475			99			121
Molybdenum mines	62			18			155			106			4			28
Rod & Refining	5			6			15			20			4			4
Atlantic Copper Smelting & Refining	8			(22		)	(5		)	(30		)	12			(9		)
U.S. oil & gas operations	(150		)	274			359			338			(3,471		)	277
Other mining, corporate, other & eliminations	(132		)	(78		)	(288		)	(432		)	(43		)	(51		)
Total FCX operating income	$	1,132		$	1,707		$	3,396		$	3,701
Total operating (loss) income													$	(2,963	)	$	1,111

Includes ~~(unfavorable) favorable~~unfavorable adjustments to provisionally priced concentrate and cathode copper sales recognized in prior periods totaling $~~(22)~~106 million ($~~(10)~~59 million to net loss attributable to common stockholders or $0.06 per share) for first-quarter2015 and $124 million ($66 million to net income attributable to common stockholders or $~~(0.01)~~0.06 per share) for ~~third-quarter~~first-quarter 2014, ~~$73 million~~ (~~$35 million~~ ~~to net income attributable to common stockholders or~~ ~~$0.03~~ ~~per share) for~~ ~~third-quarter2013~~, ~~$(118) million~~ (~~$(65) million~~ ~~to net income attributable to common stockholders or~~ ~~$(0.06)~~ ~~per share) for the~~ ~~first nine months of2014~~ ~~and~~ ~~$(26) million~~ (~~$(12) million~~ ~~to net income attributable to common stockholders or~~ ~~$(0.01)~~ ~~per share) for the~~ ~~first nine months of2013~~. Refer to “Revenues” for further discussion.

Includes net noncash mark-to-market (losses) gains ~~(losses)~~ associated with crude oil and natural gas derivative contracts totaling ~~$122~~$(48) million ($76(30) million to net ~~income~~loss attributable to common stockholders or ~~$0.07~~$(0.03) per share) for ~~third-quarter 2014, $(158)~~first-quarter 2015 and $15 million ($~~(98)~~9 million to net income attributable to common stock or ~~$(0.09)~~$0.01 per share) for third-quarter 2013, $130 million ($80 million to net income attributable to common stockholders or $0.08 per share) for the first nine months of 2014, and $(194) million ($(120) million to net income attributable to common stock or $(0.12) per share) for the four-month period from June 1, 2013, to September 30, 2013.first-quarter 2014. Refer to "Revenues" for further discussion.

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e.	Includes a charge of ~~$308 million~~$3.1 billion ($~~192 million~~1.9 billion to net ~~income~~loss attributable to common stockholders or ~~$0.18~~$1.87 per share) to reduce the carrying value of oil and gas properties pursuant to full cost accounting rules.


f.	Includes (i) a gain of ~~$46~~$39 million ($3125 million to net loss attributable to common stockholders or $0.02 per share) associated with the $140 million sale of our one-third interest in the Luna Energy power facility in New Mexico and (ii) charges totaling

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$17 million ($10 million to net loss attributable to common stockholders or $0.01 per share) associated with idle/terminated rig costs and inventory write offs at oil and gas operations.


g.	Includes $53 million ($28 million to net income attributable to common stockholders or ~~$0.03~~$0.03 per share) ~~primarily from~~of fixed costs charged directly to cost of sales as a result of the ~~sale~~impact of ~~a metals injection molding plant.~~

Includes net credits (charges) for adjustments to environmental obligations and related litigation reserves of $1 million ($1 million to net income attributable to common stockholders or less than $0.01 per share) for third-quarter export restrictions on PT Freeport Indonesia's (PT-FI) first-quarter2014 $22 million ($14 million to net income attributable to common stockholders or $0.01 per share) for third-quarter 2013, $(68) million ($(67) million to net income attributable to common stockholders or $(0.06) per share) for the first nine months of 2014 and $14 million ($7 million to net income attributable to common stockholders or $0.01 per share) for the first nine months of 2013. operating rates.


h.	~~Includes transaction and related costs totaling $76 million ($47 million to net income attributable to common stock or $0.05 per share) principally associated with oil and gas acquisitions.~~


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


i.	As a result of the impairment to oil and gas properties, we recorded a tax charge of $458 million ($0.44 per share) to establish a valuation allowance primarily against U.S. federal alternative minimum tax credits.

Includes net gains (losses) on early extinguishment of debt totaling $58 million ($17 million to net income attributable to common stockholders or $0.02 per share) in third-quarter 2014 and $63 million ($21 million to net income attributable to common stockholders or $0.02 per share) for the first nine months of 2014 related to the redemption of senior notes and $(45) million ($(36) million to net income attributable to common stockholders or $(0.04) per share) for the first nine months of 2013 related to the termination of the acquisition bridge loan facilities.


k.	Includes a tax charge of $54 million ($47 million net of noncontrolling interests or $0.04 per share) related to changes in Chilean tax rules. Additionally, the first nine months of 2014 include a tax charge of $62 million ($0.06 per share) associated with deferred taxes recorded in connection with the allocation of goodwill to the sale of Eagle Ford properties.

Includes gains associated with the oil and gas acquisitions, including $128 million to net income attributable to common stockholders or $0.13 per share, related to our preferred stock investment in and the subsequent acquisition of McMoRan Exploration Co., and $183 million to net income attributable to common stockholders or $0.18 per share, associated with net reductions in our deferred tax liabilities and deferred tax asset valuation allowances.


m.	Includes net working capital ~~sources (uses)~~uses and changes in other tax payments of $7886 million for ~~third-quarter~~first-quarter ~~2014~~2015, and $~~(294)~~413 million for ~~third-quarter2013~~, ~~$(699) million~~ ~~for the~~ ~~first nine months of~~first-quarter 2014 ~~and~~ ~~$(489) million~~ ~~for the~~ ~~first nine months of2013~~.


	Three Months Ended					Nine Months Ended					Three Months Ended
	September 30,					September 30,					March 31,
	2014			2013		2014			2013^a		2015		2014^a
SUMMARY OPERATING DATA
Copper (recoverable)
Production (millions of pounds)	1,027			1,063		2,906			2,952		915		948
Sales, excluding purchases (millions of pounds)	1,077			1,041		2,916			2,946		960		871
Average realized price per pound	$	3.12		$	3.28	$	3.14		$	3.31	$	2.72	$	3.14
Site production and delivery costs per pound^b	$	1.91		$	1.85	$	1.92	^c	$	1.96	$	1.93	$	1.89	^c
Unit net cash costs per pound^b	$	1.34	^d	$	1.46	$	1.52	^c,d	$	1.62	$	1.64	$	1.54	^c
Gold (recoverable)
Production (thousands of ounces)	449			327		846			713		259		231
Sales, excluding purchases (thousands of ounces)	525			305		871			692		263		187
Average realized price per ounce	$	1,220		$	1,329	$	1,251		$	1,395	$	1,186	$	1,300
Molybdenum (recoverable)
Production (millions of pounds)	24			25		73			71		24		24
Sales, excluding purchases (millions of pounds)	22			23		74			71		23		27
Average realized price per pound	$	14.71		$	11.21	$	13.01		$	12.12	$	10.17	$	11.21
Oil Equivalents
Sales volumes:
Sales volumes
MMBOE	12.5			16.5		44.7			21.5		12.5		16.1
Thousand BOE (MBOE) per day	136			179		164			176		139		179
Cash operating margin per BOE:^e
Cash operating margin per BOE^d
Realized revenues	$	69.08		$	80.93	$	75.04		$	79.40	$	43.71	$	77.22
Cash production costs	20.93			16.80		19.57			16.76		20.26		18.51
Cash operating margin	$	48.15		$	64.13	$	55.47		$	62.64	$	23.45	$	58.71

Includes the results of ~~FM O&G beginning~~the Candelaria and Ojos del Salado mines that were sold in November 2014, and the Eagle Ford properties that were sold in June ~~1, 2013.~~2014. First-quarter 2014 sales volumes included 94 million pounds of copper and 23 thousand ounces of gold from the Candelaria and Ojos del Salado mines and 4.7 MMBOE (53 MBOE per day) from Eagle Ford. Excluding Candelaria and Ojos del Salado, first-quarter 2014 mining unit net cash costs averaged $1.57 per pound of copper; excluding Eagle Ford, first-quarter 2014 oil and gas cash production costs were $20.89 per BOE.

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Reflects per pound weighted-average production and delivery costs and unit net cash costs (net of by-product credits) for all copper ~~mines, excluding net noncash and other costs.~~mines. For reconciliations of ~~the~~ 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.	Excludes ~~$0.05~~$0.06 per pound of copper 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)~~PT-FI's operating rates.


d.	~~Includes $0.06 per pound of copper in third-quarter 2014 and $0.02 per pound of copper for the first nine months of 2014 for export duties and increased royalty rates at PT-FI.~~

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, and cash production costs exclude accretion and other costs.~~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 $~~5.7~~4.2 billion in ~~third-quarter~~first-quarter ~~2014~~ ~~and $16.2 billion for the first nine months of~~ ~~2014~~2015, compared with $~~6.2~~5.0 billion in ~~third-quarter~~first-quarter ~~2013~~ ~~and $15.0 billion for the first nine months of~~ ~~2013~~2014. Revenues ~~included~~include the sale of copper concentrates, copper cathodes, copper rod, gold, molybdenum, silver and

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cobalt ~~hydroxide~~by our mining operations, and ~~beginning June 1, 2013,~~ the sale of oil, natural gas and natural gas liquids (NGLs) by our oil and gas operations.

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


	Three Months Ended September 30,			Nine Months Ended September 30,				Three Months Ended March 31,

Consolidated revenues - 2013 periods	$	6,165		$	15,036
Consolidated revenues - 2014 period								$	4,985
Mining operations:
Higher (lower) sales volumes:
Higher (lower) sales volumes from mining operations:
Copper	119			(100		)		279
Gold	293			250				100
Molybdenum	(9		)	35				(38		)
(Lower) higher price realizations:
Lower price realizations from mining operations:
Copper	(172		)	(496		)		(403		)
Gold	(57		)	(126		)		(29		)
Molybdenum	78			66				(24		)
Unfavorable impact of net adjustments for prior period provisionally priced copper sales	(95		)	(92		)
Net adjustments for prior period provisionally priced copper sales								18
Lower revenues from purchased copper	(189		)	(324		)		(9		)
Lower Atlantic Copper revenues								(47		)
Oil and gas operations:
Lower oil sales volumes	(302		)	—				(320		)
Lower oil price realizations, including realized cash losses on derivative contacts	(136		)	—
Higher oil and gas revenues, including realized cash losses on derivative contracts	—			1,651			^a
Favorable impact of net noncash mark-to-market adjustments on derivative contracts	280			324
Lower oil price realizations, including cash realizations on derivative contacts								(312		)
Net noncash mark-to-market adjustments on derivative contracts								(63		)
Other, including intercompany eliminations	(279		)	(21		)		16
Consolidated revenues - 2014 periods	$	5,696		$	16,203
Consolidated revenues - 2015 period								$	4,153

a. Represents the change in oil and gas revenues, excluding impacts from net noncash mark-to-market adjustments on derivative contracts, for the first nine months of 2014 compared to the four-month period from June 1, 2013, to September 30, 2013.

Mining Sales Volumes

Consolidated ~~copper~~ sales volumes were ~~1.08 billion~~960 million pounds of copper, 263 thousand ounces of gold and 23 million pounds of molybdenum in ~~third-quarter~~first-quarter2015, and 871 million pounds of copper, 187 thousand ounces of gold and 27 million pounds of molybdenum in first-quarter 2014. Higher copper and ~~2.9 billion pounds for the first nine months of~~ ~~2014, compared with~~ ~~1.04 billion~~ ~~pounds in~~ ~~third-quarter2013~~ ~~and 2.9 billion pounds for the first nine months of~~ ~~2013. Consolidated~~ gold sales volumes ~~increased to~~ ~~525 thousand~~ ~~ounces~~primarily reflected higher volumes in ~~third-quarter2014~~North America, Indonesia and ~~871 thousand ounces for~~Africa; partly offset by lower volumes in South America mostly associated with the ~~first nine months~~sale of ~~2014, compared with~~ ~~305 thousand~~ ~~ounces in~~ ~~third-quarter2013~~the Candelaria and ~~692 thousand ounces for the first nine months of~~ ~~2013, primarily reflecting higher ore grades at PT-FI. Consolidated molybdenum sales volumes were~~ ~~22 million~~ ~~pounds in~~ ~~third-quarter2014~~ ~~and 74 million pounds for the first nine months of~~ ~~2014, compared with 23 million pounds in~~ ~~third-quarter2013~~ ~~and 71 million pounds for the first nine months of~~ ~~2013~~.Ojos del Salado mines. Refer to “Operations” for further discussion of sales volumes at our mining operations.

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Metal Price Realizations

Our consolidated revenues can vary significantly as a result of fluctuations in the market prices of copper, gold, molybdenum, silver and ~~molybdenum. Following is a~~cobalt. As presented above on the summary ~~of our average~~operating data table, metals price ~~realizations from mining operations for the~~ ~~third quarters~~ ~~and first nine months of~~ ~~2014~~ ~~and~~ ~~2013~~:

Three Months Ended Nine Months Ended
September 30, September 30,
2014 2013 2014 2013
Copper (per pound) $ 3.12
$ 3.28
$ 3.14
$ 3.31
Gold (per ounce) $ 1,220
$ 1,329
$ 1,251
$ 1,395
Molybdenum (per pound) $ 14.71
$ 11.21
$ 13.01
$ 12.12

~~Copper and gold~~ realizations were lower in ~~third-quarter2014~~ ~~and for the first nine months of~~ ~~2014~~,first-quarter 2015, compared with ~~third-quarter2013~~ ~~and the first nine months of~~ ~~2013. Realized molybdenum prices improved in~~ ~~third-quarter2014~~ ~~and the first nine months of~~ ~~2014, compared with~~ ~~third-quarter2013~~ ~~and the first nine months of~~ ~~2013~~.first-quarter 2014. Refer to ~~"Markets."~~"Markets" for further discussion.

Provisionally Priced Copper Sales

~~During the first nine months of~~For first-quarter ~~2014~~2015, 4339 percent of our mined copper was sold in concentrate, 3136 percent as cathode and 2625 percent as rod from ~~our~~ 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 opposite occurs.

~~Following is a summary of the (unfavorable) favorable~~ The unfavorable impacts of net adjustments to the prior periods' provisionally priced copper sales totaled $106 million for ~~the~~first-quarter ~~third quarters~~2015 and ~~first nine months of~~$124 million for first-quarter 2014 ~~and~~ .~~2013~~ ~~(in millions, except per share amounts):~~

Three Months Ended Nine Months Ended
September 30, September 30,
2014 2013 2014 2013
Revenues $ (22 ) $ 73
$ (118 ) $ (26 )
Net income attributable to common stockholders $ (10 ) $ 35
$ (65 ) $ (12 )
Net income per share attributable to common stockholders $ (0.01 ) $ 0.03
$ (0.06 ) $ (0.01 )

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At ~~September 30, 2014~~March 31, 2015, we had provisionally priced copper sales at our copper mining operations, primarily South America and Indonesia, totaling ~~394~~413 million pounds of copper (net of intercompany sales and noncontrolling interests) recorded at an average of $~~3.03~~2.74 per pound, subject to final pricing over the next several months. We estimate that each $0.05 change in the price realized from the ~~September 30, 2014~~March 31, 2015, provisional price recorded would have an approximate $1314 million ~~impact~~effect on ~~2014~~2015 net income attributable to common stockholders. The LME spot copper price ~~closed at~~was $~~3.10~~2.83 per pound on ~~October 31, 2014~~April 30, 2015.

Purchased Copper

~~From time to time, we purchase~~We purchased copper cathode for processing by our Rod & Refining segment ~~when production from our North America copper mines does not meet customer demand.~~totaling 40 million pounds in first-quarter2015 and 32 million pounds in first-quarter2014.

Oil and Gas Revenues

~~Oil realizations of $88.58 per barrel in~~ ~~third-quarter2014~~ and ~~$93.00 per barrel for the first nine months of~~ ~~2014, were lower compared with $104.33 per barrel for third-quarter~~ ~~2013~~ ~~and $102.76 per barrel for the four-month period from June 1, 2013, to September 30, 2013, primarily reflecting lower oil prices and higher realized cash losses on derivative contracts.~~

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Derivative Contracts

Oil sales volumes ~~were~~ ~~8.6~~of 8.4 million barrels (MMBbls) in ~~third-quarter2014~~, ~~11.5~~first-quarter 2015, were lower than sales volumes of 11.8 MMBbls in ~~third-quarter2013~~, ~~32.1 MMBbls for the first nine months of~~ first-quarter 2014, ~~and 14.9 MMBbls for the four-month period from June 1, 2013, to September 30, 2013. Lower oil sales volumes in~~ ~~third-quarter2014, compared with~~ ~~third-quarter2013~~, primarily ~~reflected~~reflecting the sale of the Eagle Ford ~~properties~~properties. Lower oil realizations, including realized cash gains on derivative contracts, of $56.51 per barrel in ~~June 2014.~~

first-quarter2015, compared with $93.76 per barrel for first-quarter 2014, primarily reflected lower oil prices. Refer to “Operations” for further discussion of average realizations and sales volumes at our oil and gas operations.

In connection with the acquisition of ~~Plains Exploration & Production Company (PXP),~~our oil and gas business, we have derivative contracts for ~~2014~~2015 consisting of crude oil options, and ~~2015~~for 2014, had derivative contracts that ~~consist~~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. ~~Following is a summary of the net noncash mark-to-market~~Realized cash gains (losses) on crude oil and natural gas derivative contracts totaled $100 million for ~~the third quarters~~first-quarter2015 and ~~first nine months of~~$(65) million for first-quarter2014. Net noncash mark-to-market (losses) gains on crude oil and natural gas derivative contracts totaled $(48) million for first-quarter 2015 and $15 million for first-quarter 2014 ~~and~~.

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 ~~2013~~March 31, 2015, fair values (in ~~millions, except per share amounts)~~millions):

Three Months Ended Nine Months Ended
September 30, September 30,
2014 2013 2014
2013^a
Revenues $ 122
$ (158 ) $ 130
$ (194 )
Net income attributable to common stockholders $ 76
$ (98 ) $ 80
$ (120 )
Net income per share attributable to common stockholders $ 0.07
$ (0.09 ) $ 0.08
$ (0.12 )



	10% Increase			10% Decrease
Crude oil options	$	(31	)	$	19


a.	~~Reflects the four month period from June 1, 2013, to September 30, 2013.~~

Refer to Note 76 for further discussion of oil and natural gas derivative contracts.

Production and Delivery Costs

Consolidated production and delivery costs totaled $~~3.2~~2.9 billion in ~~third-quarter~~first-quarter ~~2014~~ ~~and $9.0 billion for the first nine months of~~ ~~2014~~2015, compared with ~~$3.3~~$2.7 billion in ~~third-quarter~~first-quarter ~~2013~~ ~~and $8.9 billion for the first nine months of~~ ~~2013~~2014. Higher production and delivery costs for ~~first nine months of 2014~~first-quarter 2015 were primarily associated with higher costs at our ~~oil~~mining operations mostly related to higher volumes in North America and ~~gas operations, which included a full nine months of results for 2014,~~Indonesia; partly offset by lower costs in South America mostly resulting from the sale of ~~cathode purchases in North America~~the Candelaria and ~~lower costs in Indonesia associated with lower volumes.~~Ojos del Salado mines.

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 oftotaled $~~1.91~~1.93 per pound of copper in ~~third-quarter~~first-quarter2015 and $1.89 per pound in first-quarter 2014 ~~were higher than~~. Higher consolidated ~~unit~~average site production and delivery costs of ~~$1.85~~ ~~per pound~~ in ~~third-quarter2013~~,first-quarter 2015, compared with first-quarter 2014, primarily ~~reflecting the impact of lower production rates at PT-FI~~reflected higher costs and lower ~~copper~~ sales volumes in South America, partly offset by higher copper sales volumes in North ~~America.~~

~~Consolidated unit site production~~America and ~~delivery costs (before net noncash and other costs) for our copper mines of $1.92 per pound for the first nine months of~~ ~~2014~~ ~~were lower than $1.96 per pound for the first nine months of~~ ~~2013~~, primarily reflecting higher copper sales volumes in North America, partly offset by the impact of lower production rates at PT-FI. Additionally, consolidated unit site production and delivery costs for the first nine months of ~~2014~~ ~~exclude fixed costs charged directly to cost of sales as a result of the impact of export restrictions on PT-FI's operating rates totaling $0.05 per pound of copper.~~Indonesia.

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 $~~1.91~~1.81 per pound of copper for the year ~~2014~~2015. 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.

Our mining operations require significant energy, principally diesel, electricity, coal and natural gas, most of which is obtained from third parties under long-term contracts. Energy costs are expected to approximate 20 percent of our consolidated copper production costs for the year ~~2014~~, including purchases of approximately 260 million gallons of diesel fuel; 8,000 gigawatt hours of electricity at our North America, South America and Africa copper mining operations (we generate all of our power at our Indonesia mining operation); 650 thousand metric tons of coal for our coal power plant in Indonesia; and 1 MMBtu of natural gas at certain of our North America mines.

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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 ~~$20.93~~$20.26 per BOE in ~~third-quarter~~first-quarter ~~2014~~2015 ~~and$19.57 for the first nine months of~~ ~~2014~~, were higher than the ~~$16.80~~$18.51 per BOE in ~~third-quarter~~first-quarter ~~2013~~2014 ~~and $16.76 for the four months from June 1, 2013, to September 30, 2013,~~, primarily reflecting the sale of ~~lower cost~~lower-cost Eagle Ford ~~properties in June 2014 and higher operating costs in California.~~properties.

Assuming achievement of current volume and cost estimates for ~~fourth-quarter 2014,~~the remainder of 2015, cash production costs are expected to approximate ~~$21~~$19 per BOE for the year ~~2014 and $24 per BOE for fourth-quarter 2014. Fourth-quarter 2014 unit cost estimates reflect downtime for maintenance affecting production rates at Marlin in the Deepwater GOM.~~

2015. Refer to “Operations” for further discussion of cash production costs at our oil and gas operations.

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 $~~0.9 billion~~939 million in ~~both the third quarters of 2014 and 2013, $2.9 billion for~~first-quarter ~~the first nine months of~~ ~~2014~~2015 and ~~$1.8 billion for the first nine months of~~$966 million in ~~2013~~first-quarter2014. ~~Higher depreciation, depletion and amortization~~DD&A in ~~the first nine months of~~ first-quarter2015, compared with first-quarter2014 ~~was primarily associated with a full nine months of~~, reflected lower expense ~~for~~from our ~~acquired~~ oil and gas operations associated with decreased production as a result of the sale of the Eagle Ford properties, offset by higher DD&A from our mining operations mostly associated with higher sales volumes in ~~2014, compared with the four months in 2013.~~North America and Indonesia.

Impairment of Oil and Gas Properties

Under the full cost accounting rules, a "ceiling test" is conducted each quarter to review the carrying value of the oil and gas properties for impairment. At ~~September 30, 2014, the~~March 31, 2015, net capitalized costs with respect to FMFCX Oil & Gas Inc.'s (FM O~~&G's~~&G) proved U.S. oil and gas properties exceeded the related ceiling limitation, which resulted in the recognition of an impairment charge of ~~$308 million~~$3.1 billion ($~~192 million~~1.9 billion to net ~~income~~loss attributable to common stockholders) for first-quarter2015, reflecting ~~higher capitalized costs and~~ the lower twelve-month average of the first-day-of-the-month historical reference oil price and higher capitalized costs at ~~September 30, 2014.~~March 31, 2015. Refer to Note 1 and "Operations - Oil and Gas" for further discussion.

Selling, General and Administrative Expenses

Consolidated selling, general and administrative expenses totaled $~~158~~154 million in ~~both the third quarters of~~first-quarter2015 and $135 millionin first-quarter 2014 ~~and~~ ~~2013, and $457~~. Adjustments to reduce accrued incentive compensation amounts were $21 million ~~for both the first nine months of~~ ~~2014~~ ~~and~~ ~~2013. Excluding amounts for our oil and gas operations, which totaled $171 million for the first nine months of~~ ~~2014~~ ~~and $65 million for the four months from June 1, 2013, to September 30, 2013, selling, general and administrative expenses were lower~~higher in ~~the first nine months of~~ first-quarter 2014,~~, primarily because of transaction costs incurred during 2013 associated~~ compared with ~~the oil and gas acquisitions.~~first-quarter 2015. Consolidated selling, general and administrative expenses were net of capitalized general and administrative expense at our oil and gas operations totaling ~~$37~~$32 million in ~~third-quarter~~first-quarter2015 and $34 million in first-quarter 2014~~, $27 million in~~ ~~third-quarter2013, $111 million for the first nine months of~~ ~~2014~~ ~~and $35 million for the four months from June 1, 2013, to September 30, 2013.~~.

Mining Exploration and Research Expenses

Consolidated exploration and research expenses for our mining operations ~~decreased to~~totaled $2933 million in ~~third-quarter~~first-quarter ~~2014~~2015 and ~~$93 million for the first nine months of~~ ~~2014, compared with~~ $5730 million in ~~third-quarter~~first-quarter ~~2013~~ ~~and $173 million for the first nine months of~~ ~~2013~~2014. WeOur exploration activities are ~~actively conducting exploration activities~~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 ~~continue to indicate~~indicates the potential for significantly expanded sulfide production. Drilling results and exploration modeling in North America have identified ~~large scale~~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 ~~2014~~2015, mining exploration ~~and research~~ expenditures are expected to ~~approximate~~ ~~$130 million, including~~total approximately $100 million. As further discussed in Note 1 of our annual report on Form 10-K for ~~mining exploration.~~

~~Under~~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.

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Environmental Obligations and Shutdown Costs

Environmental obligation costs reflect net revisions to our long-term environmental obligations, which will 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 ~~(credits)~~ for environmental obligations and shutdown costs totaled $1813 million in ~~third-quarter~~first-quarter ~~2014~~2015 and ~~$100 million for the first nine months of~~ ~~2014, compared with~~ $~~(8)~~6 million in ~~third-quarter~~first-quarter ~~2013~~ ~~and $23 million for the first nine months of~~ ~~2013~~2014. Refer to "Contingencies" for further discussion of environmental obligations and litigation matters associated with closed facilities or operations.

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Net Gain on ~~Sales~~Sale of Assets

Net gain on ~~sales~~sale of assets totaled ~~$46~~$39 million ($3125 million to net income attributable to common stockholders) for ~~the third quarter and first nine months of 2014,~~first-quarter2015, primarily related to the $140 million sale of ~~a metals injection molding plant.~~our one-third interest in the Luna Energy power facility in New Mexico.

Interest Expense, Net

Consolidated interest expense (excluding capitalized interest) totaled $~~212~~210 million in ~~third-quarter~~first-quarter ~~2014~~2015~~, $661 million for the first nine months of~~ ~~2014~~, and $~~223~~224 million in ~~third-quarter~~first-quarter ~~2013~~ ~~and $465 million for the first nine months of~~ ~~2013~~2014. ~~Increased interest expense for the first nine months of 2014 was primarily associated with acquisition-related debt and assumed debt of PXP.~~

Capitalized interest is related to the level of expenditures for our development projects and average interest rates on our borrowings, and totaled $5464 million in ~~third-quarter~~first-quarter ~~2014~~2015 and ~~$178 million for the first nine months of~~ ~~2014, compared with~~ $6163 million in ~~third-quarter~~first-quarter ~~2013~~ ~~and $114 million for the first nine months of~~ ~~2013~~2014. Refer to "Operations" and “Capital Resources and Liquidity - Investing Activities” for further discussion of current development projects.

~~Net Gain (Loss) on Early Extinguishment of Debt~~

~~Net gain (loss) on early extinguishment of debt totaled $58 millionin the third quarter and $63 millionfor thefirst nine months of2014, primarily related to the redemption of senior notes and~~ ~~$(45) million~~ ~~for the~~ ~~first nine months of2013~~ ~~related to the termination of the bridge loan facilities for the oil and gas acquisitions.~~

~~Gain on Investment in McMoRan Exploration Co. (MMR)~~

~~During the~~ ~~first nine months of2013~~, we recorded a gain totaling $128 million related to the carrying value of our preferred stock investment in and the subsequent acquisition of MMR. Refer to Note 2 in our annual report on Form 10-K for the year ended December 31, 2013.

~~Provision for~~ Income Taxes

Following is a summary of the approximate amounts used in the calculation of our consolidated ~~provision for~~ income ~~taxes~~tax benefit (provision) for the first ~~nine months~~quarters of ~~2014~~2015 and ~~2013~~2014 (in millions, except percentages):


	Nine Months Ended								Nine Months Ended							Three Months Ended									Three Months Ended
	September 30, 2014								September 30, 2013							March 31, 2015									March 31, 2014
	Income^a		Effective Tax Rate		Income Tax Provision				Income^a		Effective Tax Rate	Income Tax (Provision) Benefit				Income(Loss)^a			Effective Tax Rate		Income Tax (Provision) Benefit				Income^a		Effective Tax Rate	Income Tax Provision
U.S.	$	1,165	28%		$	(321	)	^b	$	1,007	26%	$	(259	)		$	(302	)	42%		$	126			$	473	29%	$	(136	)
South America	1,014		40%		(409		)	^c	1,325		36%	(472		)		60			40%		(24		)		344		37%	(127		)
Indonesia	397		42%		(166		)		622		46%	(289		)		61			47%		(29		)		44		42%	(18		)
Africa	305		30%		(93		)		320		31%	(99		)		55			47%		(26		)		80		30%	(24		)
Impairment of oil and gas properties																(3,104		)	37%		1,163				—		N/A	—
Valuation allowance																—			N/A		(458		)	^b	—		N/A	—
Eliminations and other	143		N/A		(14		)		172		N/A	(31		)		128			N/A		(27		)		42		N/A	(11		)
Annualized rate adjustment^d	—		N/A		(31		)		—		N/A	—
	3,024		34%		(1,034		)		3,446		33%	(1,150		)
Adjustments	—		N/A		—				—		N/A	183			^e
Annualized rate adjustment^c																—			N/A		(30		)		—		N/A	(41		)
Consolidated FCX	$	3,024	34%	^f	$	(1,034	)		$	3,446	28%	$	(967	)		$	(3,102	)	22%	^d	$	695			$	983	36%	$	(357	)


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


b.	~~Includes~~As a ~~$62 million~~result of the impairment to oil and gas properties, we recorded a tax charge ~~for deferred taxes recorded in connection with the allocation of goodwill~~ to ~~the sale of Eagle Ford properties.~~

~~Table of Contents~~


c.	~~Includes~~establish a ~~$54 million charge related to changes in Chilean~~valuation allowance primarily against U.S. federal alternative minimum tax ~~rules.~~credits.


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


e.	~~Reflects net reductions in our deferred tax liabilities and deferred tax asset valuation allowances resulting from the oil and gas acquisitions.~~

f.d.

Our consolidated effective income tax rate is a function of the combined effective tax rates for the jurisdictions in which we ~~conduct operations.~~operate. Accordingly, variations in the relative proportions of jurisdictional income result in fluctuations to our consolidated effective income tax rate. Assuming ~~average prices of~~ ~~$3.00~~ ~~per pound for copper,~~ ~~$1,250~~ ~~per ounce for gold,~~ ~~$10~~ ~~per pound for molybdenum and Brent crude oil of~~ ~~$90~~ ~~per barrel for fourth-quarter~~ ~~2014~~ ~~and~~ achievement of current sales volume and cost estimates and average prices of $2.75 per pound for copper, $1,200 per ounce for gold, $8 per pound for molybdenum and $65 per barrel of Brent crude oil for the remainder of 2015, we estimate that our consolidated effective tax rate will approximate 3423 percent for the year ~~2014~~2015.

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 ~~copper~~ smelter). Molybdenum concentrate isand silver are also produced by certain of our North America copper mines.

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Operating and Development Activities. We have increased production from our North America copper mines by approximately 2550 percent over the past five years and continue to evaluate a number of opportunities to ~~invest in additional~~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 ~~is expected to reach~~approached full rates ~~by year-end 2014.~~in first-quarter 2015. The project ~~targets average incremental annual production of approximately 225 million pounds of copper (an approximate 40 percent increase from 2013) through an increase in milling rates~~expanded mill capacity from 50,000 metric tons of ore per day to approximately 115,000 metric tons of ore per ~~day. During third-quarter 2014, Morenci's mill rates averaged 77,900 metric tons per day. At full rates,~~day and is expected to add 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.

~~Construction of the expanded Morenci milling facility is substantially complete. Remaining items include completion of~~ Additionally, the molybdenum circuit ~~which would add~~began production in first-quarter 2015 and is expected to reach design capacity of approximately 9 million pounds of molybdenum per year ~~and~~in second-quarter 2015. Remaining items associated with the project include construction of anthe expanded tailings storage facility, which is expected to be completed in third-quarter 2015. ~~As of~~ ~~September 30, 2014~~, ~~$1.5 billion~~ ~~had been incurred for this project ($0.5 billion during the first nine months of 2014), with approximately $0.1 billion remaining to be incurred.~~

~~Table of Contents~~

Operating Data. Following is summary operating data for the North America copper mines for the ~~third~~first quarters ~~and first nine months~~ of ~~2014~~2015 and ~~2013~~2014:


	Three Months Ended				Nine Months Ended				Three Months Ended
	September 30,				September 30,				March 31,
	2014		2013		2014		2013		2015		2014
Operating Data, Net of Joint Venture Interest
Copper (recoverable)
Production (millions of pounds)	423		354		1,203		1,046		452		385
Sales, excluding purchases (millions of pounds)	436		363		1,230		1,088
Sales (millions of pounds)									472		371
Average realized price per pound	$	3.17	$	3.27	$	3.19	$	3.37	$	2.73	$	3.24

Molybdenum (millions of recoverable pounds)
Production^a	8		9		25		26
Molybdenum (recoverable)
Production(millions of pounds)^a									9		8

100% Operating Data
SX/EW operations
Leach ore placed in stockpiles (metric tons per day)	1,003,900		993,100		1,010,600		1,015,400		915,100		983,100
Average copper ore grade (percent)	0.25		0.22		0.25		0.22		0.25		0.24
Copper production (millions of recoverable pounds)	244		216		707		651		247		229

Mill operations
Ore milled (metric tons per day)	278,000		247,400		264,500		246,300		301,500		255,300
Average ore grade (percent):
Copper	0.44		0.38		0.43		0.39		0.48		0.42
Molybdenum	0.03		0.03		0.03		0.03		0.03		0.03
Copper recovery rate (percent)	87.5		86.3		85.5		84.6		85.4		86.1
Copper production (millions of recoverable pounds)	211		163		581		469		241		182


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

Copper sales volumes from our North America copper mines increased to ~~436~~472 million pounds in ~~third-quarter~~first-quarter ~~2014~~ ~~and 1.2 billion pounds for the first nine months of~~ ~~2014~~2015, compared with ~~363~~371 million pounds in ~~third-quarter~~first-quarter ~~2013~~ ~~and 1.1 billion pounds for the first nine months of~~ ~~2013~~2014, primarily reflecting higher ~~mining~~milling rates and ~~milling rates~~ore grades at Morenci and higher ore grades at Chino.

Copper sales from North America are expected to approximate ~~1.7~~1.94 billion pounds for the year ~~2014~~2015, compared with ~~1.4~~1.66 billion pounds in ~~2013~~2014. North America copper production is expected to continue to increase for the year 2015 as a result of higher mill rates from the Morenci expansion. Refer to "Outlook" for projected molybdenum sales volumes.

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.

~~Table of Contents~~

Gross Profit per Pound of Copper and Molybdenum

The following ~~tables summarize~~table summarizes unit net cash costs and gross profit per pound at our North America copper mines for the ~~third~~first quarters ~~and first nine months~~ of ~~2014~~2015 and ~~2013~~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
September 30, 2014 September 30, 2013
By- Product Method Co-Product Method By- Product Method Co-Product Method
Copper
Molyb-
denum^a
Copper
Molyb-
denum^a

Revenues, excluding adjustments $ 3.17
$ 3.17
$ 13.55
$ 3.27
$ 3.27
$ 10.24

Site production and delivery, before net noncash and other costs shown below 1.83
1.79
3.17
2.00
1.94
4.01

By-product credits (0.26 ) —
—
(0.24 ) —
—

Treatment charges 0.11
0.11
—
0.10
0.09
—

Unit net cash costs 1.68
1.90
3.17
1.86
2.03
4.01

Depreciation, depletion and amortization 0.30
0.30
0.17
0.27
0.27
0.24

Noncash and other costs, net 0.11
0.10
0.03
0.08
0.07
0.03

Total unit costs 2.09
2.30
3.37
2.21
2.37
4.28

Revenue adjustments, primarily for pricing on prior period open sales (0.02 ) (0.02 ) —
0.02
0.02
—

Gross profit per pound $ 1.06
$ 0.85
$ 10.18
$ 1.08
$ 0.92
$ 5.96

Copper sales (millions of recoverable pounds) 434
434
362
362

Molybdenum sales (millions of recoverable pounds)^a
8
9



	Nine Months Ended								Nine Months Ended											Three Months Ended											Three Months Ended
	September 30, 2014								September 30, 2013											March 31, 2015											March 31, 2014
	By- Product Method			Co-Product Method					By- Product Method				Co-Product Method							By- Product Method				Co-Product Method							By- Product Method				Co-Product Method
				Copper			Molyb- denum^a					Copper				Molyb- denum^a							Copper				Molyb- denum^a							Copper				Molyb- denum^a
Revenues, excluding adjustments	$	3.19		$	3.19		$	11.93		$	3.37			$	3.37			$	11.03		$	2.73			$	2.73			$	8.81		$	3.24			$	3.24			$	10.17

Site production and delivery, before net noncash and other costs shown below	1.86			1.83			2.75		2.03				1.97				3.99			1.81				1.70				6.25			1.88				1.78				6.14
By-product credits	(0.25		)	—			—		(0.25		)		—				—			(0.18		)		—				—			(0.22		)		—				—
Treatment charges	0.11			0.11			—		0.10				0.10				—			0.13				0.13				—			0.13				0.12				—
Unit net cash costs	1.72			1.94			2.75		1.88				2.07				3.99			1.76				1.83				6.25			1.79				1.90				6.14
Depreciation, depletion and amortization	0.29			0.29			0.15		0.28				0.27				0.25			0.28				0.27				0.63			0.29				0.27				0.53
Noncash and other costs, net	0.09			0.08			0.03		0.08				0.08				0.03			0.07				0.06				0.05			0.08				0.08				0.02
Total unit costs	2.10			2.31			2.93		2.24				2.42				4.27			2.11				2.16				6.93			2.16				2.25				6.69
Revenue adjustments, primarily for pricing on prior period open sales	(0.01		)	(0.01		)	—		—				—				—			(0.06		)		(0.06		)		—			(0.02		)		(0.02		)		—
Gross profit per pound	$	1.08		$	0.87		$	9.00	$	1.13			$	0.95			$	6.76		$	0.56			$	0.51			$	1.88		$	1.06			$	0.97			$	3.48

Copper sales (millions of recoverable pounds)	1,224			1,224					1,084				1,084							471				471							369				369
Molybdenum sales (millions of recoverable pounds)^a							25										26											9											8


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

~~Table of Contents~~

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 $~~1.68~~1.76 per pound of copper in ~~third-quarter~~first-quarter ~~2014~~ ~~and $1.72 per pound for the first nine months of~~ ~~2014~~2015 were lower than unit net cash costs of $~~1.86~~1.79 per pound in ~~third-quarter~~first-quarter ~~2013~~ ~~and $1.88 per pound for the first nine months of~~ ~~2013~~2014, primarily reflecting 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 $108 per pound of molybdenum for ~~fourth-quarter~~the remainder of ~~2014~~2015, average unit net cash costs (net of by-product credits) for our North America copper mines are expected to approximate $~~1.73~~1.71 per pound of copper for the year ~~2014~~2015, compared with $~~1.87~~1.73 per pound in ~~2013~~2014. North America's unit net cash costs for ~~fourth-quarter 2014~~the remainder 2015 would change by approximately ~~$0.007~~$0.03 per pound for each $2 per pound change in the average price of molybdenum.

South America Mining

We operate ~~four~~two copper mines in South America – Cerro Verde in Peru ~~and El Abra, Candelaria and Ojos del Salado in Chile. We~~(in which we own a 53.56 percent ~~interest~~interest) and El Abra in ~~Cerro Verde,~~Chile (in which we own a 51 percent ~~interest in El Abra, and an 80 percent interest in the Candelaria and Ojos del Salado mining complex.~~interest). All operations in South America are consolidated in our financial statements.

South America mining includes open-pit ~~and underground~~ 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 ~~Candelaria and Ojos del Salado mines produce gold and silver, and the~~ Cerro Verde mine produces molybdenum ~~concentrates.~~concentrates and silver.

~~Sale Transaction.~~ ~~In November 2014, we completed the sale~~

Table of our 80 percent ownership interests in Candelaria/Ojos to Lundin for $1.8 billion in cash and contingent consideration of up to $0.2 billion. Contingent consideration is calculated as five percent of net copper revenues in any annual period over the next five years when the average copper price exceeds $4.00 per pound. Excluding contingent consideration, we estimate after-tax net proceeds from the transaction of approximately $1.5 billion.Contents

As of December 31, 2013, we estimated that Candelaria and Ojos del Salado had consolidated recoverable proven and probable reserves totaling 4.0 billion pounds of copper and 1.1 million ounces of gold, determined using a long-term average price of $2.00 per pound for copper and $1,000 per ounce for gold. Consolidated production for the first nine months of 2014 totaled 246 million pounds of copper and 62 thousand ounces of gold.

~~The transaction has an effective date of June 30, 2014. We expect to record an after-tax net gain of approximately $450 million related to the transaction. Refer to Note 13 for further discussion.~~

Development Activities.

Cerro Verde Expansion. Construction activities associated with a large-scale expansion at Cerro Verde are advancing toward completion in ~~progress.~~late 2015. Detailed engineering and major procurement activities are complete and construction ~~progress~~ is ~~approaching 40~~approximately 70 percent ~~completion.~~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 ~~September 30, 2014, $2.7~~March 31, 2015, $3.5 billion had been incurred for this project ($~~1.2~~0.4 billion during ~~the first nine months of 2014)~~first-quarter 2015), with approximately ~~$1.9~~$1.1 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 ~~be dependent~~depend on technical studies, economic factors and global copper market conditions.

~~Table of Contents~~

Operating Data. Following is summary operating data for our South America mining operations for the ~~third~~first quarters ~~and first nine months~~ of ~~2014~~2015 and ~~2013~~2014:


	Three Months Ended				Nine Months Ended				Three Months Ended
	September 30,				September 30,				March 31,
	2014		2013		2014		2013		2015		2014^a
Copper (recoverable)
Production (millions of pounds)	284		347		898		944		193		314
Sales (millions of pounds)	271		323		888		923		200		307
Average realized price per pound	$	3.10	$	3.30	$	3.12	$	3.30	$	2.71	$	3.07

Gold (recoverable)
Production (thousands of ounces)	20		30		62		70		—		21
Sales (thousands of ounces)	16		26		59		68		—		23
Average realized price per ounce	$	1,234	$	1,335	$	1,280	$	1,415	$	—	$	1,307

Molybdenum (millions of recoverable pounds)
Production^a	3		4		8		8
Production^b									2		3

SX/EW operations
Leach ore placed in stockpiles (metric tons per day)	269,600		287,500		279,300		276,600		233,600		286,700
Average copper ore grade (percent)	0.50		0.48		0.50		0.49		0.41		0.50
Copper production (millions of recoverable pounds)	122		110		370		329		114		123

Mill operations
Ore milled (metric tons per day)	192,100		189,900		187,700		191,000		119,300		188,700
Average ore grade:
Copper (percent)	0.50		0.71		0.55		0.62		0.44		0.59
Molybdenum (percent)									0.02		0.02
Gold (grams per metric ton)	0.09		0.14		0.10		0.11		—		0.10
Molybdenum (percent)	0.02		0.03		0.02		0.02
Copper recovery rate (percent)	86.9		90.5		88.6		90.4		79.6		90.0
Copper production (millions of recoverable pounds)	162		237		528		615		79		191


a.	Includes the results of the Candelaria and Ojos del Salado mines, which had sales totaling 94 million pounds of copper and 23 thousand ounces of gold in first-quarter 2014.


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

Consolidated copper sales volumes from South America of ~~271~~200 million pounds in ~~third-quarter~~first-quarter ~~2014~~ ~~and 888 million pounds for the first nine months of~~ ~~2014~~2015 were lower than ~~third-quarter 2013~~first-quarter2014 sales of ~~323~~307 million pounds, reflecting the sale of the Candelaria and ~~923 million pounds for the first nine months of~~ ~~2013, primarily reflecting anticipated~~Ojos del Salado mines and lower production from Cerro Verde associated with lower ore grades ~~at Candelaria~~ and ~~Cerro Verde.~~recovery rates from stockpile material.

~~Sales~~For the year 2015, consolidated sales volumes from South America ~~mining~~mines are expected to approximate ~~1.1 billion~~935 million pounds of copper, ~~for the year~~ ~~2014~~ ~~and exclude estimated fourth-quarter~~compared with 1.14 billion pounds in 2014, ~~production~~which included copper sales volumes of 268 million pounds from the Candelaria and Ojos del Salado ~~mines (totaling approximately 80 million pounds~~mines.

Table of ~~copper) because of the pending sale transaction. Refer to "Outlook" for projected gold and molybdenum sales volumes.~~Contents

~~Table of Contents~~

Gross Profit per Pound of Copper

The following ~~tables summarize~~table summarizes unit net cash costs and gross profit per pound of copper at the South America mining operations for the ~~third~~first quarters ~~and first nine months~~ of ~~2014~~2015 and ~~2013~~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					Three Months Ended						Three Months Ended
	September 30, 2014						September 30, 2013					March 31, 2015						March 31, 2014
	By-Product Method			Co-Product Method			By-Product Method			Co-Product Method		By-Product Method			Co-Product Method			By-Product Method				Co-Product Method
Revenues, excluding adjustments	$	3.10		$	3.10		$	3.30		$	3.30	$	2.71		$	2.71		$	3.07			$	3.07

Site production and delivery, before net noncash and other costs shown below	1.67			1.53			1.49			1.40		1.75			1.69			1.50				1.39
By-product credits	(0.23		)	—			(0.22		)	—		(0.08		)	—			(0.25		)		—
Treatment charges	0.16			0.16			0.16			0.16		0.17			0.17			0.17				0.17
Unit net cash costs	1.60			1.69			1.43			1.56		1.84			1.86			1.42			^a	1.56
Depreciation, depletion and amortization	0.37			0.35			0.26			0.25		0.38			0.36			0.28				0.27
Noncash and other costs, net	0.07			0.07			0.05			0.02		0.02			0.03			0.06				0.06
Total unit costs	2.04			2.11			1.74			1.83		2.24			2.25			1.76				1.89
Revenue adjustments, primarily for pricing on prior period open sales	(0.06		)	(0.06		)	0.15			0.15		(0.15		)	(0.15		)	(0.24		)		(0.24		)
Gross profit per pound	$	1.00		$	0.93		$	1.71		$	1.62	$	0.32		$	0.31		$	1.07			$	0.94

Copper sales (millions of recoverable pounds)	271			271			323			323		200			200			307				307


a.	Excluding the results of Candelaria and Ojos del Salado, South America mining's first-quarter 2014 unit net cash costs averaged $1.47 per pound.

Nine Months Ended Nine Months Ended
September 30, 2014 September 30, 2013

By-Product
Method

Co-Product
Method

By-Product
Method

Co-Product
Method
Revenues, excluding adjustments $ 3.12
$ 3.12
$ 3.30
$ 3.30

Site production and delivery, before net noncash and other costs shown below 1.61
1.48
1.57
1.46
By-product credits (0.24 ) —
(0.25 ) —
Treatment charges 0.17
0.17
0.17
0.17
Unit net cash costs 1.54
1.65
1.49
1.63
Depreciation, depletion and amortization 0.32
0.30
0.26
0.24
Noncash and other costs, net 0.06
0.08
0.04
0.01
Total unit costs 1.92
2.03
1.79
1.88
Revenue adjustments, primarily for pricing on prior period open sales (0.07 ) (0.07 ) (0.04 ) (0.04 )
Gross profit per pound $ 1.13
$ 1.02
$ 1.47
$ 1.38

Copper sales (millions of recoverable pounds) 888
888
923
923

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 $~~1.60~~1.84 per pound of copper in ~~third-quarter~~first-quarter ~~2014~~2015 ~~and $1.54 per pound for the first nine months of~~ ~~2014~~, were higher than unit net cash costs of $~~1.43~~1.42 per pound in ~~third-quarter~~first-quarter ~~2013~~ ~~and $1.49 per pound for the first nine months of~~ ~~2013~~2014, primarily reflecting lower sales ~~volumes.~~volumes and higher mining costs at Cerro Verde mostly associated with increased repair and maintenance expense. In addition, first-quarter 2015 reflected lower by-product credits primarily because of the sale of the Candelaria mine.

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.

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.

~~Table of Contents~~

Assuming achievement of current sales volume and cost estimates, and average prices of $~~1,250~~ ~~per ounce of gold and~~ ~~$10~~8 per pound of molybdenum for ~~fourth-quarter~~the remainder of ~~2014~~2015, we estimate that average unit net cash costs (net of by-product credits) for our South America mining operations would approximate $~~1.56~~1.72 per pound of copper for the year ~~2014~~2015, compared with $~~1.43~~1.58 per pound in ~~2013~~2014.

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Indonesia Mining

Indonesia mining includes PT-FI’s Grasberg minerals ~~district.~~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 ~~operates a proportionately consolidated joint venture, which~~ 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, of which approximately one-half is sold to PT Smelting and Atlantic Copper, ~~and PT Smelting~~ and the remainder to third-party customers.

~~We have established certain~~PT-FI proportionately consolidates an unincorporated joint ~~ventures~~venture with Rio Tinto plc (Rio Tinto), under which Rio Tinto has a 40 percent interest in certain assets and ~~future~~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, ~~2013~~2014, for discussion of our joint ~~ventures~~venture with Rio Tinto.

Refer to "Risk Factors" contained in Part ~~II, Item 1A of this quarterly report and in Part~~ I, Item 1A1A. of our annual report on Form 10-K for the year ended December 31, ~~2013~~2014, for discussions of risks associated with operations in Indonesia.

Regulatory Matters. ~~On July 25, 2014,~~ PT-FI is engaged in active discussions with the Indonesian government regarding its Contract of Work (COW) and long-term operating rights. The parties entered into a Memorandum of Understanding (MOU) ~~with the Indonesian government under which PT-FI and the government agreed to negotiate an amended Contract of Work (COW) to address provisions~~ related to the size of PT-FI’s concession area, royalties and taxes, domestic processing and refining, divestment, local content, and continuation of operations post-2021. Execution of the MOU enabled the resumption of concentrate exports in August 2014, which had been suspended since January 2014. In addition, PT-FI is required to apply for renewal of export permits at six-month intervals, with the next renewal date in January 2015.

~~Under the MOU, provisions to be addressed in the negotiation of~~ an amended COW ~~include provisions for the development of new copper smelting and refining capacity~~ in ~~Indonesia, provisions for divestment~~July 2014, which was extended to the Indonesian government and/or Indonesian nationals of up to a 30 percent interest (an additional 20.64 percent interest) in PT-FI at fair value, and continuation of operations from 2022 through 2041. The MOU provides that negotiations for an amended COW will takeJuly 25, 2015. Negotiations are taking into consideration ~~PT-FI’s need~~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 ~~development~~construction of new smelter capacity in parallel with completing negotiations on its ~~underground reserves. The revisions~~COW and long-term operating rights. PT-FI has identified a site adjacent to the ~~COW are expected to result~~existing PT Smelting site in Gresik, Indonesia, for the construction of additional ~~costs for our Indonesian operations. PT-FI~~smelter capacity and is ~~engaged~~ in discussions with potential partners for the ~~Indonesian government regarding an amended COW.~~

Effective with the signing of the MOU, PT-FI provided a $115 million assurance bond to support its commitment for smelter development, agreed to increase royalties to 4.0 percent for copper and 3.75 percent for gold from the previous rates of 3.5 percent for copper and 1.0 percent for gold, and to pay export duties set forth in a new regulation. The Indonesian government revised its January 2014 regulations regarding export duties to incorporate reduced rates for copper concentrate exports for companies engaged in smelter development. The revised regulations provide for duties on copper concentrate exports during smelter development initially at 7.5 percent, declining to 5.0 percent when development progress exceeds 7.5 percent and is eliminated when development progress exceeds 30 percent. During third-quarter 2014, PT-FI paid export duties of $42 million and increased royalties of $20 million.project.

Under the MOU, no terms of the COW other than those relating to the export duties, ~~the~~a smelter bond and increased royalties ~~described above~~ will be changed until the completion of an amended COW.

PT-FI is required to apply for renewal of export permits at six-month intervals and the next renewal date is July 25, 2015.

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.

Operating and Development Activities. We have several projects in progress in the Grasberg minerals district related to the development of ~~the~~ 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

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~~2017.~~ 2018. Over the next five years, estimated aggregate capital spending on these projects is currently expected to average ~~$0.9~~$0.8 billion per year ($~~0.7~~0.6 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 ~~large~~ size of these projects, actual costs could vary from these estimates. ~~Additionally,~~ PT-FI may reduce or defer these activities pending resolution of negotiations for an amended COW.

The following provides additional information on the continued development of the Common Infrastructure project, the Grasberg Block Cave underground mine and ~~development of~~ 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

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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 ~~2017,~~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 ~~$5.2~~$5.7 billion (incurred between 2008 and 2021), with PT-FI’s share totaling approximately ~~$4.6~~$5.1 billion. Aggregate project costs totaling $~~1.7~~1.9 billion have been incurred through ~~September 30, 2014~~March 31, 2015 ($~~0.3~~0.1 billion during ~~the first nine months of~~first-quarter ~~2014~~2015).

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 ~~$2.6~~$2.7 billion (incurred between 2009 and 2020), with PT-FI’s share totaling approximately ~~$1.5~~$1.6 billion. Aggregate project costs totaling $~~1.1~~1.3 billion have been incurred through ~~September 30, 2014~~March 31, 2015 ($~~0.2~~0.1 billion during ~~the first nine months of~~first-quarter ~~2014~~2015).

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Operating Data. Following is summary operating data for our Indonesia mining operations for the ~~third~~first quarters ~~and first nine months~~ of ~~2014~~2015 and ~~2013~~2014:


	Three Months Ended				Nine Months Ended				Three Months Ended
	September 30,				September 30,				March 31,
	2014		2013		2014		2013		2015		2014
Operating Data, Net of Joint Venture Interest
Copper (recoverable)
Production (millions of pounds)	203		253		465		611		154		140
Sales (millions of pounds)	258		237		484		593		155		109
Average realized price per pound	$	3.05	$	3.30	$	3.09	$	3.27	$	2.74	$	3.04

Gold (recoverable)
Gold (thousands of recoverable ounces)
Production (thousands of ounces)	426		297		776		640		255		208
Sales (thousands of ounces)	505		278		802		620		260		162
Average realized price per ounce	$	1,219	$	1,330	$	1,248	$	1,393	$	1,186	$	1,299

100% Operating Data
Ore milled (metric tons per day):^a
Grasberg open pit	78,100		149,000		64,900		122,700		107,900		65,800
DOZ underground mine^b	57,600		47,600		52,800		45,900		49,000		50,300
Big Gossan underground mine^c	—		1,600		1,200		2,000		—		1,900
Total	135,700		198,200		118,900		170,600		156,900		118,000
Average ore grades:
Copper (percent)	0.88		0.74		0.78		0.71		0.57		0.73
Gold (grams per metric ton)	1.28		0.65		0.94		0.57		0.68		0.79
Recovery rates (percent):
Copper	91.4		89.7		89.9		89.1		90.5		88.5
Gold	84.6		80.3		81.5		76.3		84.5		79.4
Production (recoverable):
Copper (millions of pounds)	207		253		476		611		154		144
Gold (thousands of ounces)	426		297		777		640		255		209


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

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b.	~~Production~~Ore milled from the DOZ underground mine is expected to ramp up to ~~the design rate of 80,000~~70,000 metric tons of ore per day in ~~third-quarter~~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 ~~2017.~~2018.

Indonesia's sales volumes increased to ~~258~~155 million pounds of copper and ~~505~~260 thousand ounces of gold ~~for~~in ~~third-quarter~~first-quarter ~~2014~~2015, compared with ~~237~~109 million pounds of copper and ~~278~~162 thousand ounces of gold ~~for~~in ~~third-quarter~~first-quarter ~~2013~~2014, primarily reflecting higher ~~ore grades.~~operating rates as Indonesia's ~~sales volumes totaled 484 million pounds of copper and 802 thousand ounces of gold for the first nine months of~~ first-quarter 2014~~, compared with 593 million pounds of copper and 620 thousand ounces of gold for the first nine months of~~ ~~2013, reflecting lower~~ mill ~~throughput resulting from~~rates were negatively impacted by the export ban, partly offset by ~~higher gold~~lower ore grades.

At the Grasberg mine, the sequencing of mining areas with varying ore grades causes fluctuations in quarterly and annual production of copper and gold. Consolidated sales volumes from our Indonesia mining operations are expected to approximate ~~0.7 billion~~885 million pounds of copper and ~~1.15~~1.3 million ounces of gold for the year ~~2014~~2015, compared with ~~0.9 billion~~664 million pounds of copper and ~~1.1~~1.2 million ounces of gold infor the year ~~2013~~2014. ~~Sales from Indonesia mining are expected to increase through 2016 as PT-FI gains access to higher grade ore.~~

~~On September 27, 2014, four Grasberg workers were fatally injured when a haul truck collided with a light~~

~~vehicle near the Grasberg open-pit operations. Operations in the Grasberg open pit were temporarily suspended in~~

~~order to complete internal and government investigations regarding the accident. On October 13, 2014, Indonesian~~

~~authorities approved the resumption of operations after issuing recommendations on traffic control procedures~~

~~that have been implemented by PT-FI. Workforce attendance in several operating areas reflect normal levels.~~

~~However, a large percentage of Grasberg open-pit operators have not reported to their scheduled shifts resulting in~~

~~reduced production from the open pit during October. These actions conflict with agreed policies and processes in~~

~~the Collective Labor Agreement (CLA), and PT-FI is working with union leadership regarding this work stoppage to~~

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~~resume normal operations as soon as possible.~~

On October 27, 2014, PT-FI received notice from union leadership indicating its intention to conduct a 30-day strike beginning on November 6, 2014. Following constructive dialogue between PT-FI and union leadership, union leadership advised PT-FI on October 31, 2014, that all strike actions had been canceled.

Gross Profit per Pound of Copper and per Ounce of Gold

The following ~~tables summarize~~table summarizes the unit net cash costs and gross profit per pound of copper and per ounce of gold at our Indonesia mining operations for the ~~third~~first quarters ~~and first nine months~~ of ~~2014~~2015 and ~~2013~~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											Three Months Ended											Three Months Ended
	September 30, 2014										September 30, 2013											March 31, 2015											March 31, 2014
	By-Product Method				Co-Product Method						By-Product Method				Co-Product Method							By-Product Method				Co-Product Method							By-Product Method				Co-Product Method
					Copper			Gold						Copper				Gold							Copper				Gold							Copper				Gold
Revenues, excluding adjustments	$	3.05			$	3.05		$	1,219			$	3.30			$	3.30			$	1,330		$	2.74			$	2.74			$	1,186		$	3.04			$	3.04			$	1,299

Site production and delivery, before net noncash and other costs shown below	2.42				1.34			537			2.30				1.54				621			2.84				1.63				705			3.33			^a	2.01				859
Gold and silver credits	(2.44		)		—			—			(1.65		)		—				—			(2.09		)		—				—			(2.15		)		—				—
Treatment charges	0.25				0.14			56			0.23				0.15				62			0.29				0.17				73			0.24				0.15				62
Export duties	0.16				0.09			36			—				—				—			0.14				0.08				35			—				—				—
Royalty on metals	0.21			^a	0.12			45			0.11				0.08				31			0.16			^b	0.09				40			0.11				0.07				31
Unit net cash costs	0.60				1.69			674			0.99				1.77				714			1.34				1.97				853			1.53				2.23				952
Depreciation and amortization	0.35				0.20			79			0.25				0.17				68			0.45				0.26				112			0.44				0.26				114
Noncash and other costs, net	0.11				0.06			24			0.15				0.10				40			0.04				0.02				9			0.67			^a	0.41				174
Total unit costs	1.06				1.95			777			1.39				2.04				822			1.83				2.25				974			2.64				2.90				1,240
Revenue adjustments, primarily for pricing on prior period open sales	(0.01		)		(0.01		)	(1		)	0.08				0.08				17			(0.32		)		(0.32		)		33			(0.53		)		(0.53		)		107
PT Smelting intercompany loss	(0.19		)		(0.10		)	(42		)	(0.15		)		(0.10		)		(41		)
PT Smelting intercompany profit																						0.04				0.02				11			0.49				0.30				129
Gross profit per pound/ounce	$	1.79			$	0.99		$	399		$	1.84			$	1.24			$	484		$	0.63			$	0.19			$	256		$	0.36			$	(0.09	)		$	295

Copper sales (millions of recoverable pounds)	258				258						237				237							155				155							109				109
Gold sales (thousands of recoverable ounces)								505											278											260											162


a.	~~Includes $0.08~~Fixed costs totaling $0.49 per pound of copper ~~associated with increased royalty rates.~~

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Nine Months Ended Nine Months Ended
September 30, 2014 September 30, 2013
By-Product Method Co-Product Method By-Product Method Co-Product Method
Copper Gold Copper Gold
Revenues, excluding adjustments $ 3.09
$ 3.09
$ 1,248
$ 3.27
$ 3.27
$ 1,393

Site production and delivery, before net noncash and other costs shown below 2.90
1.72
694
2.74
1.87
795
Gold and silver credits (2.16 ) —
—
(1.52 ) —
—
Treatment charges 0.25
0.15
60
0.23
0.16
67
Export duties 0.09
0.05
21
—
—
—
Royalty on metals 0.16
^a
0.09
39
0.12
0.08
36
Unit net cash costs 1.24
2.01
814
1.57
2.11
898
Depreciation and amortization 0.40
0.24
96
0.29
0.20
85
Noncash and other costs, net 0.41
^b
0.25
98
0.21
0.14
60
Total unit costs 2.05
2.50
1,008
2.07
2.45
1,043
Revenue adjustments, primarily for pricing on prior period open sales (0.11 ) (0.11 ) 22
—
—
(2 )
PT Smelting intercompany profit 0.02
0.01
5
0.01
0.01
1
Gross profit per pound/ounce $ 0.95
$ 0.49
$ 267
$ 1.21
$ 0.83
$ 349

Copper sales (millions of recoverable pounds) 484
484
593
593

Gold sales (thousands of recoverable ounces) 802
620


a.	~~Includes $0.04 per pound of copper for the first nine months of 2014 associated with increased royalty rates.~~


b.	~~Includes $0.30 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.~~rates are excluded from site production and delivery and included in net noncash and other costs.


b.	Includes $0.07 per pound of copper associated with increased royalty rates pursuant to the MOU.

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A significant portion of PT-FI's costs are fixed and unit costs vary depending on ~~production~~sales volumes. Indonesia's unit net cash costs (net of gold and silver credits) totaled $~~0.60~~1.34 per pound of copper in ~~third-quarter~~first-quarter ~~2014~~ ~~and $1.24 per pound for the first nine months of~~ ~~2014~~2015, compared with $~~0.99~~1.53 per pound in ~~third-quarter~~first-quarter ~~2013~~ ~~and $1.57 per pound for the first nine months of~~ ~~2013~~2014, primarily reflecting higher ~~gold and silver credits,~~volumes, partly offset by ~~export duties, increased royalty rates and~~ the impact of ~~lower production~~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.

PT Smelting intercompany profit ~~(loss)~~ represents the change in the ~~elimination~~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 $~~1,250~~1,200 per ounce for ~~fourth-quarter~~the remainder of ~~2014~~2015, Indonesia's unit net cash costs (net of gold and silver credits) are expected to approximate $~~1.19~~1.09 per pound of copper for the year ~~2014~~2015, compared with ~~$1.12~~$1.06 for the year ~~2013.~~2014. Indonesia's projected unit net cash costs would change by approximately $~~0.05~~0.06 per pound for each $50 per ounce change in the average price of gold for ~~fourth-quarter~~the remainder of ~~2014~~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.

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Africa Mining

Africa mining includes ~~Tenke Fungurume Mining S.A.R.L's (TFM)~~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 ~~TFM,~~Tenke Fungurume Mining S.A. (TFM), and we are the operator of Tenke.

The Tenke operation includes surface 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.

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 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.

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Operating Data. Following is summary operating data for our Africa mining operations for the ~~third~~first quarters ~~and first nine months~~ of ~~2014~~2015 and ~~2013~~2014:


	Three Months Ended				Nine Months Ended				Three Months Ended
	September 30,				September 30,				March 31,
	2014		2013		2014		2013		2015		2014
Copper (recoverable)
Production (millions of pounds)	117		109		340		351		116		109
Sales (millions of pounds)	112		118		314		342		133		84
Average realized price per pound^a	$	3.11	$	3.19	$	3.09	$	3.22	$	2.66	$	3.07

Cobalt (contained)
Production (millions of pounds)	8		8		22		19		7		7
Sales (millions of pounds)	8		6		23		17		8		8
Average realized price per pound	$	9.99	$	8.57	$	9.68	$	8.10	$	8.72	$	9.21

Ore milled (metric tons per day)	15,500		14,500		15,100		14,700		14,500		14,500
Average ore grades (percent):
Copper	4.13		3.94		4.09		4.32		4.36		4.05
Cobalt	0.33		0.43		0.33		0.36		0.35		0.33
Copper recovery rate (percent)	91.3		91.6		92.8		91.7		94.0		94.7


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

TFM's copper sales of ~~112~~133 million pounds in ~~third-quarter~~first-quarter ~~2014~~ ~~and 314 million pounds for the first nine months of~~ ~~2014~~2015 were ~~lower~~higher than copper sales of ~~118~~84 million pounds in ~~third-quarter~~first-quarter ~~2013~~ ~~and 342 million pounds for thefirst nine months of~~ ~~2013~~2014, primarily because of timing of ~~shipments.~~shipments and higher ore grades.

For the year ~~2014~~2015, we expect sales volumes from TFM to approximate ~~445~~455 million pounds of copper and 34 million pounds of cobalt, compared with 425 million pounds of copper and 30 million pounds of cobalt ~~compared with~~ ~~454 million~~ ~~pounds of copper and~~ ~~25 million~~ ~~pounds of cobalt~~ for the year ~~2013~~2014.

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Gross Profit per Pound of Copper and Cobalt

The following ~~tables summarize~~table summarizes the unit net cash costs and gross profit per pound of copper and cobalt at our Africa mining operations for the ~~third~~first quarters of ~~and first nine months of~~ ~~2014~~2015 and ~~2013~~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											Three Months Ended											Three Months Ended
	September 30, 2014							September 30, 2013											March 31, 2015											March 31, 2014
	By-Product Method			Co-Product Method				By-Product Method				Co-Product Method							By-Product Method				Co-Product Method							By-Product Method				Co-Product Method
				Copper		Cobalt					Copper				Cobalt							Copper				Cobalt							Copper				Cobalt
Revenues, excluding adjustments^a	$	3.11		$	3.11	$	9.99		$	3.19			$	3.19			$	8.57		$	2.66			$	2.66			$	8.72		$	3.07			$	3.07			$	9.21

Site production and delivery, before net noncash and other costs shown below	1.61			1.40		5.32		1.43				1.38				4.14			1.57				1.39				5.61			1.48				1.22				5.16
Cobalt credits^b	(0.58		)	—		—		(0.27		)		—				—			(0.37		)		—				—			(0.66		)		—				—
Royalty on metals	0.07			0.06		0.18		0.07				0.06				0.13			0.06				0.05				0.14			0.07				0.06				0.16
Unit net cash costs	1.10			1.46		5.50		1.23				1.44				4.27			1.26				1.44				5.75			0.89				1.28				5.32
Depreciation, depletion and amortization	0.51			0.43		1.06		0.55				0.48				1.37			0.55				0.48				1.18			0.61				0.53				0.80
Noncash and other costs, net	0.05			0.04		0.10		0.02				0.02				0.06			0.03				0.02				0.06			0.08				0.08				0.12
Total unit costs	1.66			1.93		6.66		1.80				1.94				5.70			1.84				1.94				6.99			1.58				1.89				6.24
Revenue adjustments, primarily for pricing on prior period open sales	0.01			0.01		0.39		0.03				0.03				(0.27		)	(0.05		)		(0.05		)		(0.10		)	(0.01		)		(0.01		)		0.24
Gross profit per pound	$	1.46		$	1.19	$	3.72	$	1.42			$	1.28			$	2.60		$	0.77			$	0.67			$	1.63		$	1.48			$	1.17			$	3.21

Copper sales (millions of recoverable pounds)	112			112				118				118							133				133							84				84
Cobalt sales (millions of contained pounds)						8										6											8											8

Nine Months Ended Nine Months Ended
September 30, 2014 September 30, 2013
By-Product Method Co-Product Method By-Product Method Co-Product Method
Copper Cobalt Copper Cobalt
Revenues, excluding adjustments^a
$ 3.09
$ 3.09
$ 9.68
$ 3.22
$ 3.22
$ 8.10

Site production and delivery, before net noncash and other costs shown below 1.51
1.33
5.24
1.43
1.36
4.40
Cobalt credits^b
(0.51 ) —
—
(0.26 ) —
—
Royalty on metals 0.07
0.06
0.16
0.06
0.06
0.14
Unit net cash costs 1.07
1.39
5.40
1.23
1.42
4.54
Depreciation, depletion and amortization 0.55
0.47
1.04
0.52
0.48
0.97
Noncash and other costs, net 0.05
0.05
0.10
0.06
0.05
0.09
Total unit costs 1.67
1.91
6.54
1.81
1.95
5.60
Revenue adjustments, primarily for pricing on prior period open sales —
—
0.09
0.01
0.01
0.14
Gross profit per pound $ 1.42
$ 1.18
$ 3.23
$ 1.42
$ 1.28
$ 2.64

Copper sales (millions of recoverable pounds) 314
314
342
342

Cobalt sales (millions of contained pounds) 23
17


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 $~~1.10~~1.26 per pound of copper in ~~third-quarter~~first-quarter ~~2014~~ ~~and $1.07 per pound for the first nine months of~~ ~~2014~~2015 were ~~lower~~higher than unit net cash costs of $~~1.23~~0.89 per pound in ~~both the third quarter and first nine months of~~first-quarter ~~2013~~2014, primarily reflecting ~~higher~~lower cobalt ~~credits, partly offset by higher site production and delivery costs.~~credits.

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.

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Assuming achievement of current sales volume and cost estimates, and an average cobalt market price of $13 per pound for ~~fourth-quarter~~the remainder of ~~2014~~2015, average unit net cash costs (net of cobalt credits) are expected to approximate $~~1.16~~1.26 per pound of copper for the year ~~2014~~2015, compared with $~~1.21~~1.15 per pound in ~~2013~~2014. Africa's projected unit net cash costs would change by $~~0.02~~0.07 per pound for each $2 per pound change in the average price of cobalt during ~~fourth-quarter~~the remainder of ~~2014~~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 ~~certain of~~ 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 ~~third-quarter 2014, 12 million pounds in third-quarter 2013, 40 million pounds for~~ the ~~first nine months~~first-quarters of ~~2014~~2015 and ~~37 million pounds for the first nine months of2013.~~2014. Refer to "Consolidated Results" for our consolidated molybdenum operating data, which includes sales of molybdenum produced at our ~~molybdenum~~Molybdenum mines, and atfrom 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

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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 ~~decreased to~~were $~~7.12~~7.17 per pound of molybdenum in ~~third-quarter~~first-quarter ~~2014~~2015 and ~~$6.76 per pound for the first nine months of~~ ~~2014, compared with~~ $~~7.15~~6.71 per pound in ~~third-quarter~~first-quarter ~~2013~~2014 ~~and $7.08 per pound for the first nine months of~~ ~~2013, primarily reflecting higher production volumes.~~. Assuming achievement of current sales volume and cost estimates, we estimate unit net cash costs for ~~our~~the Molybdenum mines ~~are expected~~ to average ~~approximately~~ $~~7.00~~7.50 per pound of molybdenum for the year ~~2014~~2015., compared with $7.08 per pound in 2014.

We continue to monitor market conditions and may make adjustments to our primary molybdenum production as market conditions warrant. 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.

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 in treatment charges because these operations are largely integrated with our ~~wholly owned smelter located in~~ Miami ~~Arizona.~~

~~Atlantic Copper, our wholly owned subsidiary located in Spain, smelts and refines copper concentrates and markets refined copper and precious metals in slimes. During the first nine months of2014~~, Atlantic Copper purchased 25 percent of its concentrate requirements from our North America mining operations, 20 percent from our South America copper mines and 9 percent from our Indonesia mining operations, with the remainder purchased from third parties.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 first-quarter2015, Atlantic Copper purchased 30 percent of its concentrate requirements from our North 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. PT-FI sold approximately half of its copper concentrate production to PT Smelting in first-quarter 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 ~~(reductions)~~ additions to net income attributable to common stockholders ~~totaling~~of $~~(20)~~24 million in ~~third-quarter~~first-quarter ~~2014~~2015 and ~~$36 million for the first nine months of~~ ~~2014, compared with~~ $216 million in ~~third-quarter~~first-quarter ~~2013~~ ~~and $28 million for the first nine months of~~ ~~2013~~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 $8738 million at ~~September 30, 2014~~March 31, 2015. Quarterly variations in ore grades, the timing of

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intercompany shipments and changes in product prices will result in variability in our net deferred profits and quarterly earnings.

Oil and Gas

~~Our~~Through our oil and gas ~~operations provide exposure to energy markets with favorable long-term fundamentals, strong margins~~subsidiary FM O&G, our portfolio of oil and ~~cash flows, and a large resource base with financially attractive exploration and development investment opportunities. The portfolio of~~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~~Central Wyoming, and an industry-leading position in the emerging Inboard Lower Tertiary/Cretaceous natural gas trend located in the shallow waters of the GOM and onshore in South Louisiana. ~~More than 90~~During first-quarter 2015, 86 percent of our oil and gas revenues, ~~are~~excluding the impact of derivative contracts, were from oil and NGLs.

~~Our oil and gas operations~~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 ~~into cost centers on a country-by-country basis. Capitalized costs, along with estimated future costs to develop proved reserves~~ and ~~asset retirement costs that are not already included in oil and gas properties, net of related salvage value, are~~ amortized to expense under the ~~unit-of-production~~UOP method on a country-by-country basis using estimates of proved oil and natural gas ~~reserves.~~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, at which time the related costs are subject to amortization.~~evaluated. Our depletion, depreciation and amortization rate is affected by changes to estimates of proved reserves and costs subject to amortization, as further discussed in ~~"Critical~~

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"Critical Accounting Estimates" in Part II, ~~Item 7~~Items 7. and 7a7A. of our annual report on Form 10-K for the year ended December 31, ~~2013.~~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. As of ~~September 30, 2014, the~~March 31, 2015, net capitalized costs with respect to FM O&G's proved U.S. oil and gas properties exceeded the ~~related~~ ceiling amount specified by the SEC's full cost accounting rules, which resulted in the recognition of an impairment charge ~~of $308 million~~totaling $3.1 billion ($~~192 million~~1.9 billion to net ~~income~~loss attributable to common stock)~~, reflecting higher capitalized costs and~~ for first-quarter 2015. The SEC requires the ~~lower~~ 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 West Texas Intermediate (WTI) as the reference oil price, was $82.72 per barrel at ~~September 30, 2014. We evaluated~~March 31, 2015 (the twelve-month average was $94.99 per barrel at December 31, 2014).

Because the ceiling limitation uses a twelve-month historical average price, if WTI oil prices remain below the twelve-month average of $82.72 per barrel, the ceiling limitation will decrease, resulting in potentially significant additional ceiling test impairments of our ~~goodwill, which totaled $1.7 billion at September 30, 2014, and is assigned to our U.S.~~ oil and gas ~~reporting unit, and concluded no impairment charge~~properties during the remainder of 2015. The twelve-month average WTI oil price was ~~required~~$78.58 per barrel at ~~September~~April 30, ~~2014.~~ 2015.

As further discussed in "Critical Accounting Estimates" in Part II, ~~Item 7~~Items 7. and 7a7A. of our annual report on Form 10-K for the year ended December 31, ~~2013,~~2014, events that could result in impairment of our oil and gas properties in future periods include, but are not limited to, a decline in trailing average oil and gas prices, ~~transfers of~~ costs ~~into~~transferred from unevaluated properties to the full cost pool without ~~equivalent increased~~corresponding proved oil and natural gas reserve ~~values, increased costs or~~additions, negative reserve ~~revisions. In the near term,~~revisions, and increased future development or production costs. As FM O&G ~~expects to conduct significant completion~~completes activities to assess ~~certain of~~ its unevaluated ~~properties. As these assessments are completed,~~properties, related costs currently recorded as unevaluated properties not subject to amortization will be transferred into 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.

~~During October~~ U.S. Oil and Gas Operations. Following is summary operating results for the U.S. oil and gas operations for the first quarters of2015 and 2014:



	Three Months Ended
	March 31,
	2015			2014
Sales Volumes
Oil (MMBbls)	8.4			11.8
Natural gas (Bcf)	21.8			19.5
NGLs (MMBbls)	0.5			1.1
MMBOE	12.5			16.1		^a

Average Realizations^b
Oil (per barrel)	$	56.51		$	93.76
Natural gas(per MMBtu)	$	2.86		$	4.67
NGLs (per barrel)	$	23.06		$	45.47

Gross (Loss) Profit per BOE
Realized revenues^b	$	43.71		$	77.22
Less: cash production costs^b	20.26			18.51		^a
Cash operating margin^b	23.45			58.71
Less: depreciation, depletion and amortization	42.30			38.21
Less: impairment of oil and gas properties	247.84			—
Less: accretion and other costs	2.31			0.78
Plus: net noncash mark-to-market (losses) gains on derivative contracts	(3.87		)	0.90
Plus: other net adjustments	0.06			0.04
Gross (loss) profit	$	(272.81	)	$	20.66


a.	Includes results from Eagle Ford, which had sales volumes totaling 4.7 MMBOE in first-quarter 2014. Excluding the Eagle Ford properties, first-quarter 2014 oil and gas production costs were $20.89 per BOE.


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

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(including average realizations 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."

In first-quarter2015, FM O&G's average realized price for crude oil was $56.51 per barrel, including $11.97 per barrel of realized cash gains on derivative contracts. Excluding the impact of derivative contracts, the first-quarter2015 average realized price for crude oil was $44.54 per barrel (81 percent of the average Brent crude oil price of $55.19 per barrel).

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 $65 per barrel for Brent crude oil, we would receive a benefit of $20 per barrel on remaining 2015 derivative contract volumes of 23.1 million barrels, before taking into account weighted-average premiums of $6.89 per barrel. See Note 6 for further discussion.

In first-quarter2015, FM O&G's average realized price for natural gas was $2.86 per MMBtu, compared to the NYMEX natural gas price average of $2.98 per MMBtu for the January through March 2015 contracts.

Realized revenues for oil and gas operations of $43.71 per BOE in first-quarter2015 were lower than realized revenues of $77.22 per BOE in first-quarter 2014, primarily reflecting lower oil prices, ~~declined significantly from~~partly offset by the ~~third-quarter~~impact of higher realized cash gains on derivative contracts (realized cash gains were $100 million or $8.00 per BOE in first-quarter2015, compared with losses of $65 million or $4.01 per BOE in first-quarter 2014).

Cash production costs for oil and gas operations of $20.26 per BOE in first-quarter2015 were higher than cash production costs of $18.51 per BOE in first-quarter 2014, ~~average. Continuation~~primarily reflecting the sale of ~~recent~~lower-cost Eagle Ford properties.

Following is a summary of average sales volumes per day by region for oil ~~price declines, increases~~and gas operations for the first quarters of2015 and 2014:



	Three Months Ended
	March 31,
	2015	2014
Sales Volumes (MBOE per day):
GOM^a	74	70
California	39	39
Haynesville/Madden/Other	26	17
Eagle Ford^b	—	53
Total oil and gas operations	139	179


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


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

Daily sales volumes averaged 139 MBOE in ~~capitalized~~first-quarter2015, including 93 thousand barrels (MBbls) of crude oil, 242 million cubic feet (MMcf) of natural gas and 6 MBbls of NGLs. Oil and gas sales volumes are expected to average 143 MBOE per day for the year 2015, comprised of 67 percent oil, 29 percent natural gas and 4 percent NGLs.

Based on current sales volume and cost estimates, cash production costs ~~subject~~are expected to ~~amortization and other factors discussed above, may result in future additional ceiling test impairments. A ceiling test impairment may also trigger an impairment assessment of our goodwill balance.~~approximate $19 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 ~~being~~ managed to reinvest its cash flows in projects with attractive rates of return and risk profiles. Following the recent sharp decline in oil prices, we have taken steps to significantly reduce capital spending plans and near-term oil and gas growth initiatives and are evaluating funding opportunities for capital expenditures for our oil and gas business, including consideration of a sale of public equity for a minority interest in FM O&G.

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FM O&G has a large strategic position in the Deepwater GOM with significant current oil production, strong cash margins and existing infrastructure and facilities with excess 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 ~~exploitation~~ drilling and development opportunities that can be tied back to existing facilities. ~~Additional oil and gas asset sales and other transactions may be considered to provide incremental funding to accelerate FM O&G’s growth plans in the Deepwater GOM.~~

U.S. Oil and Gas Capital Expenditures. First-quarter 2015 capital expenditures for our U.S. oil and gas operations ~~approximated $0.9~~totaled $1.0 billion ~~for~~ ~~third-quarter2014, including $0.5~~(including $0.6 billion incurred for the Deepwater GOM, ~~and $0.2~~$0.1 billion for the Inboard Lower Tertiary/Cretaceous natural gas trend and $0.3 billion primarily associated with prior period costs).

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~~and $2.4 billion for the first nine months of 2014, including $1.3 billion incurred for the Deepwater GOM and $0.5 billion for the Inboard Lower Tertiary/Cretaceous natural gas trend.~~ Capital expenditures for ~~our~~ oil and gas operations ~~which~~ are ~~expected~~estimated to ~~be funded by its operating cash flows and oil and gas asset sales, are projected to approximate~~total $~~3.4~~2.8 billion for the year ~~2014~~2015~~, including~~ ~~$2.0 billion~~ ~~for the Deepwater GOM and~~ ~~$0.7 billion~~ for the Inboard Lower Tertiary/Cretaceous natural gas trend. Our future capital spending estimates may be adjusted to incorporate results from our ongoing drilling activities and follow-on development activities, and changes in market conditions.

~~See "Financial and Operating Data" below for further discussion of our current oil and gas operations.~~

~~Sale and Purchase Transactions.In June 2014, FM O&G completed the sale of the Eagle Ford shale assets for cash consideration of $3.1 billion ($2.6 billion net of taxes and closing adjustments)~~. Approximately $1.3 billion of the proceeds was placed in a like-kind exchange escrow to reinvest in additional oil and gas interests and the remaining net proceeds were used to repay debt. In June 2014, FM O&G completed the acquisition of Deepwater GOM interests for $0.9 billion, including interests in the Lucius and Heidelberg oil fields and several exploration leases, and in September 2014, FM O&G acquired additional Deepwater GOM interests for $0.5 billion, including an 18.67 percent interest in the Vito oil discovery in the Mississippi Canyon area (Blocks 940, 941, 984 and 985) and a significant lease position in the Vito area.

~~Financial and Operating Data.~~ ~~Following is summary operating results for the U.S. oil and gas operations for the~~ ~~third quarters~~ ~~and first nine months of~~ ~~2014~~ ~~and~~ ~~2013~~:

Three Months Ended Nine Months Ended
September 30, September 30,
2014 2013
2014^a

2013^b

Sales Volumes
Oil (MMBbls) 8.6
11.5
32.1
14.9

Natural gas (Bcf) 20.2
23.5
59.9
31.3

NGLs (MMBbls) 0.6
1.0
2.7
1.3

MMBOE 12.5
16.5
44.7
21.5

Average Realizations^c

Oil (per barrel) $ 88.58
$ 104.33
$ 93.00
$ 102.76

Natural gas(per MMBtu)
$ 4.02
$ 3.97
$ 4.37
$ 3.94

NGLs (per barrel) $ 39.69
$ 37.16
$ 41.77
$ 36.70

Gross (Loss) Profit per BOE
Realized revenues^c
$ 69.08
$ 80.93
$ 75.04
$ 79.40

Less: cash production costs^c
20.93
16.80
19.57
16.76

Cash operating margin^c
48.15
64.13
55.47
62.64

Less: depreciation, depletion and amortization 40.12
34.15
38.81
34.07

Less: impairment of oil and gas properties 24.59
—
6.90
—

Less: accretion and other costs 0.85
0.70
0.86
0.80

Plus: net noncash mark-to-market gains (losses) on derivative contracts 9.73
(9.58 ) 2.90
(9.04 )
Plus: other net adjustments 0.09
0.06
0.05
0.04

Gross (loss) profit $ (7.59 ) $ 19.76
$ 11.85
$ 18.77


a.	~~Includes results from Eagle Ford through June 19, 2014.~~


b.	~~Include the results of FM O&G beginning June 1, 2013.~~

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, and cash production costs exclude accretion and other costs. For reconciliations of realized revenues (including average realizations for oil, natural gas and NGLs) 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."

~~FM O&G's average realized price for crude oil was $88.58 per barrel, net of $6.77 per barrel associated with payments on derivative contracts in~~ ~~third-quarter2014, and $93.00 per barrel, net of $5.41 per barrel associated with payments on derivative contracts for the first nine months of~~ ~~2014. Excluding the impact of derivative contracts,~~

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~~the~~ ~~third-quarter2014~~ ~~average realized price for crude oil was $95.35 per barrel (92 percent~~ ~~of the average Brent crude oil price of~~ ~~$103.50~~ ~~per barrel) and $98.41 per barrel (92~~85 percent of the ~~average Brent crude oil price of $106.98 per barrel) for the first nine months of~~ ~~2014~~.

FM O&G has derivative contracts that provide price protection averaging between approximately $70 and $90 per barrel of Brent crude oil for all of its estimated fourth-quarter 2014 oil production and approximately 80 percent of estimated 2015 ~~oil production. See Note 7 for further discussion.~~

~~FM O&G's average realized price for natural gas was $4.02 per MMBtu in~~ ~~third-quarter2014~~ ~~and $4.37 per MMBtu for the first nine months of~~ ~~2014. Excluding the impact of derivative contracts, the~~ ~~third-quarter2014~~ ~~average realized price for natural gas was $4.00 per MMBtu, compared~~capital budget is expected to be directed to the ~~NYMEX natural gas price average~~highest return focus areas in the GOM. Capital expenditures for 2015 have been revised from the estimate of ~~$4.06 per MMBtu for the July through~~ ~~September 2014~~ ~~contracts, and $4.58 per MMBtu for the first nine months of~~ ~~2014, compared to the NYMEX natural gas price average of $4.54 per MMBtu for the January through~~ ~~September 2014~~ ~~contracts.~~

~~Realized revenues for oil and gas operations of $69.08 per BOE~~$2.3 billion, provided in ~~third-quarter2014~~ were lower than realized revenues of $80.93 per BOE in third-quarter 2013, primarily reflecting lower oil prices (the Brent crude oil average price was $6.09 per barrel lower) and higher realized cash lossesour annual report on derivative contracts ($58 million or $4.62 per BOE in third-quarter 2014, compared with $12 million or $0.74 per BOE in third-quarter 2013). Realized revenues of $75.04 per BOE for the first nine months of ~~2014~~ were lower than realized revenues of $79.40 per BOE for the four month period from June 1, 2013, to September 30, 2013 primarily reflecting higher realized cash losses on derivative contracts ($186 million or $4.16 per BOE for the first nine months of ~~2014, compared with $11 million or $0.49 per BOE for the four month period from June 1, 2013, to September 30, 2013).~~

~~Cash production costs of $20.93 per BOE in~~ ~~third-quarter2014~~ ~~and $19.57 per BOE for the first nine months of~~ ~~2014~~ ~~were higher than cash production costs of $16.80 per BOE in~~ ~~third-quarter~~ 2013 and $16.76 per BOE for the four month period from June 1, 2013, to September 30, 2013, primarily reflecting the sale of lower cost Eagle Ford properties in June 2014 and the higher operating costs in California.

~~Based on current sales volume and cost estimates for fourth-quarter 2014, cash production costs are expected to approximate~~ ~~$21~~ ~~per BOE~~Form 10-K for the year ended December 31, 2014, reflecting increased development drilling and ~~$24~~ ~~per BOE for fourth-quarter 2014. Fourth-quarter 2014 sales volumes and unit cost estimates reflect downtime for maintenance affecting production rates at Marlin in the Deepwater GOM.~~

~~The~~activities following ~~table presents average sales volumes per day by region for our oil and gas operations for the~~ ~~third quarters~~ ~~and first nine months of~~ ~~2014~~ ~~and 2013:~~

Three Months Ended Nine Months Ended
September 30, September 30,
2014 2013 2014
2013^a
Sales Volumes (MBOE per day):
GOM^b
75
73
74
71
California 39
39
39
38
Haynesville/Madden/Other 22
^c
21
19
^c
22
Eagle Ford —
46
32
^d
45
Total oil and gas operations 136
179
164
176


a.	~~Includes the results of FM O&G beginning June 1, 2013.~~

Includes sales from properties on the GOM Shelf and in the Deepwater GOM. Production from the GOM Shelf totaled 14 MBOE per day in third-quarter 2014 (18 percent of the GOM total), 12 MBOE per day for the first nine months of 2014 (17 percent of the GOM total) and 13 MBOE per day (18 percent of the GOM total) for both third-quarter 2013 and the four-month period from June 1, 2013, to September 30, 2013.


c.	~~Results include volume adjustments related to Eagle Ford's pre-close sales.~~


d.	~~FM O&G completed the sale of Eagle Ford on June 20, 2014.~~

~~Daily sales volumes averaged~~ ~~136~~ ~~MBOE in~~ ~~third-quarter2014, including~~ 93 ~~MBbls of crude oil,~~ ~~219~~ ~~million cubic feet (MMcf) of natural gas and~~ 6 ~~MBbls of NGLs, and 164 MBOE for the first nine months of~~ ~~2014, including 117 MBbls of crude oil, 220 MMcf of natural gas and 10 MBbls of NGLs. The decrease in daily average sales volumes~~

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~~for the 2014 periods primarily reflects the sale of Eagle Ford properties in June 2014. Oil and gas sales volumes are expected to average 125 MBOE per day for fourth-quarter~~ ~~2014, comprised of 67 percent oil, 29 percent natural gas and 4 percent NGLs.~~success from first-quarter 2015 exploration results.

Deepwater ~~Gulf of Mexico.~~GOM. Multiple development and exploration opportunities have been identified in the Deepwater GOM that ~~are expected to~~ benefit from ~~tie-back~~tieback opportunities to significant available production capacity at the FM O&G operated large-scale Holstein, Marlin and Horn Mountain deepwater production platforms. ~~Operations to pursue these opportunities have commenced and activities are expected to accelerate following the delivery of additional contracted drillships~~In addition, FM O&G has interests in ~~late 2014 and mid-year 2015. Production is also expected to benefit from the commencement of production from~~ the Lucius ~~oil field in late 2014, the~~and Heidelberg oil ~~field in 2016~~fields, and ~~longer range development~~ in the Vito basin area.

~~All major construction~~During first-quarter 2015, FM O&G achieved several important accomplishments. Positive drilling results were achieved at the Holstein Deep and ~~installation~~King tie-back projects ~~for~~and the Power Nap prospect in the Vito area. Production commenced at the Lucius facility, the Dorado development well and Highlander, with aggregate rates of approximately 25 MBOE per day by the end of March 2015. Development progressed at the Heidelberg field.

Initial production was successfully established in January 2015 at the Lucius oil ~~field~~facility inKeathley ~~Canyon are finished, and the initial six development wells are being completed. Commissioning work is in progress with first oil production from the~~Canyon. The facility has a capacity of 80 MBbls of oil per day ~~spar expected~~and is scheduled to ~~be achieved~~ramp up to full capacity in ~~fourth-quarter 2014. The geologic results from the~~second-quarter 2015. Lucius consists of six subsea wells ~~drilled since 2009 confirm a significant oil resource. Lucius is a subsea development consisting of~~tied back to a truss spar hull located in 7,200 feet of water. FM O&G has a 25.1 percent working interest in Lucius.

During ~~third-quarter 2014, fabrication work on the~~first-quarter 2015, development activities advanced at Heidelberg, spar hull and load-out was completed in Finland. The hull for this 80 MBbls of oil per day Lucius-look-alike facility arrived in Texas in October 2014, and fabrication of the main topsides module is approximately 60 percent complete. Development drilling is underway and the project remains on track for first production in 2016. Heidelbergwhich is a large, high-quality oil development project located in 5,300 feet of water in the Green Canyon area. Fabrication of the main topsides module is more than 85 percent complete, and the operator plans to install the hull in second-quarter 2015. The Heidelberg truss spar was designed as a Lucius-look-alike facility with capacity of 80 MBbls of oil per day. Development drilling continues, and the project remains on track for first production in 2016. FM O&G has a 12.5 percent working interest in Heidelberg.

Following successful drilling results at the 100-percent-owned Holstein Deep delineation well in the Green Canyon area in late 2014 that logged 444 feet of net oil pay, FM O&G achieved positive results at the second delineation well in first-quarter 2015. Wireline logs indicated that the well encountered approximately 482 feet of net oil pay and established sand continuity across the primary reservoir encountered in the first delineation well. The second well, which is updip to the discovery well, was drilled to 32,260 feet in February 2015. In April 2015, FM O&G commenced drilling the third delineation well, which is the most updip in the reservoir and is currently drilling below 7,200 feet towards a proposed total depth of approximately 30,800 feet. Production from the planned three-well subsea tieback development program is expected to reach approximately 15 MBOE per day in the first half of 2016.

Drilling results, logs and accompanying other data received to date continues to support the potential for additional development opportunities at Holstein Deep to achieve production of up to 75 MBOE per day by 2020. The Holstein Deep development is located in Green Canyon Block 643, west of the Holstein platform in 3,890 feet of water. FM O&G has identified multiple additional development opportunities in the Green Canyon area that could be tied back to the Holstein facility.

Marlin, in which FM O&G has a 100 percent working interest, is located in ~~Green Canyon~~Viosca Knoll and has production facilities capable of producing in excess of ~~100~~60 MBbls of oil per day. Several tieback opportunities in the area have been identified, including the Dorado and King development projects.

In March 2015, FM O&G performed a successful production test in excess of 8 MBOE per ~~day. Drilling~~day and established production on the first of three planned subsea tieback wells from the ~~Holstein platform rig commenced~~100-percent-owned Dorado development

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project. 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.

In first-quarter ~~2014. The first~~2015, sidetrack ~~well commenced production~~drilling at the 100-percent-owned King prospect encountered the optimum oil take point in ~~June 2014~~the M66 reservoir, and a second sidetrack well was completed in third-quarter 2014, commencing initial production in October 2014. Combined production from the first two sidetrack wells is over 4 MBOE per day. Operations to commence the third sidetrack wellcompletion operations are under way. ~~FM O&G expects~~The well is expected to ~~drill four~~commence production in late 2015, and additional ~~sidetrack wells from~~drilling is planned in the ~~Holstein platform. FM O&G also plans to drill several subsea tie-back wells from contracted drillships to enhance production volumes from~~area starting in the ~~spar.~~

~~Delineation drilling for subsalt Miocene objectives on the western flank~~second-half of ~~the Holstein Deep prospect commenced~~2015. King is located in third-quarter 2014. In October 2014, interim logging and core results above 28,500 feet from the delineation well indicated 110 net feet of pay with positive reservoir characteristics and good correlation with the discovery well. The delineation well, which is approximately one mileMississippi Canyon south of the ~~discovery well, is currently drilling below 28,900 feet towards a proposed total depth of 32,000 feet to evaluate the primary objectives. The Holstein Deep development,~~Marlin facility in ~~which FM O&G has a 100 percent working interest, is located west of the Holstein platform in 3,890~~5,200 feet of water and is a subsea tie-back opportunity to the Holstein facility. FM O&G acquired the acreage associated with this development in a 2013 lease sale held by the BOEM. Two successful wells with approximately 500 net feet of oil pay had previously been drilled in recent years.water.

FM O&G drilled two exploration wells at the Copper prospect during third-quarter 2014. The first well encountered multiple hydrocarbon bearing sands in the Pliocene and Miocene totaling approximately 100 feet of net pay. Follow-on drilling at the second location was unsuccessful. FM O&G is currently evaluating future plans for this prospect, which is located southeast of the Holstein field in 4,400 feet of water and is a subsea tie-back opportunity to the Holstein facility. FM O&G has a 100 percent working interest in Copper.

~~Marlin,~~Horn Mountain, in which FM O&G has a 100 percent working interest, is located in Mississippi Canyon and has production facilities capable of producing ~~in excess~~75 MBbls of ~~60 MBOE~~oil per day. Several ~~tie-back~~tieback opportunities in the area have been ~~identified. Development~~identified including Kilo/Oscar/Quebec/Victory (KOQV), which are expected to commence drilling ~~at Dorado commenced~~ in ~~October 2014.~~mid-2015. This ~~multi-well,~~ infill ~~development~~drilling program will target undrained fault blocks and updip resource potential just east of the Horn Mountain facility. KOQV is located in approximately 5,500 feet of water.

In first-quarter 2015, sidetrack drilling at the Power Nap exploration well in the Vito area successfully extended the known oil reservoir downdip. A second sidetrack well was drilled to a favorable position to acquire core data from the primary pay sand. The operator is preparing to drill the Deep Sleep exploration well, which is a key offset to the Vito and Power Nap discoveries. Deep Sleep is located in 4,200 feet of water approximately 5 miles south of ~~the Marlin facility.~~Power Nap. FM O&G ~~also plans to commence exploitation drilling at the King M63 prospect~~owns a 50 percent working interest in ~~late 2014. King is located south of the Marlin facility in 5,200 feet of water.~~Power Nap and Deep Sleep.

FM O&G has an 18.67 percent working interest in the Vito oil discovery in the Mississippi Canyon area and a significant lease position in the Vito basin in the Mississippi Canyon and Atwater Valley areas. Vito, a large, deep subsalt Miocene oil discovery made in 2009, is located in approximately 4,000 feet of ~~water and is operated by Shell Offshore Inc.~~water. Exploration and appraisal drilling in recent years confirmed a significant resource in high-quality, subsalt Miocene

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sands. Development options are under evaluation. The acquired exploration leases in the Vito basin area (with working interests ranging from 50 percent to 100 percent) provide high potential tie-back opportunities and are complementary to FM O&G’s existing lease position in the Mississippi Canyon and Atwater Valley areas.

The Power Nap exploration prospect, in which FM O&G has a 50 percent working interest, commenced drilling in September 2014 towards a proposed total depth of 31,100 feet. The prospect is a Vito analog play. Power Nap is located in the Vito basin in 4,200 feet of water and is operated by Shell Offshore Inc.

Inboard Lower Tertiary/Cretaceous. FM O&G has an industry-leading position in the emerging Inboard Lower Tertiary/Cretaceous natural gas trend, located on the Shelf of the GOM and onshore in South Louisiana. FM O&G has a large onshore and offshore lease acreage position with high-quality prospects and the potential to develop a significant long-term, low-cost source of natural gas. Data from eight wells drilled to date indicate the presence of geologic formations that are analogous to productive formations in the Deepwater GOM and onshore in the Gulf Coast region. The near-term focus is on defining the trend onshore.

The Highlander discovery, which is located onshore in South Louisiana, began production on February 25, 2015, following production testing that indicated a flow rate of 75 MMcf per day (approximately 37 MMcf per day net to FM O&G). The well has been restricted to approximately 24 MMcf per day because of limited processing facilities. FM O&G is currently developing additional processing facilities to accommodate the higher flow rates, and installation is expected by year-end 2015. A second well location has been identified and future plans are being ~~completed to test Cretaceous/Tuscaloosa objectives found below the salt weld and flow testing is anticipated in fourth-quarter 2014. The Highlander onshore exploratory well, in which~~considered. FM O&G is the operator and has a 72 percent working interest ~~located~~and an approximate 49 percent net revenue interest in St. Martin Parish, Louisiana, encountered gas pay in several Wilcox and Cretaceous/Tuscaloosa sands between 24,000 feet and 29,000 feet in January 2014. As previously reported, the wireline log and core data obtained from the Wilcox and Cretaceous sand packages indicated favorable reservoir characteristics with approximately 150 feet of net pay.Highlander. FM O&G has identified multiple ~~exploratory~~ prospects in the Highlander area where it controls rights to more than ~~60,000~~50,000 gross acres.

In September and October 2014, flow testing was performed on middle Miocene sand sections in the Blackbeard West No. 2 well on Ship Shoal Block 188, in which FM O&G has a 69.4 percent working interest. During the testing period, the well flowed at a rate of approximately 2,000 barrels of water per day with flowing tubing pressure of approximately 9,000 pounds per square inch. While the well did not result in hydrocarbon production in commercial quantities, this water rate indicates that subsalt sands on the Shelf below 20,000 feet are capable of substantial production rates. The well will be temporarily abandoned while FM O&G evaluates plans to complete and test shallower upper Miocene sands in the well. A rig will be moved to Blackbeard East in fourth-quarter 2014 to complete and test the middle Miocene sands in this well. FM O&G holds a 90 percent working interest in Blackbeard East. FM O&G plans to temporarily abandon the Davy Jones No. 2 well in order to use certain equipment from the well to advance the completion and testing of the Highlander well. Future plans for Davy Jones will be determined following the Highlander flow test.

The Farthest Gate West onshore exploration prospect ~~commenced drilling in October 2014 and is currently drilling below 9,100 feet towards~~was drilled to a ~~proposed~~ total depth of ~~29,000 feet.~~approximately 22,000 feet in March 2015, and wireline logs indicated the well encountered hydrocarbon bearing sands in the Eocene section. FM O&G plans to complete and flow test the well in second-quarter 2015. FM O&G is the operator and has a 90 percent working interest in Farthest Gate West, which is located onshore in Cameron Parish, Louisiana, and is a Lineham Creek analog prospect with Paleogene objectives. FM O&G is currently reviewing completion options for the Lineham Creek discovery, in which FM O&G has a 36 percent working interest.Louisiana.

California. FM O&G's California assets benefit from an established oil production base with a stable production profile and access to favorably priced crude markets. Development plans are principally focused on maintaining stable production levels through continued drilling in the long-established producing fields onshore in California. FM O~~&G's~~&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.

Haynesville.FM O&G has rights to a substantial natural gas resource, located in the Haynesville shale play in North Louisiana. Drilling activities in recent years have been reduced to maximize cash flows in a low natural gas price environment and to benefit from 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. ~~The prospects include Miocene, Cretaceous and Jurassic targets.~~ FM O&G expects to commence drilling the ~~first~~MZ-1 well associated with the Ouanoukrim prospect in ~~early~~May 2015. First-quarter 2015 capital expenditures for international oil and gas exploration activities in Morocco totaled $15 million.

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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. We ~~continue~~remain committed to ~~target significant reductions~~a strong balance sheet and will take prudent actions in ~~debt by the end of 2016 using cash flows generated above capital expenditures and other cash requirements.~~response to market conditions. We have taken steps to ~~accelerate~~sell assets, defer capital spending and reduce dividends on our ~~deleveraging plans through asset sales and~~common stock. We will continue to evaluate our portfolio for ~~potential~~ future ~~monetizations. We may also take additional steps to reduce or defer capital spending and other costs in response to market conditions.~~actions.

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 at ~~September 30, 2014~~March 31, 2015 (in millions):

Cash at domestic companies $ 61

Cash at international operations 597
^a
Total consolidated cash and cash equivalents 658

Less: noncontrolling interests’ share (161 )
Cash, net of noncontrolling interests’ share 497

Less: withholding taxes and other (41 )
Net cash available $ 456
^a

~~a. Includes $121 million of consolidated cash and cash equivalents at Candelaria and Ojos del Salado ($80 million available to the parent company).~~




Cash at domestic companies	$	53
Cash at international operations	496
Total consolidated cash and cash equivalents	549
Less: noncontrolling interests’ share	(143		)
Cash, net of noncontrolling interests’ share	406
Less: withholding taxes and other	(18		)
Net cash available	$	388

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. Management believes that sufficient liquidity is available in the U.S. from cash balances and availability from our revolving credit facility and uncommitted lines of credit (see discussion below). 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.

Debt

Following is a summary of our total debt and the related weighted-average interest rates at ~~September 30, 2014~~March 31, 2015 (in billions, except percentages):

Weighted-
Average
Interest Rate
FCX Senior Notes $ 9.5
3.6%
FM O&G Senior Notes 4.6
^a
6.9%
FCX Term Loan 3.8
1.7%
Other FCX debt 1.8
2.8%
Total debt $ 19.7
3.9%

a. On October 15, 2014, we redeemed the $400 million principal amount of our 8.625% Senior Notes. Holders received the principal amount together with the redemption premium and accrued and unpaid interest to the redemption date. We expect to report a pre-tax gain of $24 million in fourth-quarter 2014 associated with this redemption.



			Weighted-
			Average
			Interest Rate
FCX Senior Notes	$	11.9	3.8%
FCX Term Loan	3.0		1.9%
FM O&G Senior Notes	2.6		6.6%
Other FCX debt	2.8		2.6%
Total debt	$	20.3	3.7%

On May 30, 2014, we amended our revolving credit facility, extending the maturity date by one year, to May 31, 2019, and increased the aggregate principal amount available from $3.0 billion to $4.0 billion. At ~~September 30, 2014~~March 31, 2015, we had ~~$1.1 billion~~$985 million of borrowings outstanding and ~~$45~~$42 million ofin letters of credit issued under our $4 billion revolving credit facility.

We also have uncommitted ~~unsecured~~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. ~~As of~~At ~~September 30, 2014~~March 31, 2015, there ~~were $250~~was $350 million of borrowings drawn on these lines of credit.

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In ~~March 2014,~~addition, Cerro Verde ~~entered into~~has a ~~five-year,~~ $1.8 billion senior unsecured credit ~~facility. Amounts may be drawn or letters of credit issued over a two-year period~~facility to fund a portion of ~~the~~its expansion project (see "Operations - South America Mining") and for Cerro Verde's general corporate purposes. At ~~September 30, 2014~~March 31, 2015, there ~~were~~ nowas $847 million of borrowings and no letters of credit issued under Cerro Verde’s credit facility.

Refer to Note 65 for further discussion of our debt.

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Operating Activities

During ~~the~~ ~~first nine months of~~first-quarter ~~2014~~2015, we generated consolidated operating cash flows totaling $~~4.5 billion~~717 million (net of $~~699~~86 million for working capital uses and changes in other tax payments), compared with consolidated operating cash flows ~~for the~~ ~~first nine months of2013~~of $~~3.7~~1.2 billion (net of $~~489~~413 million for working capital uses and changes in other tax payments) for first-quarter2014. Consolidated operating cash flows for ~~the first nine months of 2014 benefited from a full nine months of our oil and gas operations, partly offset by~~first-quarter2015 reflected the impact of lower ~~copper and gold~~oil volumes, lower commodity price realizations and ~~lower copper sales volumes.~~changes in inventory.

Based on current operating plans and subject to future copper, gold, molybdenum and crude oil prices, we expect estimated consolidated operating cash flows for the year ~~2014~~2015, plus available cash ~~asset sales proceeds~~ and availability under our ~~revolving~~ 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 ~~2014~~2015.

Investing Activities

Capital Expenditures. Capital expenditures, including capitalized interest, totaled $~~5.4~~1.9 billion for ~~the~~ ~~first nine months of~~first-quarter ~~2014~~2015, including $~~2.0~~0.6 billion for major projects at mining operations and ~~$2.4~~$1.0 billion for oil and gas operations, compared with ~~$3.6~~$1.6 billion for ~~the~~ ~~first nine months of~~first-quarter ~~2013~~2014, including ~~$1.4~~$0.7 billion for major projects at mining operations and ~~$0.9~~$0.6 billion for oil and gas ~~operations for the four month period from June 1, 2013, to September 30, 2013.~~operations. Increased capital expenditures at our ~~mining~~oil and gas operations for ~~the first nine months of~~ ~~2014~~first-quarter2015 iswas primarily associated with our highest return focus areas in the ~~expansion project at Cerro Verde.~~GOM. Refer to “Operations” for further discussion.

Capital expenditures are currently expected to approximate $~~7.5~~6.5 billion for the year ~~2014~~2015, including $~~3.0~~2.5 billion for major projects at mining operations (primarily for the ~~expansion projects at~~ Cerro Verde ~~and Morenci,~~expansion and underground development activities at Grasberg) and $~~3.4~~2.8 billion for oil and gas ~~operations (primarily~~operations. We have taken actions to reduce or defer capital expenditures and other costs and are evaluating funding alternatives to advance growth projects in ~~the Deepwater GOM). Capital spending plans remain under review~~our oil and gas business, including consideration of a sale of public equity for a minority interest in our oil and gas subsidiary. Additional capital cost reductions, potential additional divestitures or monetizations and other actions will be ~~revised~~pursued as ~~market conditions warrant.~~required to maintain a strong balance sheet while preserving a strong resource position and portfolio of assets with attractive long-term growth prospects. We have a broad set of natural resource assets that provide many alternatives for future actions to enhance our financial flexibility. Refer to "Operations" for further discussion.

~~Acquisitions and Dispositions.~~ In June 2014, we completed the sale of the Eagle Ford shale assets for cash consideration of $3.1 billion. Approximately $1.3 billion of the proceeds was placed in a like-kind exchange escrow to reinvest in additional oil and gas interests and the remaining net proceeds were used to repay debt. In June 2014 and September 2014, we completed acquisitions of Deepwater GOM interests totaling $1.4 billion. Refer to Note 2 ~~for further discussion of our oil and gas acquisition and disposal transactions.~~

~~In second-quarter 2013, we paid $3.5 billion in cash (net of cash acquired) for the acquisition of PXP and $1.6 billion in cash (net of cash acquired) for the acquisition of MMR.~~

In March 2013, we paid $348 million (net of cash acquired) to fund the acquisition of a cobalt chemical refinery in Kokkola, Finland, and the related sales and marketing business. The acquisition was funded 70 percent by us and 30 percent by Lundin, our joint venture partner.

Financing Activities

~~Debt Transactions.~~ In third-quarter 2014, we redeemed $1.7 billion of the aggregate principal amount of outstanding senior notes with an average interest rate of 6.6 percent under the equity clawback provisions of the instruments. Holders received the principal amount together with the redemption premium and accrued and unpaid interest to the redemption date.

In second-quarter 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.

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~~We used available cash and borrowings under the revolving credit facility and uncommitted lines of credit to fund the redemptions. Refer to Note~~ 6 ~~for further discussion of debt transactions for the~~ ~~first nine months of2014~~.

~~Proceeds from debt for the~~ ~~first nine months of2013~~ ~~primarily included amounts from the sale of~~ ~~$6.5 billion~~ ~~of unsecured senior notes in four tranches with a weighted-average interest rate of~~ ~~3.9 percent~~ and borrowings of $4.0 billion under an unsecured term loan with an interest rate of LIBOR plus 1.5 percent. Net proceeds from these borrowings were used to fund the second-quarter 2013 oil and gas acquisitions, repay certain debt of PXP and for general corporate purposes. Repayments of debt for the ~~first nine months of2013~~ ~~primarily reflected the repayment of the $3.9 billion outstanding under PXP's amended credit facility and $0.4 billion of PXP senior notes that were assumed in the oil and gas acquisitions.~~

Dividends. We paid dividends on our common stock totaling $~~1.0 billion~~327 million for ~~the first nine months of~~ ~~2014~~first-quarter2015 and $~~2.0 billion~~326 million for first-quarter2014. In response to the ~~first nine months~~impact of ~~2013~~ ~~(which included $1.0 billion for a supplemental dividend of $1.00 per share paid on July 1, 2013). The current~~lower commodity prices, in March 2015, the annual dividend rate for our common stock iswas reduced to $0.20 per share from the previous rate of $1.25 per ~~share ($0.3125~~share. On March 24, 2015, our Board of Directors (the Board) declared a regular quarterly dividend of $0.05 per share, ~~quarterly).~~which was paid on May 1, 2015. The declaration of dividends is at the discretion of ~~our~~the Board ~~of Directors (Board)~~ and will depend upon our financial results, cash requirements, future prospects and other factors deemed relevant by the Board. The Board will continue to review our financial policy on an ongoing ~~basis.~~basis and anticipates increasing cash returns to shareholders as market and business conditions warrant.

As further discussed in Note 8, on April 7, 2015, the Delaware Court of Chancery approved the settlement of our stockholder derivative litigation and awarded the plaintiffs' legal fees and expenses. In accordance with the settlement terms, we expect the Board to declare a special dividend of approximately $115 million ($0.11 per share) that would be payable in early August 2015, corresponding with the timing of our next regular quarterly dividend. This special dividend will be primarily funded with insurance proceeds, net of plaintiffs’ legal fees and expenses, that were deposited in an escrow account in first-quarter 2015.

Cash dividends and other distributions paid to noncontrolling interests totaled $~~365~~23 million for the first ~~nine~~three months of ~~2014~~2015 and $~~157~~77 million for the first ~~nine~~three months of ~~2013~~2014. These payments will vary based on the cash requirements of our consolidated subsidiaries.

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CONTRACTUAL OBLIGATIONS

~~Except as discussed in Note 13, there~~There have been no material changes in our contractual obligations since December 31, ~~2013.~~2014. Refer to Item 7 in our annual report on Form 10-K for the year ended December 31, ~~2013,~~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. ~~During third-quarter 2014, we recorded additional~~There have been no material changes to our environmental and asset retirement obligations totaling $403 million ($413 million on an undiscounted and unescalated basis) related to increased estimated costs to reclaim a waste stockpile at Grasberg. Additionally, in accordance with the 2011 Chilean legislation regulating mine closure, we will submit revised closure plans for our Chilean mine sites in Novembersince December 31, 2014. ~~We expect to record additional asset retirement obligations in fourth-quarter 2014 associated with these revised closure plans.~~ Updated cost assumptions, including increases and decreases to cost estimates, changes in the anticipated 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, ~~2013~~2014, for further information regarding our environmental and asset retirement obligations.

Litigation and Other Contingencies

~~There~~Other than as discussed in Note 8, 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, ~~2013~~2014. Refer to Note 12 and "Legal Proceedings" contained in Part I, Item 33. of our annual report on Form 10-K for the year ended December 31, ~~2013~~2014, ~~as updated in Note 9 to the financial statements included in our quarterly report on Form 10-Q for the quarter ended March 31, 2014,~~ for further information regarding legal proceedings and other matters.

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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 11 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. ~~GAAP~~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 ~~presentation~~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, 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.

~~U.S.~~ 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 September 30, 2014
Three Months Ended March 31, 2015
(In millions)	By-Product			Co-Product Method											By-Product			Co-Product Method
	Method			Copper			Molybdenum^a			Other^b		Total			Method			Copper			Molybdenum^a			Other^b		Total
Revenues, excluding adjustments	$	1,374		$	1,374		$	106		$	34	$	1,514		$	1,285		$	1,285		$	82		$	26	$	1,393
Site production and delivery, before net noncash and other costs shown below	791			776			25			19		820			854			802			58			19		879
By-product credits	(111		)	—			—			—		—			(83		)	—			—			—		—
Treatment charges	50			49			—			1		50			60			59			—			1		60
Net cash costs	730			825			25			20		870			831			861			58			20		939
Depreciation, depletion and amortization	131			128			1			2		131			133			125			6			2		133
Noncash and other costs, net	46			45			—			1		46			31			30			1			—		31
Total costs	907			998			26			23		1,047			995			1,016			65			22		1,103
Revenue adjustments, primarily for pricing on prior period open sales	(8		)	(8		)	—			—		(8		)	(29		)	(29		)	—			—		(29		)
Gross profit	$	459		$	368		$	80		$	11	$	459		$	261		$	240		$	17		$	4	$	261

Copper sales (millions of recoverable pounds)	434			434											471			471
Molybdenum sales (millions of recoverable pounds)^a							8														9

Gross profit per pound of copper/molybdenum:	Gross profit per pound of copper/molybdenum:														Gross profit per pound of copper/molybdenum:

Revenues, excluding adjustments	$	3.17		$	3.17		$	13.55							$	2.73		$	2.73		$	8.81
Site production and delivery, before net noncash and other costs shown below	1.83			1.79			3.17								1.81			1.70			6.25
By-product credits	(0.26		)	—			—								(0.18		)	—			—
Treatment charges	0.11			0.11			—								0.13			0.13			—
Unit net cash costs	1.68			1.90			3.17								1.76			1.83			6.25
Depreciation, depletion and amortization	0.30			0.30			0.17								0.28			0.27			0.63
Noncash and other costs, net	0.11			0.10			0.03								0.07			0.06			0.05
Total unit costs	2.09			2.30			3.37								2.11			2.16			6.93
Revenue adjustments, primarily for pricing
on prior period open sales	(0.02		)	(0.02		)	—								(0.06		)	(0.06		)	—
Gross profit per pound	$	1.06		$	0.85		$	10.18							$	0.56		$	0.51		$	1.88

Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization								Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	1,514		$	820		$	131							$	1,393		$	879		$	133
Treatment charges	—			50			—								—			60			—
Noncash and other costs, net	—			46			—								—			31			—
Revenue adjustments, primarily for pricing on prior period open sales	(8		)	—			—								(29		)	—			—
Eliminations and other	(16		)	(14		)	2								(29		)	(27		)	—
North America copper mines	1,490			902			133								1,335			943			133
Other mining & eliminations^c	3,216			1,978			305								2,318			1,683			272
Total mining	4,706			2,880			438								3,653			2,626			405
U.S. oil & gas operations	990			273			812		^d						500			283			3,634		^d
Corporate, other & eliminations	—			(1		)	3								—			3			4
As reported in FCX’s consolidated financial statements	$	5,696		$	3,152		$	1,253	^d						$	4,153		$	2,912		$	4,043	^d


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 109.


d.	Includes impairment of oil and gas properties of $~~308 million~~3.1 billion.

6757

Table of Contents

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


Three Months Ended September 30, 2013
Three Months Ended March 31, 2014
(In millions)	By-Product			Co-Product Method									By-Product			Co-Product Method
	Method			Copper			Molybdenum^a		Other^b		Total		Method			Copper			Molybdenum^a		Other^b		Total
Revenues, excluding adjustments	$	1,183		$	1,183		$	89	$	27	$	1,299	$	1,194		$	1,194		$	82	$	28	$	1,304
Site production and delivery, before net noncash and other costs shown below	725			701			35		18		754		695			655			50		19		724
By-product credits	(87		)	—			—		—		—		(81		)	—			—		—		—
Treatment charges	35			34			—		1		35		47			46			—		1		47
Net cash costs	673			735			35		19		789		661			701			50		20		771
Depreciation, depletion and amortization	100			97			2		1		100		104			99			4		1		104
Noncash and other costs, net	27			27			—		—		27		30			30			—		—		30
Total costs	800			859			37		20		916		795			830			54		21		905
Revenue adjustments, primarily for pricing on prior period open sales	9			9			—		—		9		(7		)	(7		)	—		—		(7		)
Gross profit	$	392		$	333		$	52	$	7	$	392	$	392		$	357		$	28	$	7	$	392

Copper sales (millions of recoverable pounds)	362			362									369			369
Molybdenum sales (millions of recoverable pounds)^a	Molybdenum sales (millions of recoverable pounds)^a						9						Molybdenum sales (millions of recoverable pounds)^a						8

Gross profit per pound of copper/molybdenum:	Gross profit per pound of copper/molybdenum:												Gross profit per pound of copper/molybdenum:

Revenues, excluding adjustments	$	3.27		$	3.27		$	10.24					$	3.24		$	3.24		$	10.17
Site production and delivery, before net noncash and other costs shown below	2.00			1.94			4.01						1.88			1.78			6.14
By-product credits	(0.24		)	—			—						(0.22		)	—			—
Treatment charges	0.10			0.09			—						0.13			0.12			—
Unit net cash costs	1.86			2.03			4.01						1.79			1.90			6.14
Depreciation, depletion and amortization	0.27			0.27			0.24						0.29			0.27			0.53
Noncash and other costs, net	0.08			0.07			0.03						0.08			0.08			0.02
Total unit costs	2.21			2.37			4.28						2.16			2.25			6.69
Revenue adjustments, primarily for pricing
on prior period open sales	0.02			0.02			—						(0.02		)	(0.02		)	—
Gross profit per pound	$	1.08		$	0.92		$	5.96					$	1.06		$	0.97		$	3.48

Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization						Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	1,299		$	754		$	100					$	1,304		$	724		$	104
Treatment charges	—			35			—						—			47			—
Noncash and other costs, net	—			27			—						—			30			—
Revenue adjustments, primarily for pricing on prior period open sales	9			—			—						(7		)	—			—
Eliminations and other	(7		)	(9		)	2						(11		)	(15		)	3
North America copper mines	1,301			807			102						1,286			786			107
Other mining & eliminations^c	3,688			2,235			251						2,438			1,640			239
Total mining	4,989			3,042			353						3,724			2,426			346
U.S. oil & gas operations	1,176			288			563						1,261			311			616
Corporate, other & eliminations	—			2			3						—			—			4
As reported in FCX’s consolidated financial statements	$	6,165		$	3,332		$	919					$	4,985		$	2,737		$	966


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.

~~Table of Contents~~

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

Nine Months Ended September 30, 2014
(In millions) By-Product Co-Product Method
Method Copper
Molybdenum^a

Other^b
Total
Revenues, excluding adjustments $ 3,901
$ 3,901
$ 297
$ 96
$ 4,294
Site production and delivery, before net noncash and other costs shown below 2,272
2,232
69
54
2,355
By-product credits (310 ) —
—
—
—
Treatment charges 144
140
—
4
144
Net cash costs 2,106
2,372
69
58
2,499
Depreciation, depletion and amortization 360
352
4
4
360
Noncash and other costs, net 105
104
—
1
105
Total costs 2,571
2,828
73
63
2,964
Revenue adjustments, primarily for pricing on prior period open sales (7 ) (7 ) —
—
(7 )
Gross profit $ 1,323
$ 1,066
$ 224
$ 33
$ 1,323

Copper sales (millions of recoverable pounds) 1,224
1,224

Molybdenum sales (millions of recoverable pounds)^a
25

Gross profit per pound of copper/molybdenum:

Revenues, excluding adjustments $ 3.19
$ 3.19
$ 11.93

Site production and delivery, before net noncash
and other costs shown below 1.86
1.83
2.75

By-product credits (0.25 ) —
—

Treatment charges 0.11
0.11
—

Unit net cash costs 1.72
1.94
2.75

Depreciation, depletion and amortization 0.29
0.29
0.15

Noncash and other costs, net 0.09
0.08
0.03

Total unit costs 2.10
2.31
2.93

Revenue adjustments, primarily for pricing
on prior period open sales (0.01 ) (0.01 ) —

Gross profit per pound $ 1.08
$ 0.87
$ 9.00

Reconciliation to Amounts Reported
(In millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 4,294
$ 2,355
$ 360

Treatment charges —
144
—

Noncash and other costs, net —
105
—

Revenue adjustments, primarily for pricing on prior period open sales (7 ) —
—

Eliminations and other (42 ) (46 ) 8

North America copper mines 4,245
2,558
368

Other mining & eliminations^c
8,471
5,502
810

Total mining 12,716
8,060
1,178

U.S. oil & gas operations 3,487
913
2,044
^d

Corporate, other & eliminations —
(2 ) 10

As reported in FCX’s consolidated financial statements $ 16,203
$ 8,971
$ 3,232
^d


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.


d.	~~Includes impairment of oil and gas properties of~~ ~~$308 million~~9.

~~Table of Contents~~

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

Nine Months Ended September 30, 2013
(In millions) By-Product Co-Product Method
Method Copper
Molybdenum^a

Other^b
Total
Revenues, excluding adjustments $ 3,655
$ 3,655
$ 280
$ 80
$ 4,015
Site production and delivery, before net noncash and other costs shown below 2,201
2,130
101
56
2,287
By-product credits (274 ) —
—
—
—
Treatment charges 112
109
—
3
112
Net cash costs 2,039
2,239
101
59
2,399
Depreciation, depletion and amortization 303
293
6
4
303
Noncash and other costs, net 88
87
1
—
88
Total costs 2,430
2,619
108
63
2,790
Revenue adjustments, primarily for pricing on prior period open sales (4 ) (4 ) —
—
(4 )
Gross profit $ 1,221
$ 1,032
$ 172
$ 17
$ 1,221

Copper sales (millions of recoverable pounds) 1,084
1,084

Molybdenum sales (millions of recoverable pounds)^a
26

Gross profit per pound of copper/molybdenum:

Revenues, excluding adjustments $ 3.37
$ 3.37
$ 11.03

Site production and delivery, before net noncash
and other costs shown below 2.03
1.97
3.99

By-product credits (0.25 ) —
—

Treatment charges 0.10
0.10
—

Unit net cash costs 1.88
2.07
3.99

Depreciation, depletion and amortization 0.28
0.27
0.25

Noncash and other costs, net 0.08
0.08
0.03

Total unit costs 2.24
2.42
4.27

Revenue adjustments, primarily for pricing
on prior period open sales —
—
—

Gross profit per pound $ 1.13
$ 0.95
$ 6.76

Reconciliation to Amounts Reported
(In millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 4,015
$ 2,287
$ 303

Treatment charges —
112
—

Noncash and other costs, net —
88
—

Revenue adjustments, primarily for pricing on prior period open sales (4 ) —
—

Eliminations and other (16 ) (28 ) 9

North America copper mines 3,995
2,459
312

Other mining & eliminations^c
9,526
6,058
726

Total mining 13,521
8,517
1,038

U.S. oil & gas operations 1,512
377
732

Corporate, other & eliminations 3
10
8

As reported in FCX’s consolidated financial statements $ 15,036
$ 8,904
$ 1,778



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.

7058

Table of Contents

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


Three Months Ended September 30, 2014
Three Months Ended March 31, 2015
(In millions)	By-Product			Co-Product Method										By-Product			Co-Product Method
	Method			Copper			Other				Total			Method			Copper			Other^a				Total
Revenues, excluding adjustments	$	840		$	840		$	69		^a	$	909		$	542		$	542		$	21			$	563
Site production and delivery, before net noncash and other costs shown below	451			415			43				458			350			337			18				355
By-product credits	(62		)	—			—				—			(16		)	—			—				—
Treatment charges	43			43			—				43			33			33			—				33
Royalty on metals	1			1			—				1			1			1			—				1
Net cash costs	433			459			43				502			368			371			18				389
Depreciation, depletion and amortization	102			96			6				102			75			72			3				75
Noncash and other costs, net	18			19			(1		)		18			4			6			(2		)		4
Total costs	553			574			48				622			447			449			19				468
Revenue adjustments, primarily for pricing on prior period open sales	(15		)	(15		)	—				(15		)	(30		)	(30		)	—				(30		)
Gross profit	$	272		$	251		$	21			$	272		$	65		$	63		$	2			$	65

Copper sales (millions of recoverable pounds)	271			271										200			200

Gross profit per pound of copper:	Gross profit per pound of copper:													Gross profit per pound of copper:

Revenues, excluding adjustments	$	3.10		$	3.10									$	2.71		$	2.71
Site production and delivery, before net noncash and other costs shown below	1.67			1.53										1.75			1.69
By-product credits	(0.23		)	—										(0.08		)	—
Treatment charges	0.16			0.16										0.17			0.17
Royalty on metals	—			—										—			—
Unit net cash costs	1.60			1.69										1.84			1.86
Depreciation, depletion and amortization	0.37			0.35										0.38			0.36
Noncash and other costs, net	0.07			0.07										0.02			0.03
Total unit costs	2.04			2.11										2.24			2.25
Revenue adjustments, primarily for pricing
on prior period open sales	(0.06		)	(0.06		)								(0.15		)	(0.15		)
Gross profit per pound	$	1.00		$	0.93									$	0.32		$	0.31

Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization							Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	909		$	458		$	102						$	563		$	355		$	75
Treatment charges	(43		)	—			—							(33		)	—			—
Royalty on metals	(1		)	—			—							(1		)	—			—
Noncash and other costs, net	—			18			—							—			4			—
Revenue adjustments, primarily for pricing on prior period open sales	(15		)	—			—							(30		)	—			—
Eliminations and other	(3		)	(5		)	—							(13		)	(14		)	—
South America mining	847			471			102							486			345			75
Other mining & eliminations^b	3,859			2,409			336							3,167			2,281			330
Total mining	4,706			2,880			438							3,653			2,626			405
U.S. oil & gas operations	990			273			812			^c				500			283			3,634			^c
Corporate, other & eliminations	—			(1		)	3							—			3			4
As reported in FCX’s consolidated financial statements	$	5,696		$	3,152		$	1,253		^c				$	4,153		$	2,912		$	4,043		^c


a.	Includes ~~gold~~silver sales of 16386 thousand ounces ($~~1,234~~ ~~per ounce average realized price) and silver sales of~~ ~~684 thousand~~ ~~ounces ($18.57~~14.79 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 109.


c.	Includes impairment of oil and gas properties of $~~308 million~~3.1 billion.

~~Table of Contents~~

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

Three Months Ended September 30, 2013
(In millions) By-Product Co-Product Method
Method Copper Other Total
Revenues, excluding adjustments $ 1,065
$ 1,065
$ 79
^a
$ 1,144
Site production and delivery, before net noncash and other costs shown below 483
453
35
488
By-product credits (74 ) —
—
—
Treatment charges 52
52
—
52
Net cash costs 461
505
35
540
Depreciation, depletion and amortization 85
80
5
85
Noncash and other costs, net 14
5
9
14
Total costs 560
590
49
639
Revenue adjustments, primarily for pricing on prior period open sales 49
49
—
49
Gross profit $ 554
$ 524
$ 30
$ 554

Copper sales (millions of recoverable pounds) 323
323

Gross profit per pound of copper:

Revenues, excluding adjustments $ 3.30
$ 3.30

Site production and delivery, before net noncash
and other costs shown below
1.49
1.40

By-product credits (0.22 ) —

Treatment charges 0.16
0.16

Unit net cash costs 1.43
1.56

Depreciation, depletion and amortization 0.26
0.25

Noncash and other costs, net 0.05
0.02

Total unit costs 1.74
1.83

Revenue adjustments, primarily for pricing
on prior period open sales 0.15
0.15

Gross profit per pound $ 1.71
$ 1.62

Reconciliation to Amounts Reported
(In millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 1,144
$ 488
$ 85

Treatment charges (52 ) —
—

Noncash and other costs, net —
14
—

Revenue adjustments, primarily for pricing on prior period open sales 49
—
—

Eliminations and other (2 ) (8 ) —

South America mining 1,139
494
85

Other mining & eliminations^b
3,850
2,548
268

Total mining 4,989
3,042
353

U.S. oil & gas operations 1,176
288
563

Corporate, other & eliminations —
2
3

As reported in FCX’s consolidated financial statements $ 6,165
$ 3,332
$ 919


a.	~~Includes gold sales of~~ ~~26 thousand~~ ~~ounces ($1,335~~ ~~per ounce average realized price) and silver sales of~~ ~~841 thousand~~ ~~ounces ($15.20~~ ~~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.

7259

Table of Contents

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



Three Months Ended March 31, 2014
(In millions)	By-Product				Co-Product Method
	Method				Copper			Other^a			Total
Revenues, excluding adjustments	$	941			$	941		$	84		$	1,025
Site production and delivery, before net noncash and other costs shown below	461				426			40			466
By-product credits	(79		)		—			—			—
Treatment charges	53				53			—			53
Net cash costs	435			^b	479			40			519
Depreciation, depletion and amortization	87				80			7			87
Noncash and other costs, net	17				19			(2		)	17
Total costs	539				578			45			623
Revenue adjustments, primarily for pricing on prior period open sales	(73		)		(73		)	—			(73		)
Gross profit	$	329			$	290		$	39		$	329

Copper sales (millions of recoverable pounds)	307			^b	307

Gross profit per pound of copper:

Revenues, excluding adjustments	$	3.07			$	3.07
Site production and delivery, before net noncash and other costs shown below	1.50				1.39
By-product credits	(0.25		)		—
Treatment charges	0.17				0.17
Unit net cash costs	1.42			^b	1.56
Depreciation, depletion and amortization	0.28				0.27
Noncash and other costs, net	0.06				0.06
Total unit costs	1.76				1.89
Revenue adjustments, primarily for pricing
on prior period open sales	(0.24		)		(0.24		)
Gross profit per pound	$	1.07			$	0.94

Reconciliation to Amounts Reported
(In millions)	Revenues				Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	1,025			$	466		$	87
Treatment charges	(53		)		—			—
Noncash and other costs, net	—				17			—
Revenue adjustments, primarily for pricing on prior period open sales	(73		)		—			—
Eliminations and other	(1		)		(7		)	—
South America mining	898				476			87
Other mining & eliminations^c	2,826				1,950			259
Total mining	3,724				2,426			346
U.S. oil & gas operations	1,261				311			616
Corporate, other & eliminations	—				—			4
As reported in FCX’s consolidated financial statements	$	4,985			$	2,737		$	966

Nine Months Ended September 30, 2014
(In millions) By-Product Co-Product Method
Method Copper Other Total
Revenues, excluding adjustments $ 2,775
$ 2,775
$ 227
^a
$ 3,002
Site production and delivery, before net noncash and other costs shown below 1,424
1,315
124
1,439
By-product credits (212 ) —
—
—
Treatment charges 151
151
—
151
Royalty on metals 4
4
—
4
Net cash costs 1,367
1,470
124
1,594
Depreciation, depletion and amortization 284
266
18
284
Noncash and other costs, net 57
64
(7 ) 57
Total costs 1,708
1,800
135
1,935
Revenue adjustments, primarily for pricing on prior period open sales (66 ) (66 ) —
(66 )
Gross profit $ 1,001
$ 909
$ 92
$ 1,001

Copper sales (millions of recoverable pounds) 888
888

Gross profit per pound of copper:

Revenues, excluding adjustments $ 3.12
$ 3.12

Site production and delivery, before net noncash
and other costs shown below 1.61
1.48

By-product credits (0.24 ) —

Treatment charges 0.17
0.17

Royalty on metals —
—

Unit net cash costs 1.54
1.65

Depreciation, depletion and amortization 0.32
0.30

Noncash and other costs, net 0.06
0.08

Total unit costs 1.92
2.03

Revenue adjustments, primarily for pricing
on prior period open sales (0.07 ) (0.07 )
Gross profit per pound $ 1.13
$ 1.02

Reconciliation to Amounts Reported
(In millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 3,002
$ 1,439
$ 284

Treatment charges (151 ) —
—

Royalty on metals (4 ) —
—

Noncash and other costs, net —
57
—

Revenue adjustments, primarily for pricing on prior period open sales (66 ) —
—

Eliminations and other (5 ) (19 ) —

South America mining 2,776
1,477
284

Other mining & eliminations^b
9,940
6,583
894

Total mining 12,716
8,060
1,178

U.S. oil & gas operations 3,487
913
2,044
^c

Corporate, other & eliminations —
(2 ) 10

As reported in FCX’s consolidated financial statements $ 16,203
$ 8,971
$ 3,232
^c


a.	Includes gold sales of 5923 thousand ounces ($~~1,280~~1,307 per ounce average realized price) and silver sales of ~~2.2 million~~796 thousand ounces ($~~19.10~~19.82 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 first-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	$	435	307	$	1.42
Less: Candelaria and Ojos del Salado	122		94
	$	313	213	$	1.47


b.c.	Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10. 9.



c.	~~Includes impairment of oil and gas properties of~~ ~~$308 million~~.

~~Table of Contents~~

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

Nine Months Ended September 30, 2013
(In millions) By-Product Co-Product Method
Method Copper Other Total
Revenues, excluding adjustments $ 3,042
$ 3,042
$ 245
^a
$ 3,287
Site production and delivery, before net noncash and other costs shown below 1,453
1,349
119
1,468
By-product credits (230 ) —
—
—
Treatment charges 151
151
—
151
Net cash costs 1,374
1,500
119
1,619
Depreciation, depletion and amortization 242
228
14
242
Noncash and other costs, net 38
11
27
38
Total costs 1,654
1,739
160
1,899
Revenue adjustments, primarily for pricing on prior period open sales (29 ) (29 ) —
(29 )
Gross profit $ 1,359
$ 1,274
$ 85
$ 1,359

Copper sales (millions of recoverable pounds) 923
923

Gross profit per pound of copper:

Revenues, excluding adjustments $ 3.30
$ 3.30

Site production and delivery, before net noncash
and other costs shown below 1.57
1.46

By-product credits (0.25 ) —

Treatment charges 0.17
0.17

Unit net cash costs 1.49
1.63

Depreciation, depletion and amortization 0.26
0.24

Noncash and other costs, net 0.04
0.01

Total unit costs 1.79
1.88

Revenue adjustments, primarily for pricing
on prior period open sales (0.04 ) (0.04 )
Gross profit per pound $ 1.47
$ 1.38

Reconciliation to Amounts Reported
(In millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 3,287
$ 1,468
$ 242

Treatment charges (151 ) —
—

Noncash and other costs, net —
38
—

Revenue adjustments, primarily for pricing on prior period open sales (29 ) —
—

Eliminations and other (3 ) (21 ) —

South America mining 3,104
1,485
242

Other mining & eliminations^b
10,417
7,032
796

Total mining 13,521
8,517
1,038

U.S. oil & gas operations 1,512
377
732

Corporate, other & eliminations 3
10
8

As reported in FCX’s consolidated financial statements $ 15,036
$ 8,904
$ 1,778



a.	Includes gold sales of 68 thousand ounces ($1,415 per ounce average realized price) and silver sales of 2.6 million ounces ($22.51 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.

7460

Table of Contents

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


Three Months Ended September 30, 2014
Three Months Ended March 31, 2015
(In millions)	By-Product			Co-Product Method													By-Product			Co-Product Method
	Method			Copper			Gold				Silver			Total			Method			Copper			Gold			Silver^a		Total
Revenues, excluding adjustments	$	786		$	786		$	615			$	15	^a	$	1,416		$	425		$	425		$	308		$	7	$	740
Site production and delivery, before net noncash and other costs shown below	624			346			271				7			624			440			252			183			5		440
Gold and silver credits	(629		)	—			—				—			—			(324		)	—			—			—		—
Treatment charges	65			36			28				1			65			45			26			19			—		45
Export duties	42			23			18				1			42			22			13			9			—		22
Royalty on metals	52			29			23				—			52			25			15			10			—		25
Net cash costs	154			434			340				9			783			208			306			221			5		532
Depreciation and amortization	92			51			40				1			92			70			40			29			1		70
Noncash and other costs, net	28			16			12				—			28			6			3			3			—		6
Total costs	274			501			392				10			903			284			349			253			6		608
Revenue adjustments, primarily for pricing on prior period open sales	(3		)	(3		)	(1		)		—			(4		)	(50		)	(50		)	8			1		(41		)
PT Smelting intercompany loss	(48		)	(27		)	(21		)		—			(48		)
PT Smelting intercompany profit																	7			4			3			—		7
Gross profit	$	461		$	255		$	201			$	5		$	461		$	98		$	30		$	66		$	2	$	98

Copper sales (millions of recoverable pounds)	258			258													155			155
Gold sales (thousands of recoverable ounces)							505																260

Gross profit per pound of copper/per ounce of gold:	Gross profit per pound of copper/per ounce of gold:																Gross profit per pound of copper/per ounce of gold:

Revenues, excluding adjustments	$	3.05		$	3.05		$	1,219									$	2.74		$	2.74		$	1,186
Site production and delivery, before net noncash and other costs shown below	2.42			1.34			537										2.84			1.63			705
Gold and silver credits	(2.44		)	—			—										(2.09		)	—			—
Treatment charges	0.25			0.14			56										0.29			0.17			73
Export duties	0.16			0.09			36										0.14			0.08			35
Royalty on metals	0.21			0.12			45										0.16			0.09			40
Unit net cash costs	0.60			1.69			674										1.34			1.97			853
Depreciation and amortization	0.35			0.20			79										0.45			0.26			112
Noncash and other costs, net	0.11			0.06			24										0.04			0.02			9
Total unit costs	1.06			1.95			777										1.83			2.25			974
Revenue adjustments, primarily for pricing on
prior period open sales	(0.01		)	(0.01		)	(1		)
PT Smelting intercompany loss	(0.19		)	(0.10		)	(42		)
Revenue adjustments, primarily for pricing
on prior period open sales																	(0.32		)	(0.32		)	33
PT Smelting intercompany profit																	0.04			0.02			11
Gross profit per pound/ounce	$	1.79		$	0.99		$	399									$	0.63		$	0.19		$	256

Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization										Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	1,416		$	624		$	92									$	740		$	440		$	70
Treatment charges	(65		)	—			—										(45		)	—			—
Export duties	(42		)	—			—										(22		)	—			—
Royalty on metals	(52		)	—			—										(25		)	—			—
Noncash and other costs, net	—			28			—										—			6			—
Revenue adjustments, primarily for pricing on prior period open sales	(4		)	—			—										(41		)	—			—
PT Smelting intercompany loss	—			48			—
PT Smelting intercompany profit																	—			(7		)	—
Indonesia mining	1,253			700			92										607			439			70
Other mining & eliminations^b	3,453			2,180			346										3,046			2,187			335
Total mining	4,706			2,880			438										3,653			2,626			405
U.S. oil & gas operations	990			273			812			^c							500			283			3,634		^c
Corporate, other & eliminations	—			(1		)	3										—			3			4
As reported in FCX’s consolidated financial statements	$	5,696		$	3,152		$	1,253		^c							$	4,153		$	2,912		$	4,043	^c


a.	Includes silver sales of ~~889~~435 thousand ounces ($~~17.11~~16.16 per ounce average realized price).


b.	Represents the combined total for all other mining operations and the related eliminations, as presented in Note ~~10.~~9.


c.	Includes impairment of oil and gas properties of ~~$308 million~~. $3.1 billion.

7561

Table of Contents

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

Three Months Ended September 30, 2013
(In millions) By-Product Co-Product Method
Method Copper Gold Silver Total
Revenues, excluding adjustments $ 782
$ 782
$ 370
$ 16
^a
$ 1,168
Site production and delivery, before net noncash and other costs shown below 545
365
173
7
545
Gold and silver credits (391 ) —
—
—
—
Treatment charges 54
36
18
—
54
Royalty on metals 27
18
8
1
27
Net cash costs 235
419
199
8
626
Depreciation and amortization 60
40
19
1
60
Noncash and other costs, net 36
24
11
1
36
Total costs 331
483
229
10
722
Revenue adjustments, primarily for pricing on prior period open sales 19
19
4
1
24
PT Smelting intercompany loss (36 ) (24 ) (11 ) (1 ) (36 )
Gross profit $ 434
$ 294
$ 134
$ 6
$ 434

Copper sales (millions of recoverable pounds) 237
237

Gold sales (thousands of recoverable ounces) 278

Gross profit per pound of copper/per ounce of gold:

Revenues, excluding adjustments $ 3.30
$ 3.30
$ 1,330

Site production and delivery, before net noncash
and other costs shown below
2.30
1.54
621

Gold and silver credits (1.65 ) —
—

Treatment charges 0.23
0.15
62

Royalty on metals 0.11
0.08
31

Unit net cash costs 0.99
1.77
714

Depreciation and amortization 0.25
0.17
68

Noncash and other costs, net 0.15
0.10
40

Total unit costs 1.39
2.04
822

Revenue adjustments, primarily for pricing on
prior period open sales 0.08
0.08
17

PT Smelting intercompany loss (0.15 ) (0.10 ) (41 )
Gross profit per pound/ounce $ 1.84
$ 1.24
$ 484

Reconciliation to Amounts Reported
(In millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 1,168
$ 545
$ 60

Treatment charges (54 ) —
—

Royalty on metals (27 ) —
—

Noncash and other costs, net —
36
—

Revenue adjustments, primarily for pricing on prior period open sales 24
—
—

PT Smelting intercompany loss —
36
—

Indonesia mining 1,111
617
60

Other mining & eliminations^b
3,878
2,425
293

Total mining 4,989
3,042
353

U.S. oil & gas operations 1,176
288
563

Corporate, other & eliminations —
2
3

As reported in FCX’s consolidated financial statements $ 6,165
$ 3,332
$ 919


a.	~~Includes silver sales of~~ ~~761 thousand~~ ~~ounces ($21.46~~ ~~per ounce average realized price).~~


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

~~Table of Contents~~

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



Nine Months Ended September 30, 2014
Three Months Ended March 31, 2014
(In millions)	By-Product				Co-Product Method												By-Product				Co-Product Method
	Method				Copper			Gold			Silver			Total			Method				Copper				Gold		Silver^a		Total
Revenues, excluding adjustments	$	1,495			$	1,495		$	1,001		$	29	^a	$	2,525		$	331			$	331			$	211	$	7	$	549
Site production and delivery, before net noncash and other costs shown below	1,404				831			557			16			1,404			363				219				139		5		363
Gold and silver credits	(1,048		)		—			—			—			—			(235		)		—				—		—		—
Treatment charges	121				72			48			1			121			26				16				10		—		26
Export duties	42				25			16			1			42
Royalty on metals	79				47			31			1			79			13				8				5		—		13
Net cash costs	598				975			652			19			1,646			167				243				154		5		402
Depreciation and amortization	194				115			77			2			194			48				29				19		—		48
Noncash and other costs, net	200			^b	118			80			2			200			74			^b	45				28		1		74
Total costs	992				1,208			809			23			2,040			289				317				201		6		524
Revenue adjustments, primarily for pricing on prior period open sales	(55		)		(55		)	18			—			(37		)	(57		)		(57		)		17		—		(40		)
PT Smelting intercompany profit	10				6			4			—			10			54				33				21		—		54
Gross profit	$	458			$	238		$	214		$	6		$	458
Gross profit (loss)																	$	39			$	(10	)		$	48	$	1	$	39

Copper sales (millions of recoverable pounds)	484				484												109				109
Gold sales (thousands of recoverable ounces)								802																	162

Gross profit per pound of copper/per ounce of gold:	Gross profit per pound of copper/per ounce of gold:																Gross profit per pound of copper/per ounce of gold:

Revenues, excluding adjustments	$	3.09			$	3.09		$	1,248								$	3.04			$	3.04			$	1,299
Site production and delivery, before net noncash
and other costs shown below	2.90				1.72			694
Site production and delivery, before net noncash and other costs shown below																	3.33				2.01				859
Gold and silver credits	(2.16		)		—			—									(2.15		)		—				—
Treatment charges	0.25				0.15			60									0.24				0.15				62
Export duties	0.09				0.05			21
Royalty on metals	0.16				0.09			39									0.11				0.07				31
Unit net cash costs	1.24				2.01			814									1.53				2.23				952
Depreciation and amortization	0.40				0.24			96									0.44				0.26				114
Noncash and other costs, net	0.41			^b	0.25			98									0.67			^b	0.41				174
Total unit costs	2.05				2.50			1,008									2.64				2.90				1,240
Revenue adjustments, primarily for pricing on
prior period open sales	(0.11		)		(0.11		)	22
Revenue adjustments, primarily for pricing
on prior period open sales																	(0.53		)		(0.53		)		107
PT Smelting intercompany profit	0.02				0.01			5									0.49				0.30				129
Gross profit per pound/ounce	$	0.95			$	0.49		$	267
Gross profit (loss) per pound/ounce																	$	0.36			$	(0.09	)		$	295

Reconciliation to Amounts Reported
(In millions)	Revenues				Production and Delivery			Depreciation, Depletion and Amortization									Revenues				Production and Delivery				Depreciation, Depletion and Amortization
Totals presented above	$	2,525			$	1,404		$	194								$	549			$	363			$	48
Treatment charges	(121		)		—			—									(26		)		—				—
Export duties	(42		)		—			—
Royalty on metals	(79		)		—			—									(13		)		—				—
Noncash and other costs, net	—				200			—									—				74			^b	—
Revenue adjustments, primarily for pricing on prior period open sales	(37		)		—			—									(40		)		—				—
PT Smelting intercompany profit	—				(10		)	—									—				(54		)		—
Indonesia mining	2,246				1,594			194									470				383				48
Other mining & eliminations^c	10,470				6,466			984									3,254				2,043				298
Total mining	12,716				8,060			1,178									3,724				2,426				346
U.S. oil & gas operations	3,487				913			2,044		^d							1,261				311				616
Corporate, other & eliminations	—				(2		)	10									—				—				4
As reported in FCX’s consolidated financial statements	$	16,203			$	8,971		$	3,232	^d							$	4,985			$	2,737			$	966


a.	Includes silver sales of ~~1.6 million~~333 thousand ounces ($~~18.21~~20.13 per ounce average realized price).


b.	Includes ~~$143~~$53 million ($~~0.30~~0.49 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 9.



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 $308 million.~~

~~Table of Contents~~

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

Nine Months Ended September 30, 2013
(In millions) By-Product Co-Product Method
Method Copper Gold Silver Total
Revenues, excluding adjustments $ 1,938
$ 1,938
$ 864
$ 40
^a
$ 2,842
Site production and delivery, before net noncash and other costs shown below 1,623
1,107
493
23
1,623
Gold and silver credits (903 ) —
—
—
—
Treatment charges 135
92
41
2
135
Royalty on metals 74
50
23
1
74
Net cash costs 929
1,249
557
26
1,832
Depreciation and amortization 173
118
53
2
173
Noncash and other costs, net 123
84
37
2
123
Total costs 1,225
1,451
647
30
2,128
Revenue adjustments, primarily for pricing on prior period open sales 1
1
(1 ) —
—
PT Smelting intercompany profit 3
2
1
—
3
Gross profit $ 717
$ 490
$ 217
$ 10
$ 717

Copper sales (millions of recoverable pounds) 593
593

Gold sales (thousands of recoverable ounces) 620

Gross profit per pound of copper/per ounce of gold:

Revenues, excluding adjustments $ 3.27
$ 3.27
$ 1,393

Site production and delivery, before net noncash
and other costs shown below 2.74
1.87
795

Gold and silver credits (1.52 ) —
—

Treatment charges 0.23
0.16
67

Royalty on metals 0.12
0.08
36

Unit net cash costs 1.57
2.11
898

Depreciation and amortization 0.29
0.20
85

Noncash and other costs, net 0.21
0.14
60

Total unit costs 2.07
2.45
1,043

Revenue adjustments, primarily for pricing on
prior period open sales —
—
(2 )
PT Smelting intercompany profit 0.01
0.01
1

Gross profit per pound/ounce $ 1.21
$ 0.83
$ 349

Reconciliation to Amounts Reported
(In millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 2,842
$ 1,623
$ 173

Treatment charges (135 ) —
—

Royalty on metals (74 ) —
—

Noncash and other costs, net —
123
—

Revenue adjustments, primarily for pricing on prior period open sales —
—
—

PT Smelting intercompany profit —
(3 ) —

Indonesia mining 2,633
1,743
173

Other mining & eliminations^b
10,888
6,774
865

Total mining 13,521
8,517
1,038

U.S. oil & gas operations 1,512
377
732

Corporate, other & eliminations 3
10
8

As reported in FCX’s consolidated financial statements $ 15,036
$ 8,904
$ 1,778


a.	~~Includes silver sales of 1.8 million ounces ($22.55 per ounce average realized price).~~


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

7862

Table of Contents

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


Three Months Ended September 30, 2014
Three Months Ended March 31, 2015
(In millions)	By-Product			Co-Product Method								By-Product			Co-Product Method
	Method			Copper			Cobalt			Total		Method			Copper			Cobalt				Total
Revenues, excluding adjustments^a	$	350		$	350		$	82		$	432	$	354		$	354		$	72			$	426
Site production and delivery, before net noncash and other costs shown below	181			158			44			202		208			185			46				231
Cobalt credits^b	(64		)	—			—			—		(48		)	—			—				—
Royalty on metals	8			6			2			8		8			6			2				8
Net cash costs	125			164			46			210		168			191			48				239
Depreciation, depletion and amortization	58			49			9			58		73			63			10				73
Noncash and other costs, net	4			4			—			4		4			4			—				4
Total costs	187			217			55			272		245			258			58				316
Revenue adjustments, primarily for pricing on prior period open sales	1			1			3			4		(7		)	(7		)	(1		)		(8		)
Gross profit	$	164		$	134		$	30		$	164	$	102		$	89		$	13			$	102

Copper sales (millions of recoverable pounds)	112			112								133			133
Cobalt sales (millions of contained pounds)							8											8

Gross profit per pound of copper/cobalt:	Gross profit per pound of copper/cobalt:											Gross profit per pound of copper/cobalt:

Revenues, excluding adjustments^a	$	3.11		$	3.11		$	9.99				$	2.66		$	2.66		$	8.72
Site production and delivery, before net noncash and other costs shown below	1.61			1.40			5.32					1.57			1.39			5.61
Cobalt credits^b	(0.58		)	—			—					(0.37		)	—			—
Royalty on metals	0.07			0.06			0.18					0.06			0.05			0.14
Unit net cash costs	1.10			1.46			5.50					1.26			1.44			5.75
Depreciation, depletion and amortization	0.51			0.43			1.06					0.55			0.48			1.18
Noncash and other costs, net	0.05			0.04			0.10					0.03			0.02			0.06
Total unit costs	1.66			1.93			6.66					1.84			1.94			6.99
Revenue adjustments, primarily for pricing
on prior period open sales	0.01			0.01			0.39					(0.05		)	(0.05		)	(0.10		)
Gross profit per pound	$	1.46		$	1.19		$	3.72				$	0.77		$	0.67		$	1.63

Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization					Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	432		$	202		$	58				$	426		$	231		$	73
Royalty on metals	(8		)	—			—					(8		)	—			—
Noncash and other costs, net	—			4			—					—			4			—
Revenue adjustments, primarily for pricing on prior period open sales	4			—			—					(8		)	—			—
Africa mining	428			206			58					410			235			73
Other mining & eliminations^c	4,278			2,674			380					3,243			2,391			332
Total mining	4,706			2,880			438					3,653			2,626			405
U.S. oil & gas operations	990			273			812		^d			500			283			3,634			^d
Corporate, other & eliminations	—			(1		)	3					—			3			4
As reported in FCX’s consolidated financial statements	$	5,696		$	3,152		$	1,253	^d			$	4,153		$	2,912		$	4,043		^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 109.


d.	Includes impairment of oil and gas properties of $~~308 million~~3.1 billion.

7963

Table of Contents

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


Three Months Ended September 30, 2013
Three Months Ended March 31, 2014
(In millions)	By-Product			Co-Product Method							By-Product			Co-Product Method
	Method			Copper		Cobalt			Total		Method			Copper			Cobalt		Total
Revenues, excluding adjustments^a	$	374		$	374	$	53		$	427	$	258		$	258		$	74	$	332
Site production and delivery, before net noncash and other costs shown below	168			162		25			187		125			103			42		145
Cobalt credits^b	(32		)	—		—			—		(56		)	—			—		—
Royalty on metals	8			7		1			8		6			5			1		6
Net cash costs	144			169		26			195		75			108			43		151
Depreciation, depletion and amortization	64			56		8			64		51			45			6		51
Noncash and other costs, net	3			2		1			3		7			6			1		7
Total costs	211			227		35			262		133			159			50		209
Revenue adjustments, primarily for pricing on prior period open sales	3			3		(2		)	1		(1		)	(1		)	2		1
Gross profit	$	166		$	150	$	16		$	166	$	124		$	98		$	26	$	124

Copper sales (millions of recoverable pounds)	118			118							84			84
Cobalt sales (millions of contained pounds)						6											8

Gross profit per pound of copper/cobalt:	Gross profit per pound of copper/cobalt:										Gross profit per pound of copper/cobalt:

Revenues, excluding adjustments^a	$	3.19		$	3.19	$	8.57				$	3.07		$	3.07		$	9.21
Site production and delivery, before net noncash and other costs shown below	1.43			1.38		4.14					1.48			1.22			5.16
Cobalt credits^b	(0.27		)	—		—					(0.66		)	—			—
Royalty on metals	0.07			0.06		0.13					0.07			0.06			0.16
Unit net cash costs	1.23			1.44		4.27					0.89			1.28			5.32
Depreciation, depletion and amortization	0.55			0.48		1.37					0.61			0.53			0.80
Noncash and other costs, net	0.02			0.02		0.06					0.08			0.08			0.12
Total unit costs	1.80			1.94		5.70					1.58			1.89			6.24
Revenue adjustments, primarily for pricing
on prior period open sales	0.03			0.03		(0.27		)			(0.01		)	(0.01		)	0.24
Gross profit per pound	$	1.42		$	1.28	$	2.60				$	1.48		$	1.17		$	3.21

Reconciliation to Amounts Reported
(In millions)	Revenues			Production and Delivery		Depreciation, Depletion and Amortization					Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	427		$	187	$	64				$	332		$	145		$	51
Royalty on metals	(8		)	—		—					(6		)	—			—
Noncash and other costs, net	—			3		—					—			7			—
Revenue adjustments, primarily for pricing on prior period open sales	1			—		—					1			—			—
Africa mining	420			190		64					327			152			51
Other mining & eliminations^c	4,569			2,852		289					3,397			2,274			295
Total mining	4,989			3,042		353					3,724			2,426			346
U.S. oil & gas operations	1,176			288		563					1,261			311			616
Corporate, other & eliminations	—			2		3					—			—			4
As reported in FCX’s consolidated financial statements	$	6,165		$	3,332	$	919				$	4,985		$	2,737		$	966


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.

~~Table of Contents~~

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

Nine Months Ended September 30, 2014
(In millions) By-Product Co-Product Method
Method Copper Cobalt Total
Revenues, excluding adjustments^a
$ 972
$ 972
$ 222
$ 1,194
Site production and delivery, before net noncash and other costs shown below 477
420
120
540
Cobalt credits^b
(161 ) —
—
—
Royalty on metals 22
18
4
22
Net cash costs 338
438
124
562
Depreciation, depletion and amortization 172
148
24
172
Noncash and other costs, net 16
14
2
16
Total costs 526
600
150
750
Revenue adjustments, primarily for pricing on prior period open sales (1 ) (1 ) 2
1
Gross profit $ 445
$ 371
$ 74
$ 445

Copper sales (millions of recoverable pounds) 314
314

Cobalt sales (millions of contained pounds) 23

Gross profit per pound of copper/cobalt:

Revenues, excluding adjustments^a
$ 3.09
$ 3.09
$ 9.68

Site production and delivery, before net noncash
and other costs shown below 1.51
1.33
5.24

Cobalt credits^b
(0.51 ) —
—

Royalty on metals 0.07
0.06
0.16

Unit net cash costs 1.07
1.39
5.40

Depreciation, depletion and amortization 0.55
0.47
1.04

Noncash and other costs, net 0.05
0.05
0.10

Total unit costs 1.67
1.91
6.54

Revenue adjustments, primarily for pricing
on prior period open sales —
—
0.09

Gross profit per pound $ 1.42
$ 1.18
$ 3.23

Reconciliation to Amounts Reported
(In millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 1,194
$ 540
$ 172

Royalty on metals (22 ) —
—

Noncash and other costs, net —
16
—

Revenue adjustments, primarily for pricing on prior period open sales 1
—
—

Africa mining 1,173
556
172

Other mining & eliminations^c
11,543
7,504
1,006

Total mining 12,716
8,060
1,178

U.S. oil & gas operations 3,487
913
2,044
^d

Corporate, other & eliminations —
(2 ) 10

As reported in FCX’s consolidated financial statements $ 16,203
$ 8,971
$ 3,232
^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~~ ~~$308 million~~9.

~~Table of Contents~~

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

Nine Months Ended September 30, 2013
(In millions) By-Product Co-Product Method
Method Copper Cobalt Total
Revenues, excluding adjustments^a
$ 1,101
$ 1,101
$ 140
$ 1,241
Site production and delivery, before net noncash and other costs shown below 488
465
76
541
Cobalt credits^b
(90 ) —
—
—
Royalty on metals 23
20
3
23
Net cash costs 421
485
79
564
Depreciation, depletion and amortization 179
163
16
179
Noncash and other costs, net 19
17
2
19
Total costs 619
665
97
762
Revenue adjustments, primarily for pricing on prior period open sales 2
2
3
5
Gross profit $ 484
$ 438
$ 46
$ 484

Copper sales (millions of recoverable pounds) 342
342

Cobalt sales (millions of contained pounds) 17

Gross profit per pound of copper/cobalt:

Revenues, excluding adjustments^a
$ 3.22
$ 3.22
$ 8.10

Site production and delivery, before net noncash
and other costs shown below 1.43
1.36
4.40

Cobalt credits^b
(0.26 ) —
—

Royalty on metals 0.06
0.06
0.14

Unit net cash costs 1.23
1.42
4.54

Depreciation, depletion and amortization 0.52
0.48
0.97

Noncash and other costs, net 0.06
0.05
0.09

Total unit costs 1.81
1.95
5.60

Revenue adjustments, primarily for pricing
on prior period open sales 0.01
0.01
0.14

Gross profit per pound $ 1.42
$ 1.28
$ 2.64

Reconciliation to Amounts Reported
(In millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 1,241
$ 541
$ 179

Royalty on metals (23 ) —
—

Noncash and other costs, net —
19
—

Revenue adjustments, primarily for pricing on prior period open sales 5
—
—

Africa mining 1,223
560
179

Other mining & eliminations^c
12,298
7,957
859

Total mining 13,521
8,517
1,038

U.S. oil & gas operations 1,512
377
732

Corporate, other & eliminations 3
10
8

As reported in FCX’s consolidated financial statements $ 15,036
$ 8,904
$ 1,778



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.

8264

Table of Contents

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


	Three Months Ended September 30,									Three Months Ended March 31,
(In millions)	2014			2013						2015			2014
Revenues, excluding adjustments^a	$	184		$	132					$	124		$	137

Site production and delivery, before net noncash and other costs shown below	83			75						81			75
Treatment charges and other	11			11						11			11
Net cash costs	94			86						92			86
Depreciation, depletion and amortization	25			21						26			22
Noncash and other costs, net	3			7						2			1
Total costs	122			114						120			109
Gross profit	$	62		$	18					$	4		$	28

Molybdenum sales (millions of recoverable pounds)^a	13			12						13			13

Gross profit per pound of molybdenum:	Gross profit per pound of molybdenum:									Gross profit per pound of molybdenum:

Revenues, excluding adjustments^a	$	13.93		$	10.92					$	9.68		$	10.76

Site production and delivery, before net noncash and other costs shown below	6.29			6.27						6.33			5.87
Treatment charges and other	0.83			0.88						0.84			0.84
Unit net cash costs	7.12			7.15						7.17			6.71
Depreciation, depletion and amortization	1.89			1.71						2.03			1.75
Noncash and other costs, net	0.21			0.54						0.14			0.11
Total unit costs	9.22			9.40						9.34			8.57
Gross profit per pound	$	4.71		$	1.52					$	0.34		$	2.19

Reconciliation to Amounts Reported
(In millions)
Three Months Ended September 30, 2014	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Three Months Ended March 31, 2015										Revenues			Production and Delivery		Depreciation, Depletion and Amortization
Totals presented above	$	184		$	83		$	25		$	124		$	81	$	26
Treatment charges and other	(11		)	—			—			(11		)	—		—
Noncash and other costs, net	—			3			—			—			2		—
Molybdenum mines	173			86			25			113			83		26
Other mining & eliminations^b	4,533			2,794			413			3,540			2,543		379
Total mining	4,706			2,880			438			3,653			2,626		405
U.S. oil & gas operations	990			273			812		^c	500			283		3,634		^c
Corporate, other & eliminations	—			(1		)	3			—			3		4
As reported in FCX’s consolidated financial statements	$	5,696		$	3,152		$	1,253	^c	$	4,153		$	2,912	$	4,043	^c

Three Months Ended September 30, 2013
Three Months Ended March 31, 2014
Totals presented above	$	132		$	75		$	21		$	137		$	75	$	22
Treatment charges and other	(11		)	—			—			(11		)	—		—
Noncash and other costs, net	—			7			—			—			1		—
Molybdenum mines	121			82			21			126			76		22
Other mining & eliminations^b	4,868			2,960			332			3,598			2,350		324
Total mining	4,989			3,042			353			3,724			2,426		346
U.S. oil & gas operations	1,176			288			563			1,261			311		616
Corporate, other & eliminations	—			2			3			—			—		4
As reported in FCX’s consolidated financial statements	$	6,165		$	3,332		$	919		$	4,985		$	2,737	$	966


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;~~third parties; as a result, our consolidated average realized price per pound of molybdenum will differ from the amounts reported in this table.


b.	Represents the combined total for all other mining operations and the related eliminations, as presented in Note 10.9. Also includes amounts associated with our molybdenum sales company, which includes sales of molybdenum produced by the ~~molybdenum~~Molybdenum mines and by certain of the North and South America copper mines.


c.	Includes impairment of oil and gas properties of ~~$308 million~~. $3.1 billion.

~~Table of Contents~~

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

Nine Months Ended September 30,
(In millions) 2014 2013
Revenues, excluding adjustments^a
$ 502
$ 443

Site production and delivery, before net noncash
and other costs shown below
237
229

Treatment charges and other 33
35

Net cash costs 270
264

Depreciation, depletion and amortization 71
62

Noncash and other costs, net 6
11

Total costs 347
337

Gross profit $ 155
$ 106

Molybdenum sales (millions of recoverable pounds)^a
40
37

Gross profit per pound of molybdenum:

Revenues, excluding adjustments^a
$ 12.56
$ 11.87

Site production and delivery, before net noncash
and other costs shown below
5.92
6.15

Treatment charges and other 0.84
0.93

Unit net cash costs 6.76
7.08

Depreciation, depletion and amortization 1.77
1.66

Noncash and other costs, net 0.14
0.29

Total unit costs 8.67
9.03

Gross profit per pound $ 3.89
$ 2.84

Reconciliation to Amounts Reported
(In millions)
Nine Months Ended September 30, 2014 Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 502
$ 237
$ 71

Treatment charges and other (33 ) —
—

Noncash and other costs, net —
6
—

Molybdenum mines 469
243
71

Other mining & eliminations^b
12,247
7,817
1,107

Total mining 12,716
8,060
1,178

U.S. oil & gas operations 3,487
913
2,044
^c
Corporate, other & eliminations —
(2 ) 10

As reported in FCX’s consolidated financial statements $ 16,203
$ 8,971
$ 3,232
^c

Nine Months Ended September 30, 2013
Totals presented above $ 443
$ 229
$ 62

Treatment charges and other (35 ) —
—

Noncash and other costs,net —
11
—

Molybdenum mines 408
240
62

Other mining & eliminations^b
13,113
8,277
976

Total mining 13,521
8,517
1,038

U.S. oil & gas operations 1,512
377
732

Corporate, other & eliminations 3
10
8

As reported in FCX’s consolidated financial statements $ 15,036
$ 8,904
$ 1,778



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.	~~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.~~


c.	~~Includes impairment of oil and gas properties of~~ ~~$308 million~~.

8465

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


Three Months Ended September 30, 2014
Three Months Ended March 31, 2015

(In millions)	Oil			Natural Gas			NGLs		Total U.S. Oil & Gas			Oil			Natural Gas		NGLs		Total U.S. Oil & Gas
Oil and gas revenues before derivatives	$	821		$	81		$	23	$	925		$	373		$	62	$	12	$	447
Realized cash losses on derivative contracts	(58		)	—			—		(58		)
Realized cash gains on derivative contracts												100			—		—		100
Realized revenues	$	763		$	81		$	23	867			$	473		$	62	$	12	547
Less: cash production costs									263										254
Cash operating margin									604										293
Less: depreciation, depletion and amortization									504										530
Less: impairment of oil and gas properties									308										3,104
Less: accretion and other costs									10										29
Plus: net noncash mark-to-market gains on derivative contracts									122
Plus: net noncash mark-to-market losses on derivative contracts																			(48		)
Plus: other net adjustments									1										1
Gross loss									$	(95	)								$	(3,417	)

Oil (MMBbls)	8.6											8.4
Gas (Bcf)				20.2											21.8
NGLs (MMBbls)							0.6										0.5
Oil Equivalents (MMBOE)									12.5										12.5

	Oil (per barrel)			Natural Gas (per MMBtu)			NGLs (per barrel)		Per BOE			Oil (per barrel)			Natural Gas (per MMBtu)		NGLs (per barrel)		Per BOE
Oil and gas revenues before derivatives	$	95.35		$	4.00		$	39.69	$	73.70		$	44.54		$	2.86	$	23.06	$	35.71
Realized cash (losses) gains on derivative contracts	(6.77		)	0.02			—		(4.62		)
Realized cash gains on derivative contracts												11.97			—		—		8.00
Realized revenues	$	88.58		$	4.02		$	39.69	69.08			$	56.51		$	2.86	$	23.06	43.71
Less: cash production costs									20.93										20.26
Cash operating margin									48.15										23.45
Less: depreciation, depletion and amortization									40.12										42.30
Less: impairment of oil and gas properties									24.59										247.84
Less: accretion and other costs									0.85										2.31
Plus: net noncash mark-to-market gains on derivative contracts									9.73
Plus: net noncash mark-to-market losses on derivative contracts																			(3.87		)
Plus: other net adjustments									0.09										0.06
Gross loss									$	(7.59	)								$	(272.81	)

Reconciliation to Amounts Reported
(In Millions)	Revenues			Production and Delivery			Depreciation, Depletion and Amortization
(In millions)												Revenues			Production and Delivery		Depreciation, Depletion and Amortization
Totals presented above	$	925		$	263		$	504				$	447		$	254	$	530
Realized cash losses on derivative contracts	(58		)	—			—
Net noncash mark-to-market gains on derivative contracts	122			—			—
Realized cash gains on derivative contracts												100			—		—
Net noncash mark-to-market losses on derivative contracts												(48		)	—		—
Accretion and other costs	—			10			—					—			29		—
Impairment of oil and gas properties	—			—			308					—			—		3,104
Other net adjustments	1			—			—					1			—		—
U.S. oil & gas operations	990			273			812					500			283		3,634
Total mining^a	4,706			2,880			438					3,653			2,626		405
Corporate, other & eliminations	—			(1		)	3					—			3		4
As reported in FCX's consolidated financial statements	$	5,696		$	3,152		$	1,253				$	4,153		$	2,912	$	4,043


a.	Represents the combined total for mining operations and the related eliminations, as presented in Note ~~10.~~9.

8566

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

Three Months Ended September 30, 2013
Three Months Ended March 31, 2014
								Total											Total
				Natural				U.S. Oil						Natural					U.S. Oil
(In Millions)	Oil			Gas		NGLs		& Gas
(In millions)											Oil			Gas			NGLs		& Gas
Oil and gas revenues before derivatives	$	1,220		$	86	$	39	$	1,345		$	1,162		$	98		$	50	$	1,310
Realized cash (losses) gains on derivative contracts	(19		)	7		—		(12		)
Realized cash losses on derivative contracts											(58		)	(7		)	—		(65		)
Realized revenues	$	1,201		$	93	$	39	1,333			$	1,104		$	91		$	50	1,245
Less: cash production costs								277											298			^a
Cash operating margin								1,056											947
Less: depreciation, depletion and amortization								563											616
Less: accretion and other costs								11											13
Plus: net noncash mark-to-market losses on derivative contracts								(158		)
Plus: net noncash mark-to-market gains on derivative contracts																			15
Plus: other net adjustments								1											1
Gross profit								$	325										$	334

Oil (MMBbls)	11.5										11.8
Gas (Bcf)				23.5										19.5
NGLs (MMBbls)						1.0											1.1
Oil Equivalents (MMBOE)								16.5											16.1

	Oil			Natural Gas		NGLs					Oil			Natural Gas			NGLs
	(per barrel)			(per MMBtu)		(per barrel)		Per BOE			(per barrel)			(per MMBtu)			(per barrel)		Per BOE
Oil and gas revenues before derivatives	$	106.00		$	3.67	$	37.16	$	81.67		$	98.62		$	5.05		$	45.47	$	81.23
Realized cash (losses) gains on derivative contracts	(1.67		)	0.30		—		(0.74		)
Realized cash losses on derivative contracts											(4.86		)	(0.38		)	—		(4.01		)
Realized revenues	$	104.33		$	3.97	$	37.16	80.93			$	93.76		$	4.67		$	45.47	77.22
Less: cash production costs								16.80											18.51			^a
Cash operating margin								64.13											58.71
Less: depreciation, depletion and amortization								34.15											38.21
Less: accretion and other costs								0.70											0.78
Plus: net noncash mark-to-market losses on derivative contracts								(9.58		)
Plus: net noncash mark-to-market gains on derivative contracts																			0.90
Plus: other net adjustments								0.06											0.04
Gross profit								$	19.76										$	20.66

Reconciliation to Amounts Reported	Reconciliation to Amounts Reported										Reconciliation to Amounts Reported
(In Millions)	Revenues			Production and Delivery		Depreciation, Depletion and Amortization
(In millions)											Revenues			Production and Delivery			Depreciation, Depletion and Amortization
Totals presented above	$	1,345		$	277	$	563				$	1,310		$	298		$	616
Realized cash losses on derivative contracts	(12		)	—		—					(65		)	—			—
Net noncash mark-to-market losses on derivative contracts	(158		)	—		—
Net noncash mark-to-market gains on derivative contracts											15			—			—
Accretion and other costs	—			11		—					—			13			—
Other net adjustments	1			—		—					1			—			—
U.S. oil & gas operations	1,176			288		563					1,261			311			616
Total mining^a	4,989			3,042		353
Total mining^b											3,724			2,426			346
Corporate, other & eliminations	—			2		3					—			—			4
As reported in FCX's consolidated financial statements	$	6,165		$	3,332	$	919				$	4,985		$	2,737		$	966

a.Following is a reconciliation of FM O&G's first-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	$	298	16.1	$	18.51
Less: Eagle Ford	60		4.7	12.75
	$	238	11.4	$	20.89


a.b.	Represents the combined total for mining operations and the related eliminations, as presented in Note 109.

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

Nine Months Ended September 30, 2014

(In millions) Oil Natural Gas NGLs
Total
U.S. Oil & Gas

Oil and gas revenues before derivatives $ 3,155
$ 275
$ 111
$ 3,541

Realized cash losses on derivative contracts (173 ) (13 ) —
(186 )
Realized revenues $ 2,982
$ 262
$ 111
3,355

Less: cash production costs 875

Cash operating margin 2,480

Less: depreciation, depletion and amortization 1,736

Less: impairment of oil and gas properties 308

Less: accretion and other costs 38

Plus: net noncash mark-to-market gains on derivative
contracts
130

Plus: other net adjustments 2

Gross profit $ 530

Oil (MMBbls) 32.1

Gas (Bcf) 59.9

NGLs (MMBbls) 2.7

Oil Equivalents (MMBOE) 44.7

Oil
(per barrel) Natural Gas
(per MMBtu) NGLs
(per barrel) Per BOE
Oil and gas revenues before derivatives $ 98.41
$ 4.58
$ 41.77
$ 79.20

Realized cash losses on derivative contracts (5.41 ) (0.21 ) —
(4.16 )
Realized revenues $ 93.00
$ 4.37
$ 41.77
75.04

Less: cash production costs 19.57

Cash operating margin 55.47

Less: depreciation, depletion and amortization 38.81

Less: impairment of oil and gas properties 6.90

Less: accretion and other costs 0.86

Plus: net noncash mark-to-market gains on derivative
contracts
2.90

Plus: other net adjustments 0.05

Gross profit $ 11.85

Reconciliation to Amounts Reported
(In Millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 3,541
$ 875
$ 1,736

Realized cash losses on derivative contracts (186 ) —
—

Net noncash mark-to-market gains on derivative contracts

130
—
—

Accretion and other costs —
38
—

Impairment of oil and gas properties —
—
308

Other net adjustments 2
—
—

U.S. oil & gas operations 3,487
913
2,044

Total mining^a
12,716
8,060
1,178

Corporate, other & eliminations —
(2 ) 10

As reported in FCX's consolidated financial statements $ 16,203
$ 8,971
$ 3,232


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

~~Table of Contents~~

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

Four months from June 1, 2013 to September 30, 2013

(In millions) Oil Natural Gas NGLs
Total
U.S. Oil & Gas

Oil and gas revenues before derivatives $ 1,550
$ 116
$ 50
$ 1,716

Realized cash (losses) gains on derivative contracts (18 ) 7
—
(11 )
Realized revenues $ 1,532
$ 123
$ 50
1,705

Less: cash production costs 360

Cash operating margin 1,345

Less: depreciation, depletion and amortization 732

Less: accretion and other costs 17

Plus: net noncash mark-to-market losses on derivative contracts (194 )
Plus: other net adjustments 1

Gross profit $ 403

Oil (MMBbls) 14.9

Gas (Bcf) 31.3

NGLs (MMBbls) 1.3

Oil Equivalents (MMBOE) 21.5

Oil
(per barrel) Natural Gas
(per MMBtu) NGLs
(per barrel) Per BOE
Oil and gas revenues before derivatives $ 103.96
$ 3.70
$ 36.70
$ 79.89

Realized cash (losses) gains on derivative contracts (1.20 ) 0.24
—
(0.49 )
Realized revenues $ 102.76
$ 3.94
$ 36.70
79.40

Less: cash production costs 16.76

Cash operating margin 62.64

Less: depreciation, depletion and amortization 34.07

Less: accretion and other costs 0.80

Plus: net noncash mark-to-market losses on derivative contracts (9.04 )
Plus: other net adjustments 0.04

Gross profit $ 18.77

Reconciliation to Amounts Reported for the Nine Months Ended September 30, 2013
(In Millions) Revenues Production and Delivery Depreciation, Depletion and Amortization
Totals presented above $ 1,716
$ 360
$ 732

Realized cash losses on derivative contracts (11 ) —
—

Net noncash mark-to-market losses on derivative contracts (194 ) —
—

Accretion and other costs —
17
—

Other net adjustments 1
—
—

U.S. oil & gas operations 1,512
377
732

Total mining^a
13,521
8,517
1,038

Corporate, other & eliminations 3
10
8

As reported in FCX's consolidated financial statements $ 15,036
$ 8,904
$ 1,778


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

~~Table of Contents~~

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,~~rates; production and sales ~~volumes,~~volumes; unit net cash ~~costs,~~costs; cash production costs per ~~BOE,~~BOE; operating cash ~~flows,~~flows; capital ~~expenditures,~~expenditures; exploration efforts and ~~results,~~results; development and production activities and ~~costs, liquidity,~~costs; liquidity; tax ~~rates,~~rates; the impact of copper, gold, molybdenum, cobalt, crude oil and natural gas price ~~changes,~~changes; the impact of derivative ~~positions,~~positions; the impact of deferred intercompany profits on ~~earnings,~~earnings; reserve ~~estimates, and~~estimates; future dividend ~~payments,~~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 that our actual results may differ materially from those anticipated, projected or assumed in the forward-looking statements. 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, oil and gas, mine sequencing, production rates, industry risks, regulatory changes, political risks, drilling results, potential additional oil and gas property impairment charges, the outcome of negotiations with the Indonesian government regarding an amendment to PT-FI's COW, PT-FI's ability to obtain renewal of its export license after July 25, 2015, the potential effects of violence in Indonesia, the ability of the parties to satisfy customary closing conditions and consummate the pending sale of our ownership interest in the Candelaria/Ojos del Salado copper mining operations and supporting infrastructure, the resolution of administrative disputes in the ~~Democratic Republic of Congo,~~DRC, weather- and climate-related risks, labor relations, environmental risks, litigation results ~~currency translation risks~~ and other factors described in more detail ~~under the heading~~in Part I, Item 1A. “Risk Factors” inof our annual report on Form 10-K for the year ended December 31, ~~2013~~2014, ~~and in Part II Item 1A of this report filed with the SEC~~ as updated by our subsequent filings with the SEC.

Investors are cautioned that many of the assumptions on which our forward-looking statements are based are likely to change after our 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 or may not be able to control. Further, we may make changes to our business plans that could or will affect our results. We caution investors that 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.

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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 ~~September 30, 2014~~March 31, 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, ~~2013~~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 ~~September 30, 2014~~March 31, 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 ~~September 30, 2014~~March 31, 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 ~~September 30, 2014~~March 31, 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 ~~September 30, 2014~~March 31, 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 ~~(FMC - formerly Freeport-McMoRan 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, ~~2013~~2014, as updated in Note 98 to the financial statements included in ~~our~~this quarterly report on Form 10-Q for the quarter ended March 31, ~~2014,~~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.

~~The risk factor~~ “Because our Grasberg minerals district is our most significant operating asset, our business may continue to be adversely affected by political, economic and social uncertainties and security risks in Indonesia”, ~~which was included in FCX’s annual report on Form 10-K for the year ended December 31, 2013, is amended to add the following:~~

PT Freeport Indonesia (PT-FI) has been engaged in discussions with officials of the Indonesian government since 2012 regarding various provisions of its Contract of Work (COW). The government has sought to modify existing mining contracts, including PT-FI’s COW, to address provisions of Indonesia’s 2009 mining law and subsequent regulations, including with respect to the size of contract concessions, government revenues, domestic processing of minerals, divestment, provision of local services, conversion from a COW to a licensing framework for extension periods, and a requirement that extensions may be applied for only within two years prior to a COW’s expiration.

In January 2014, the Indonesian government published regulations providing that holders of contracts of work with existing processing facilities in Indonesia may continue to export product through January 12, 2017, but established new requirements for the continued export of copper concentrates, including the imposition of a progressive export duty on copper concentrates in the amount of 25 percent in 2014, rising to 60 percent by mid-2016. Regulations published in 2014 require companies to obtain permits issued at six-month intervals to allow exports of products, including copper concentrates.

~~Table of Contents~~

Despite PT-FI’s rights under its 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 until late-July 2014.

On July 25, 2014, PT-FI and the Indonesian government entered into a Memorandum of Understanding (MOU) under which PT-FI and the government agreed to negotiate an amended COW to address provisions related to the size of PT-FI’s concession area, royalties and taxes, domestic processing and refining, divestment, local content, and continuation of operations post-2021. Execution of the MOU enabled the resumption of concentrate exports, which began in August 2014.

Effective with the signing of the MOU, PT-FI agreed to provide a $115 million assurance bond to support its commitment for smelter development, pay higher royalties on copper, gold and silver and pay export duties set forth in a new regulation issued by the Indonesian government on July 25, 2014.

Among other items, MOU provisions to be addressed in the negotiation of an amended COW include provisions for the development of new copper smelting and refining capacity in Indonesia, which will take into consideration an equitable sharing of costs between PT-FI (and any partners in the project) and the Indonesian government through fiscal incentives and PT-FI’s requirement for assurance of fiscal and legal certainty of its operational rights, provisions for divestment to the Indonesian government and/or Indonesian nationals of up to a 30 percent interest (an additional 20.64 percent interest) in PT-FI at fair value, and continuation of operations from 2022 through 2041. The parties agreed to complete negotiations within a six month period. Under the MOU, no terms of the COW other than those relating to the export duties, smelter bond and royalties described above will be changed until the completion of an amended COW.

The MOU also provides that negotiations for an amended COW will take into consideration PT-FI’s need for assurance of legal and fiscal terms post-2021 for PT-FI to continue with its large-scale investment program for the development of its underground reserves.

The revisions to the COW are expected to result in additional costs for our Indonesian operations. We cannot predict whether we will be successful in reaching a satisfactory agreement on the terms of our long-term mining rights. If we are unable to reach agreement with the government on our long-term rights, we may be required to reduce or defer investments in our underground development projects, which would negatively impact future production and reserves. In addition, we are required to apply for renewal of export permits at six-month intervals and cannot predict if such permits will be granted on a timely basis or whether we will be permitted to export concentrates after January 12, 2017.

In October 2014, Joko “Jokowi” Widodo took office as the president of Indonesia, elected in July 2014, to serve for a five-year term. PT-FI’s COW negotiations are taking place during a period of transition for the Indonesian national government, and we cannot predict what impact the transition will have on the progress or outcome of the negotiations.

On September 27, 2014, four Grasberg workers were fatally injured when a haul truck collided with a light vehicle near the Grasberg open-pit operations. Operations in the Grasberg open pit were temporarily suspended in order to complete internal and government investigations regarding the accident. On October 13, 2014, Indonesian authorities approved the resumption of operations after issuing recommendations on traffic control procedures that have been implemented by PT-FI. Workforce attendance in several operating areas reflect normal levels. However, a large percentage of Grasberg open-pit operators have not reported to their scheduled shifts resulting in reduced production from the open pit during October. These actions conflict with agreed policies and processes in the Collective Labor Agreement (CLA) and PT-FI is working with union leadership regarding this work stoppage to resume normal operations as soon as possible.

On October 27, 2014, PT-FI received notice from union leadership indicating its intention to conduct a 30-day strike beginning on November 6. Following constructive dialogue between PT-FI and union leadership, union leadership advised PT-FI on October 31, 2014, that all strike actions had been canceled.

~~Except as described above, there~~There have been no material changes to our risk factors ~~as discussed in~~during the three-month period ended March 31, 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, ~~2013~~2014.

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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 ~~September 30, 2014~~March 31, 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 Programs^a	(d) Maximum Number of Shares That May Yet Be Purchased Under the Plans or Programs^a
Period	(a) Total Number of Shares Purchased	(b) Average Price Paid Per Share
~~July~~January 1-31, ~~2014~~2015	—	$	—	—	23,685,500
~~August 1-31, 2014~~February 1-28, 2015	—	$	—	—	23,685,500
~~September 1-30, 2014~~March 1-31, 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.

~~Table of Contents~~


~~Item 5.~~	~~Other Information.~~

~~(a) Completion of Disposition of Assets; Pro Forma Financial Information.~~

The following unaudited pro forma condensed financial statements (the Pro Forma Financial Statements) have been prepared to reflect the sale of FCX's 80 percent ownership interests in the Candelaria and Ojos del Salado mining operations to Lundin Mining Corporation (Lundin), which was completed on November 3, 2014 (the sale transaction). For additional information, see Part I, Item II "Operations - South America Mining" in this report on Form 10-Q.

The unaudited pro forma condensed balance sheet is presented as if the sale transaction had occurred on September 30, 2014. The unaudited pro forma condensed statements of income for the year ended December 31, 2013, and the nine months ended September 30, 2014, are presented as if the sale transaction had occurred on January 1, 2013. The historical consolidated financial information has been adjusted to reflect factually supportable items that are directly attributable to the sale transaction and, with respect to the statements of income only, expected to have a continuing impact on the combined results.

The Pro Forma Financial Statements have been prepared using the sale of assets method of accounting under accounting principles generally accepted in the United States (U.S.). The sale transaction is subject to closing adjustments that have not yet been finalized. Accordingly, the pro forma adjustments are preliminary, and have been made solely for the purpose of providing Pro Forma Financial Statements as required by the U.S. Securities and Exchange Commission (SEC) rules. Differences between these preliminary estimates and the final sale accounting may be material.

The Pro Forma Financial Statements are provided for informational purposes only and do not purport to represent what the actual consolidated results of operations or the consolidated financial position of FCX would have been had the sale transaction occurred on the dates assumed, nor are they necessarily indicative of future consolidated results of operations or consolidated financial position. The Pro Forma Financial Statements should be read in conjunction with (i) the accompanying notes to the Pro Forma Financial Statements; (ii) the audited consolidated financial statements and accompanying notes of FCX contained in its annual report on Form 10-K for the year ended December 31, 2013; and (iii) the unaudited condensed consolidated financial statements and accompanying notes of FCX contained in this quarterly report on Form 10-Q for the quarterly period ended September 30, 2014.

Affiliates of FCX own an effective 56 percent interest in Tenke Fungurume Mining S.A.R.L. (TFM), with the remaining ownership interests held by affiliates of Lundin (an effective 24 percent interest) and La Generale des Carrieres et des Mines (Gecamines), which is wholly owned by the government of the Democratic Republic of Congo (DRC) (a 20 percent non-dilutable interest). TFM holds copper and cobalt mining concessions in the Katanga province of the DRC, and affiliates of FCX operate the mine. Affiliates of FCX also own and operate a cobalt chemical refinery in Kokkola, Finland, and related sales and marketing business, through a joint venture with affiliates of Lundin and Gecamines, with ownership interests similar to the interests in TFM. The consideration in the sale transaction was determined through arms-length bargaining.

~~Table of Contents~~

~~FREEPORT-McMoRan INC.~~

~~UNAUDITED PRO FORMA CONDENSED BALANCE SHEET~~

~~AT SEPTEMBER 30, 2014~~

~~(in millions)~~

Historical Adjustments
FCX Candelaria/Ojos del Salado
Pro Forma⁽¹⁾

Sale⁽²⁾
Pro Forma
ASSETS
Current assets:
    Cash and cash equivalents $ 658
$ 121
$ —
$ 1,852
A $ 2,389
    Trade and other accounts receivable 2,307
197
94
—
2,204
    Inventories 5,489
124
—
—
5,365
    Other current assets 577
7
(1 ) —
569
         Total current assets 9,031
449
93
1,852
10,527
Property, plant, equipment and development costs, net 26,304
663
—
—
25,641
Oil and natural gas properties, net - full cost method 22,337
—
—
—
22,337
Long-term mill and leach stockpiles 2,569
438
—
—
2,131
Goodwill and other assets 3,735
59
(19 ) 1
3,658
Total assets $ 63,976
$ 1,609
$ 74
$ 1,853
$ 64,294

LIABILITIES AND EQUITY
Current liabilities $ 6,343
$ 138
$ 94
$ 405
A $ 6,704
Long-term debt, less current portion 17,975
—
—
—
17,975
Deferred income taxes 7,559
—
—
(179 ) B 7,380
Reclamation and environmental obligations, less current portion 3,654
36
—
—
3,618
Other liabilities 1,730
56
3
—
1,677
        Total liabilities 37,261
230
97
226
37,354

Redeemable noncontrolling interest 749
—
—
—
749

Total stockholders' equity 21,591
1,140
(23 ) 1,627
22,055
Noncontrolling interests 4,375
239
—
—
4,136
        Total equity 25,966
1,379
(23 ) 1,627
26,191
Total liabilities and equity $ 63,976
$ 1,609
$ 74
$ 1,853
$ 64,294

~~NOTES TO THE UNAUDITED PRO FORMA CONDENSED BALANCE SHEET~~


~~(1)~~	~~Pro Forma Adjustments~~

Pro forma adjustments reflect reversal of the elimination of intercompany balances (such as intercompany receivables/payables) primarily between the Candelaria and Ojos del Salado mining complex (Candelaria/Ojos) and Atlantic Copper, FCX's wholly owned copper smelter.


~~(2)~~	~~Sale Adjustments~~


A.	~~Represents adjusted gross cash proceeds of $1.85 billion from the sale of Candelaria/Ojos and $405 million for income taxes related to the sale of Candelaria/Ojos.~~


B.	~~Adjustment reflects the reversal of $179 million of deferred withholding taxes associated with FCX's tax liability for its share of undistributed earnings from Candelaria/Ojos.~~

~~Table of Contents~~

~~FREEPORT-McMoRan INC.~~

~~UNAUDITED PRO FORMA CONDENSED STATEMENTS OF INCOME~~

~~(in millions, except per share amounts)~~

Year Ended December 31, 2013
Historical
FCX Candelaria/Ojos del Salado
Pro Forma Adjustments⁽¹⁾
Pro Forma

Revenues $ 20,921
$ 1,518
$ 274
$ 19,677
Total operating costs and expenses 15,570
834
222
14,958
Operating income 5,351
684
52
4,719
Interest expense and other, net (438 ) 5
—
(443 )
Income before taxes and equity in affiliated companies' net earnings 4,913
689
52
4,276
Provision for income taxes (1,475 ) (252 ) (18 ) (1,241 )
Equity in affiliated companies' net earnings 3
—
—
3
Net income 3,441
437
34
3,038
Net income and preferred dividends attributable to noncontrolling interests (783 ) (96 ) (8 ) (695 )
Net income attributable to FCX common stockholders $ 2,658
$ 341
$ 26
$ 2,343

Net income per share attributable to FCX common stockholders:
Basic $ 2.65
$ 2.34
Diluted $ 2.64
$ 2.33
Weighted-average common shares outstanding:
Basic 1,002
1,002
Diluted 1,006
1,006

Nine Months Ended September 30, 2014
Historical
FCX Candelaria/Ojos del Salado
Pro Forma Adjustments⁽¹⁾
Pro Forma

Revenues $ 16,203
$ 769
$ 238
$ 15,672
Total operating costs and expenses 12,807
541
214
12,480
Operating income 3,396
228
24
3,192
Interest expense and other, net (372 ) 8
—
(380 )
Income before taxes and equity in affiliated companies' net earnings 3,024
236
24
2,812
Provision for income taxes (1,034 ) (80 ) (8 ) (962 )
Equity in affiliated companies' net earnings —
—
—
—
Net income 1,990
156
16
1,850
Net income and preferred dividends attributable to noncontrolling interests (446 ) (24 ) (3 ) (425 )
Net income attributable to FCX common stockholders $ 1,544
$ 132
$ 13
$ 1,425

Net income per share attributable to FCX common stockholders:
Basic $ 1.48
$ 1.37
Diluted $ 1.47
$ 1.36
Weighted-average common shares outstanding:
Basic 1,039
1,039
Diluted 1,045
1,045

~~Table of Contents~~

~~NOTE TO THE UNAUDITED PRO FORMA CONDENSED STATEMENTS OF INCOME~~


~~(1)~~	~~Pro Forma Adjustments~~

Candelaria/Ojos revenues include sales to Atlantic Copper that are eliminated in FCX's consolidated results. The pro forma adjustments primarily reflect recognition of these previously eliminated intercompany sales and purchases.


Item 6.	Exhibits.

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

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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: ~~November 7, 2014~~May 8, 2015

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FREEPORT-McMoRan INC.
EXHIBIT INDEX
		Filed
Exhibit		with this	Incorporated by Reference
Number	Exhibit Title	Form 10-Q	Form	File No.	Date Filed
~~2.1~~	~~Stock Purchase Agreement, dated as of October 6, 2014, among LMC Candelaria SpA, LMC Ojos del Salado SpA and Freeport Minerals Corporation~~	X
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 ~~1.4% Senior Notes due 2015, the~~ 2.15% Senior Notes due 2017, ~~and~~ the 3.55% Senior Notes due ~~2022)~~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	~~First Supplemental Indenture dated as of February 13, 2012, between FCX and U.S. Bank National Association, as Trustee (relating to the 1.4% Senior Notes due 2015)~~		~~8-K~~	~~001-11307-01~~	~~2/13/2012~~
~~4.3~~	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
~~4.4~~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
~~4.5~~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 ~~1.4% Senior Notes due 2015, the~~ 2.15% Senior Notes due 2017, and the 3.55% Senior Notes due ~~2022)~~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
~~4.7~~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
~~4.8~~	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 8.625% Senior Notes due 2019, the 7.625% Senior Notes due 2020, 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~~

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FREEPORT-McMoRan INC.
EXHIBIT INDEX
		Filed
Exhibit		with this	Incorporated by Reference
Number	Exhibit Title	Form 10-Q	Form	File No.	Date Filed
~~4.09~~4.11	~~Tenth Supplemental Indenture dated as of September 11, 2009 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 ~~8.625%~~6.625% Senior Notes due ~~2019)~~		~~8-K~~	~~001-31470~~	~~9/11/2009~~
~~4.10~~	~~Eleventh Supplemental Indenture dated as of March 29, 2010 to~~2021, 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 7.625%~~6.75% Senior Notes due ~~2020)~~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/~~29/2010~~13/2007
~~4.11~~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
~~4.12~~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
~~4.13~~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
~~4.14~~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
~~4.15~~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
~~4.16~~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 ~~8.625% Senior Notes due 2019, the 7.625% Senior Notes due 2020, 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
~~4.17~~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

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FREEPORT-McMoRan INC.
EXHIBIT INDEX
		Filed
Exhibit		with this	Incorporated by Reference
Number	Exhibit Title	Form 10-Q	Form	File No.	Date Filed
~~4.18~~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
~~4.19~~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
~~4.20~~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	Extension dated as of January 23, 2015, to Memorandum of Understanding Between the Government of the Republic of Indonesia and PT Freeport Indonesia dated as of July 25, ~~2014, between the Directorate General of Mineral and Coal, the Ministry of Energy and Mineral Resources and PT Freeport Indonesia on Adjustment of the Contract of Work.~~2014.		~~8-K~~10-K	001-11307-01	~~7/28/~~2/27/2015
10.2#	First Amendment, dated January 1, 2014, to the Crude Oil Purchase Agreement dated January 1, 2012, between Freeport-McMoRan Oil & Gas LLC (formerly Plains Exploration & Production Company) and ConocoPhillips Company.	X
10.3#	Second Amendment, dated July 1, 2014, to the Crude Oil Purchase Agreement dated January 1, 2012, between Freeport-McMoRan Oil & Gas LLC and ConocoPhillips Company.	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.

# Pursuant to a request for confidential treatment, portions of this exhibit have been redacted from the publicly filed document and have been furnished separately to the Securities and Exchange Commission.

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	Nine Months
	Ended
	September 30, 2013
	(in millions, except per share amounts)

Revenues	$	17,190
Operating income	4,617
Net income from continuing operations	2,683
Net income attributable to FCX common stockholders	2,134

Net income per share attributable to FCX common stockholders:
Basic	$	2.05
Diluted	2.04



	Crude Oil				Plains Offshore
	Options				Warrants
Fair value at December 31, 2013	$	(309	)		$	(2	)
Net realized losses	(21		)	^a	—
Net unrealized (losses) gains included in earnings related to assets and liabilities still held at the end of the period	(29		)	^b	2			^c
Settlement payments	177				—
Fair value at September 30, 2014	$	(182	)		$	—




Nine Months Ended September 30, 2013
	FCX			FM O&G LLC			Non-guarantor						Consolidated
	Issuer			Guarantor			Subsidiaries			Eliminations			FCX
Revenues	$	—		$	674		$	14,362		$	—		$	15,036
Total costs and expenses	106			587			10,642			—			11,335
Operating (loss) income	(106		)	87			3,720			—			3,701
Interest expense, net	(222		)	(63		)	(104		)	38			(351		)
Loss on early extinguishment of debt	(45		)	—			—			—			(45		)
Gain on investment in MMR	128			—			—			—			128
Other income (expense), net	39			—			12			(38		)	13
Benefit from (provision for) income taxes	61			(10		)	(1,018		)	—			(967		)
Equity in affiliated companies' net earnings (losses)	2,096			207			1			(2,301		)	3
Net income (loss)	1,951			221			2,611			(2,301		)	2,482
Net income and preferred dividends attributable to noncontrolling interests	—			—			(494		)	(37		)	(531		)
Net income (loss) attributable to FCX common stockholders	$	1,951		$	221		$	2,117		$	(2,338	)	$	1,951

Other comprehensive income	—			—			22			—			22
Total comprehensive income (loss)	$	1,951		$	221		$	2,139		$	(2,338	)	$	1,973



Current assets	$	449
Long-term assets	1,160
Current liabilities	138
Long-term liabilities	92



	Historical				Adjustments
	FCX		Candelaria/Ojos del Salado		Pro Forma⁽¹⁾			Sale⁽²⁾				Pro Forma
ASSETS
Current assets:
Cash and cash equivalents	$	658	$	121	$	—		$	1,852		A	$	2,389
Trade and other accounts receivable	2,307		197		94			—				2,204
Inventories	5,489		124		—			—				5,365
Other current assets	577		7		(1		)	—				569
Total current assets	9,031		449		93			1,852				10,527
Property, plant, equipment and development costs, net	26,304		663		—			—				25,641
Oil and natural gas properties, net - full cost method	22,337		—		—			—				22,337
Long-term mill and leach stockpiles	2,569		438		—			—				2,131
Goodwill and other assets	3,735		59		(19		)	1				3,658
Total assets	$	63,976	$	1,609	$	74		$	1,853			$	64,294

LIABILITIES AND EQUITY
Current liabilities	$	6,343	$	138	$	94		$	405		A	$	6,704
Long-term debt, less current portion	17,975		—		—			—				17,975
Deferred income taxes	7,559		—		—			(179		)	B	7,380
Reclamation and environmental obligations, less current portion	3,654		36		—			—				3,618
Other liabilities	1,730		56		3			—				1,677
Total liabilities	37,261		230		97			226				37,354

Redeemable noncontrolling interest	749		—		—			—				749

Total stockholders' equity	21,591		1,140		(23		)	1,627				22,055
Noncontrolling interests	4,375		239		—			—				4,136
Total equity	25,966		1,379		(23		)	1,627				26,191
Total liabilities and equity	$	63,976	$	1,609	$	74		$	1,853			$	64,294



	Year Ended December 31, 2013
	Historical
	FCX			Candelaria/Ojos del Salado			Pro Forma Adjustments⁽¹⁾			Pro Forma

Revenues	$	20,921		$	1,518		$	274		$	19,677
Total operating costs and expenses	15,570			834			222			14,958
Operating income	5,351			684			52			4,719
Interest expense and other, net	(438		)	5			—			(443		)
Income before taxes and equity in affiliated companies' net earnings	4,913			689			52			4,276
Provision for income taxes	(1,475		)	(252		)	(18		)	(1,241		)
Equity in affiliated companies' net earnings	3			—			—			3
Net income	3,441			437			34			3,038
Net income and preferred dividends attributable to noncontrolling interests	(783		)	(96		)	(8		)	(695		)
Net income attributable to FCX common stockholders	$	2,658		$	341		$	26		$	2,343

Net income per share attributable to FCX common stockholders:
Basic	$	2.65								$	2.34
Diluted	$	2.64								$	2.33
Weighted-average common shares outstanding:
Basic	1,002									1,002
Diluted	1,006									1,006