Filed by Bowne Pure Compliance

FORM 10-Q/A

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549


þ		QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarter ended June 30, 2007


o		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 1-10877

TERRA NITROGEN COMPANY, L.P.

(Exact name of registrant as specified in its charter)


Delaware		73-1389684
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)


Terra Centre
PO Box 6000, 600 Fourth Street
Sioux City, Iowa		51102-6000
(Address of principal executive office)		(Zip Code)

Registrant’s telephone number:
(712) 277-1340

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.
x Yes o No

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

o Large accelerated filer x Accelerated filer o Non-accelerated filer

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

At the close of business on July 27, 2007 there were 18,501,576 Common Units and 184,072 Class B Common Units outstanding.

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

TERRA NITROGEN COMPANY, L.P.
CONSOLIDATED BALANCE SHEETS
(in thousands)
(unaudited)


	June 30,			December 31,			June 30,
	2007			2006			2006
ASSETS
Current assets:
Cash and cash equivalents	$	80,732		$	62,287		$	33,110
Demand deposits with affiliate		5,332			2,457			7,469
Accounts receivable		49,999			37,676			31,340
Inventory		22,542			22,709			27,362
Prepaid expenses and other current assets		2,471			3,334			1,350

Total current assets		161,076			128,463			100,631


Property, plant and equipment, net		72,250			74,096			75,125
Other assets		13,749			15,655			7,467

Total assets	$	247,075		$	218,214		$	183,223


LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accounts payable and accrued liabilities	$	47,481		$	38,342		$	24,456
Customer prepayments		16,846			35,326			7,138

Total current liabilities		64,327			73,668			31,594


Other long-term liabilities		1,815			474			289

Total liabilities		66,142			74,142			31,883


Partners’ capital:
Limited partners’ interests, 18,502 Common Units and 184 Class B Common Units authorized and outstanding		204,785			160,795			165,731
General partner’s interest, 5 Master Limited Partner Units authorized and outstanding		(10,099	)		(10,544	)		(10,495	)
Accumulated other comprehensive loss		(13,753	)		(6,179	)		(3,896	)

Total partners’ capital		180,933			144,072			151,340


Total liabilities and partners’ capital	$	247,075		$	218,214		$	183,223

See Accompanying Notes to the Consolidated Financial Statements.

TERRA NITROGEN COMPANY, L.P.
CONSOLIDATED STATEMENTS OF OPERATIONS
(in thousands, except per unit amounts)
(unaudited)


	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2007			2006			2007			2006
Revenues	$	177,158		$	119,109		$	305,010		$	214,587
Other		282			42			587			21

Total revenues		177,440			119,151			305,597			214,608

Cost of goods sold		114,111			100,105			204,881			196,215


Gross profit		63,329			19,046			100,716			18,393
Operating expenses		7,470			2,027			10,648			4,065


Operating income		55,859			17,019			90,068			14,328
Interest expense		(114	)		(110	)		(226	)		(219	)
Interest income		1,312			456			2,545			819


Net income	$	57,057		$	17,365		$	92,387		$	14,928
Net income allocable to limited partners’ interest	$	56,486		$	17,191		$	91,463		$	14,779


Net income per limited partnership unit	$	3.02		$	0.92		$	4.90		$	0.79

See Accompanying Notes to the Consolidated Financial Statements.

TERRA NITROGEN COMPANY, L.P.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands)
(unaudited)


	Six Months Ended
	June 30,
	2007			2006
Operating activities:

Net income	$	92,387		$	14,928
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization		7,619			6,668
Non-cash (gain) loss on derivative instruments		(342	)		333
Changes in operating assets and liabilities:
Receivables		(12,323	)		748
Inventories		167			(630	)
Accounts payable, accrued liabilities and customer prepayments		(16,188	)		(18,631	)
Other assets and liabilities		1,909			6,887

Net cash flows from operating activities		73,229			10,303


Investing activities:
Capital expenditures		(2,900	)		(3,426	)
Plant turnaround expenditures		(1,057	)		(282	)
Change in demand deposits with affiliate		(2,875	)		19,036

Net cash flows from investing activities		(6,832	)		15,328


Financing activities:
Partnership distributions paid		(47,952	)		—
Repayment of long-term debt and capital lease obligations		—			(12	)

Net cash flows used in financing activities		(47,952	)		(12	)


Net increase in cash and cash equivalents		18,445			25,619
Cash and cash equivalents at beginning of year		62,287			7,491

Cash and cash equivalents at end of period	$	80,732		$	33,110

Supplemental disclosure of cash flow information:
Cash paid during the year for interest	$	64		$	126

See Accompanying Notes to the Consolidated Financial Statements.

TERRA NITROGEN COMPANY, L.P.
CONSOLIDATED STATEMENTS OF PARTNERS’ CAPITAL
(in thousands, except for units)
(unaudited)


							Accumulated
	Limited			General			Other			Total
	Partners'			Partner's			Comprehensive			Partners'			Comprehensive
(in thousands, except for Units)	Interests			Interests			Income (Loss)			Capital			Income
Partners’ capital at January 1, 2007	$	160,795		$	(10,544	)	$	(6,179	)	$	144,072
Net income		91,463			924			—			92,387		$	92,387
Change in fair value of derivatives		—			—			(7,574	)		(7,574	)		(7,574	)

Comprehensive income													$	84,813

Distributions		(47,473	)		(479	)		—			(47,952	)

Partners’ capital at June 30 ,2007	$	204,785		$	(10,099	)	$	(13,753	)	$	180,933


Limited partner units issued and outstanding at June 30, 2007:
Common Units			18,501,576
Class B Common Units			184,072

Total units outstanding at June 30, 2007			18,685,648


						Accumulated
	Limited		General			Other			Total
	Partners'		Partner's			Comprehensive			Partners'		Comprehensive
(in thousands, except for Units)	Interests		Interest			Income (Loss)			Capital		Income
Partners’ capital at January 1, 2006	$	150,952	$	(10,644	)	$	(5,949	)	$	134,359
Net income		14,779		149			—			14,928	$	14,928
Change in fair value of derivatives		—		—			2,053			2,053		2,053

Comprehensive income											$	16,981

Partners’ capital at June 30, 2006	$	165,731	$	(10,495	)	$	(3,896	)	$	151,340


Limited partner units issued and outstanding June 30, 2006:
Common Units			18,501,576
Class B Common Units			184,072

Total units outstanding at June 30, 2006			18,685,648

See Accompanying Notes to the Consolidated Financial Statements.

Explanatory Note

This Amendment No. 1 to the Terra Nitrogen Company, L.P. (the Partnership) Quarterly Report on Form 10-Q/A for the quarterly period ended June 30, 2007, amends and supplements the Quarterly Report on Form 10-Q filed by the registrant with the Securities and Exchange Commission (SEC) on July 30, 2007 (the “Original Form 10-Q”). This Amendment No. 1 amends Part I, Item 1 — Financial Statements and Part I, Item 2 — Managements Discussion and Analysis of Financial Condition and Results of Operations, to correct an error in the pro forma cumulative shortfall of distributions reported for September 30, 2007. As a result, the pro forma cumulative shortfall of distributions for September 30, 2007 are anticipated to be approximately $152.9 million, or $8.18 per unit.

The Amendment No. 1 does not otherwise alter the disclosures set forth in the original 10-Q and does not reflect events occurring after the filing of the original 10-Q. This Amendment No. 1 is effective for all purposes as of the date of the filing of the original 10-Q.

TERRA NITROGEN COMPANY, L.P.

Notes to Consolidated Financial Statements (Unaudited)

1.		Financial Statement Presentation

		Basis of Presentation

		The condensed consolidated financial statements contained herein should be read in conjunction with the consolidated financial statements and notes thereto contained in the Terra Nitrogen Company, L.P. (“TNCLP”) Annual Report on Form 10-K for the year ended December 31, 2006. TNCLP and its operating partnership subsidiary, Terra Nitrogen, Limited Partnership (the “Operating Partnership”), are referred to herein, collectively, as the “Partnership”.

		The accompanying unaudited condensed consolidated financial statements reflect all adjustments, which are, in the opinion of management, necessary for the fair statement of the results for the periods presented. All of these adjustments are of a normal and recurring nature. Results for the quarter are not necessarily indicative of future financial results of the Partnership.

		Derivatives and Financial Instruments

		The Partnership accounts for derivatives in accordance with Statement of Financial Accounting Standards (“SFAS”) No. 133, Accounting for Derivative Instruments and Hedging Activities, which requires that derivatives be reported on the balance sheet at fair value and, if the derivative is not designated as a hedging instrument, changes in fair value must be recognized in earnings in the period of change. If the derivative is designated as a hedge and to the extent such hedge is determined effective, changes in fair value are either (a) offset by the change in fair value of the hedged asset or liability or (b) reported as a component of accumulated other comprehensive income (loss) in the period of change, and subsequently recognized in the determination of net income in the period that the offsetting hedged transaction occurs.

		Terra Industries Inc. and its subsidiaries (“Terra”) enter into derivative instruments with counterparties for the Partnership’s operations. When Terra enters into a derivative instrument for the Partnership’s operations, the Partnership simultaneously enters into a derivative instrument with Terra as the counterparty. The terms of the derivative instruments between the Partnership and Terra are identical to the terms of the derivative instruments between Terra and Terra’s counterparty. The types of derivative instruments entered into include future contracts, swap agreements, put and call options to cap or fix prices for a portion of the Partnership’s natural gas production requirements. Terra may also enter into similar derivative instruments to fix or set floor prices for a portion of the Partnership’s nitrogen sales volumes.

		Revenue Recognition

		Revenue is recognized when persuasive evidence of a transaction exists, delivery has occurred, the price is fixed or determinable, no obligations remain and collectibility is probable. The Partnership classifies any discounts and trade allowances as a reduction in revenue. Gains or losses associated with settled nitrogen derivative contracts are classified as revenue. The Partnership classifies amounts directly or indirectly billed to its customers for shipping and handling as revenue.

		Cost of Sales

		The cost of manufacturing fertilizer products is recorded when the fertilizer products are sold and revenue is recognized. The Partnership classifies amounts directly or indirectly billed for delivery of products to its customers or its terminals as cost of sales. Premiums paid for option contracts are deferred and recognized in cost of sales in the month to which the related derivative transactions are settled. Realized gains and losses on derivatives activities are recognized in cost of sales.

		Inventories

		Inventories are stated at the lower of average cost or estimated net realizable value. The Partnership performs a monthly analysis of its inventory balances to determine if the carrying amount of inventories exceeds its net realizable value. The analysis of estimated realizable value is based on customer orders, market trends and historical pricing. If the carrying amount exceeds the estimated net realizable value, the carrying amount is reduced to the estimated net realizable value.

		Production costs include the cost of direct labor and materials, depreciation and amortization, and overhead costs related to manufacturing activities. The cost of inventories is determined using the first-in, first-out method.

		The Partnership estimates a reserve for obsolescence and excess of its materials and supplies inventory. Inventory is stated net of the reserve.

		Impairment of Long-Lived Assets

		The Partnership reviews its long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If the sum of the undiscounted future cash flows expected to result from the use of the asset is less than the carrying amount of the asset, an impairment loss is recognized based on the difference between the carrying amount and the fair value of the asset.

		Natural Gas Futures, Swaps, Options and Basis Swaps

		The estimated fair value of each class of derivatives is based on published referenced prices and quoted market prices from brokers.

		Cash and Cash Equivalents

		The Partnership classifies cash and short-term investments with an original maturity of three months or less as cash and cash equivalents. Demand deposits with affiliate are not classified in cash and cash equivalents.

		Demand Deposits with Affiliate

		Partnership cash receipts are generally received by Terra Capital, Inc., (“Terra Capital”) the indirect parent of the General Partner. Cash receipts, net of cash payments made by Terra Capital, are transferred to the Partnership from Terra Capital on a weekly basis. As a result of this cash collection and distribution arrangement, Terra Capital is a creditor to the Partnership.

		Use of Estimates in Preparation of the Financial Statements

		The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

2.		Agreement of Limited Partnership

		The Partnership makes quarterly cash distributions to Unitholders and the General Partner in an amount equal to 100% of its “Available Cash” as defined in the Agreement of Limited Partnership. Available Cash is defined generally as all cash receipts less all cash disbursements, adjusted for changes in certain reserves that the General Partner reasonably determines necessary.

		The Limited Partner receives 99% of the Available Cash and 1% is distributed to the General Partner, except when cumulative distributions of Available Cash exceed specified target levels above the Minimum Quarterly Distribution (“MQD”) of $0.605 per unit. Under such circumstances, the General Partner is entitled, as an incentive, to larger percentage interests. As of June 30, 2007, the cumulative shortfall on quarterly distributions to holders of Common Units that must be paid before the General Partner receives an incentive payment was $197.7 million, or $10.58 per unit.

When cumulative distributions of Available Cash exceed specified target levels above the MQD, the General Partner’s percentage interest in the Partnership’s distributions of Available Cash at various levels follows:


Incremental Distribution	Percentage of Incremental Distribution
per Common Unit	to General Partner
Less than $0.715		1	%
$0.715-$0.825		15	%
$0.825-$1.045		25	%
Greater than $1.045		50	%

On July 26, 2007, the Partnership announced a $3.00 per unit distribution to be paid during the 2007 third quarter. As a result of this distribution, the pro forma cumulative shortfall that must be paid before the General Partner affiliate receives an incentive payment as of September 30, 2007 is anticipated to be approximately $152.9 million, or $8.18 per unit.

The General Partner is required to remit the majority of cash distributions it receives from the Partnership in excess of its one percent Partnership equity interest to an affiliated company.

In the first six months of 2007, the Partnership paid $47.9 million in cash distributions to its partners. In the first six months of 2006 the Partnership did not pay any cash distributions.

At June 30, 2007, the General Partner and its affiliates owned 75.3% of the Partnership’s outstanding units. When less than 25% of the issued and outstanding units are held by non-affiliates of the General Partner, the Partnership, at the General Partner’s sole discretion, may call, or assign to the General Partner or its affiliates, its right to acquire all such outstanding units held by non-affiliated persons. If the General Partner elects to acquire all outstanding units, the Partnership is required to give at least 30 but not more than 60 days’ notice of its decision to purchase the outstanding units. The purchase price per unit will be the greater of 1) the average of the previous 20 trading days’ closing prices as of the date five days before the purchase is announced and 2) the highest price paid by the General Partner or any of its affiliates for any unit within the 90 days preceding the date the purchase is announced. Additional purchases of common units by the General Partner may be restricted under the terms of Terra’s bank credit agreement as described therein.

3.		Net Income per Limited Partnership Unit

		Basic income per unit data is based on the weighted-average number of Partnership Units outstanding during the period. Diluted income per unit data is based on the weighted-average number of Partnership Units outstanding and the effect of all dilutive potential common units.
		The following table provides the components of basic income per unit for the three-month periods ended June 30, 2007 and 2006:

The following table provides the components of basic income per unit for the three-month periods ended June 30, 2007 and 2006:


	Three Months Ended				Six Months Ended
	June 30,				June 30,
(in thousands, except share amounts)	2007		2006		2007		2006
Basic income (loss) per limited Partnership unit computation:

Net income allocable to limited Partners’ interest	$	56,486	$	17,191	$	91,463	$	14,779

Weighted average units outstanding		18,686		18,686		18,686		18,686


Net income per limited Partnership unit	$	3.02	$	0.92	$	4.90	$	0.79

		There were no dilutive Partnership units outstanding for the three- and six-month periods ended June 30, 2007 and 2006.

4.		Inventories

		Inventories consisted of the following:


	June 30,		December 31,		June 30,
(in thousands)	2007		2006		2006

Materials and supplies	$	7,494	$	7,925	$	7,932
Finished goods		15,048		14,784		19,430

Total	$	22,542	$	22,709	$	27,362

		Inventory is valued at actual first in, first out cost. Costs include raw material, labor and overhead.

5.		Derivative Financial Instruments

		The Partnership manages risk using derivative financial instruments for changes in natural gas supply prices and changes in nitrogen prices. Derivative financial instruments have credit risk and market risk.

		Terra enters into derivative instruments with counterparties for the Partnership’s operations. When Terra enters into a derivative instrument for the Partnership’s operations, the Partnership simultaneously enters into a derivative instrument with Terra as the counterparty. The terms of the derivative instruments between the Partnership and Terra are identical to the terms of the derivative instruments between Terra and Terra’s counterparty. Terra will not enter into transactions with a counterparty if the additional transaction will result in credit exposure exceeding $20 million. The credit rating of counterparties may be modified through guarantees, letters of credit or other credit enhancement vehicles.

The Partnership classifies a derivative financial instrument as a hedge if all of the following conditions are met:

	1.		The item to be hedged must expose the Partnership to currency or price risk.

	2.		It must be probable that the results of the hedge position substantially offset the effects of currency or price changes on the hedged item (e.g., there is a high correlation between the hedge position and changes in market value of the hedge item).

	3.		The derivative financial instrument must be designated as a hedge of the item at the inception of the hedge.

Natural gas supplies to meet production requirements at the Partnership’s production facilities are purchased at market prices. Natural gas market prices are volatile and the Partnership effectively hedges a portion of its natural gas production requirements and inventory through the use of futures contracts, swaps and options. These contracts reference physical natural gas prices or approximate NYMEX futures contract prices. Contract physical prices are frequently based on prices at the Henry Hub in Louisiana, the most common and financially liquid location of reference for financial derivatives related to natural gas. However, natural gas supplies for the Partnership’s production facilities are purchased at locations other than Henry Hub, which often creates a location basis differential between the contract price and the physical price of natural gas. Accordingly, the use of financial derivatives may not exactly offset the changes in the price of physical gas. The contracts are traded in months forward and settlement dates are scheduled to coincide with gas purchases during that future period.

A swap is a contract between the Partnership and a third party to exchange cash based on a designated price. Option contracts give the holder the right to either own or sell a futures or swap contract. The futures contracts require maintenance of cash balances generally 10% to 20% of the contract value and option contracts require initial premium payments ranging from 2% to 5% of contract value. Basis swap contracts require payments to or from the Partnership for the amount, if any, that monthly published gas prices from the source specified in the contract differ from the prices of a NYMEX natural gas futures during a specified period. There are no initial cash requirements related to the swap and basis swap agreements.

The following summarizes the position of open natural gas derivative contracts at June 30, 2007, December 31, 2006 and June 30, 2006:


	Other		Accrued
	Current		Current			Net
(in thousands)	Assets		Liabilities			Asset (Liability)
June 30, 2007	$	1,806	$	(14,898	)	$	(13,092	)
December 31, 2006		1,529		(8,052	)		(6,523	)
June 30, 2006		707		(4,935	)		(4,228	)

Certain derivatives outstanding at June 30, 2007 and 2006, which settled during July 2007 and 2006, respectively, are included in the position of open natural gas derivatives in the table above. The July 2007 derivatives settled for an approximate $2.6 million loss. All open derivatives will settle during the next 12 months.

At June 30, 2007, the Partnership determined that certain derivative contracts were ineffective hedges for accounting purposes and recorded a credit of $0.3 million and $0.7 million to cost of sales for the three-and six-month periods ending June 30, 2007, respectively. Derivatives outstanding at June 30, 2006 included a loss of $0.3 million that was recorded as an ineffective position and charged to cost of sales for the three- and six-month periods ending June 30, 2006.

The effective portion of gains and losses on settlement of these contracts that qualify for hedge treatment are carried as accumulated other comprehensive income (loss) and are credited or charged to cost of sales in the month in which the hedged transaction settles. Gains and losses on the contracts that do not qualify for hedge treatment are credited or charged to cost of sales based on the positions’ fair value. The risk and reward of outstanding natural gas positions are directly related to increases or decreases in natural gas prices in relation to the underlying NYMEX natural gas contract prices.
The activity related to accumulated other comprehensive income (loss) for the six month periods ended June 30, 2007 and 2006 is:


(in thousands)	2007			2006
Beginning accumulated (loss)	$	(6,179	)	$	(5,949	)
Reclassification into earnings		282			21,538
Net change associated with current period hedging transactions		(7,856	)		(19,485	)

Ending accumulated loss	$	(13,753	)	$	(3,896	)

		All of the accumulated loss recorded above will be reclassified into earnings during the next twelve-month period ending June 30, 2008.

		At times, the Partnership also uses forward derivative instruments to fix or set floor prices for a portion of its nitrogen sales volumes. At June 30, 2007, the Partnership had open contracts covering nitrogen solutions. When outstanding, the nitrogen solution contracts do not qualify for hedge treatment due to inadequate trading history to demonstrate effectiveness. Consequently, these contracts are marked-to-market and unrealized gains or losses are reflected in revenue in the statement of operations. For the three- and six-month periods ending June 30, 2007, the Partnership recognized a loss of $1.0 million and $1.9 million, respectively, on nitrogen forward derivative instruments. For the three-and six-month periods ending June 30, 2006, there were no gains or losses on nitrogen forward derivative instruments.

6.		Revolving Credit Facility

		In the first quarter of 2007, the Partnership amended the $50.0 million revolving credit facility to extend the expiration date to January 31, 2012. The revolving credit facility bears interest at a variable rate plus a margin (London Interbank Offer Rate (LIBOR) plus 175 basis points, or 7.07% at June 30, 2007). Under the credit facility, the Partnership may borrow an amount generally based on eligible cash balances, 85% of eligible accounts receivable and 60% of eligible finished goods inventory, less outstanding letters of credit. The Partnership’s borrowings under the credit facility are secured by substantially all of its working capital. The agreement also requires the Partnership to adhere to certain limitations on additional debt, capital expenditures, acquisitions, liens, asset sales, investments, prepayments of subordinated indebtedness, changes in lines of business and transactions with affiliates. At June 30, 2007, the Partnership had $50.0 million of borrowing availability, and, there were no outstanding borrowings or letters of credit under the facility.

7.		New Accounting Pronouncements

		In September 2006, the FASB issued SFAS 157, Fair Value Measurements, (SFAS 157). SFAS 157 is definitional and disclosure oriented and addresses how companies should approach measuring fair value when required by generally accepted accounting principles (GAAP); it does not create or modify any current GAAP requirements to apply fair value accounting. SFAS 157 provides a single definition for fair value that is to be applied consistently for all accounting applications, and also generally describes and prioritized according to reliability the methods and input used in valuations. SFAS 157 prescribes various disclosures about financial statement categories and amounts which are measured at fair value, if such disclosures are not already specified elsewhere in GAAP. The new measurement and disclosure and requirements of SFAS 157 are effective for the Partnership in 2008 first quarter and the Partnership expects no significant impact from adopting the Standard.

		In February 2007 the Financial Accounting Standards Board (FASB) issued Statement of Financial Accounting Standards (SFAS) 159, The Fair Value Option for Financial Assets and Financial Liabilities (SFAS 159). SFAS 159 permits entities to choose to measure many financial instruments and certain other items at fair value at specified election dates. SFAS 159 is effective for the Partnership beginning in the first quarter of 2008. The Partnership is currently assessing the impact SFAS 159 may have on its financial statements.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Introduction

The Partnership produces and markets nitrogen products for use in agricultural and industrial markets. Nitrogen is a commodity chemical and prices are established based on global supply and demand conditions. The nitrogen products industry has cycles of oversupply, resulting in lower prices and idled capacity, followed by supply shortages, resulting in high selling prices and higher industry-wide production rates. Natural gas is the most significant raw material in the production of nitrogen products. To be viable under these market conditions, a producer must be among the low-cost producers to markets it serves and have a financial position that can sustain it during periods of oversupply.

Imports, most of which are produced at facilities with access to fixed-price natural gas supplies, account for a significant portion of U.S. nitrogen product supply. Imported products’ natural gas costs have been and could continue to be substantially lower than the delivered cost of natural gas to the Partnership’s facilities. Offshore producers are most competitive in regions close to the point of entry for imports, including the Gulf Coast and East Coast.

The Partnership’s sales volumes are primarily dependent upon the operating rates for its Verdigris plant. The Partnership may purchase product from other manufacturers or importers for resale, however, historic gross margins on those volumes are rarely significant. Profitability and cash flows from the operations are affected by the ability to manage costs and expenses (other than natural gas), most of which do not materially change for different levels of production or sales. Other factors affecting operating results include the level of planted acres, transportation costs, weather conditions (particularly during the planting season), grain prices and other variables described in Item 1 “Business” and Item 2 “Properties” sections of the Partnership’s most recent Form 10-K filing with the Securities and Exchange Commission.

Dependence on Terra Industries

The Partnership is dependent on Terra Industries Inc. (“Terra”) in a number of respects. Terra provides all of the Partnership’s management, natural gas purchasing and hedging, selling and administrative services and operates its facilities through its wholly-owned subsidiary Terra Nitrogen GP Inc., the Partnership’s General Partner. Terra and its wholly-owned subsidiaries have more debt and debt service requirements than the Partnership. Although Terra is affected by most of the factors that affect the Partnership, its higher level of debt could put a greater risk on Terra in the event of adverse business conditions. The Partnership’s results of operations and financial condition might be materially adversely affected by financial difficulties at Terra, default by it or its subsidiaries on their debt or their bankruptcy. For additional information concerning Terra, refer to Terra’s filings with the Securities and Exchange Commission on Form 10-K, Forms 10-Q and current reports on Form 8-K.

Three months ended June 30, 2007 compared with
three months ended June 30, 2006

Volumes and prices for the three-month periods ended June 30, 2007 and 2006 are:


	2007				2006
	Volumes		Unit Price		Volumes		Unit Price
	(000 tons)		($/ton)*		(000 tons)		($/ton)*
Ammonia		95	$	382		68	$	381
UAN		631	$	201		571	$	141

*After deducting outbound freight costs

Revenues for the 2007 second quarter were $177.4 million, compared to $119.2 million for the 2006 second quarter. The $58.2 million, or 49%, increase in revenues was primarily due to an increase in sales volumes of 40% in ammonia and 11% in UAN, and a 43% increase in UAN prices. The higher volumes and UAN prices were due to stronger demand for nitrogen products primarily as a result of increased planted corn acreage as compared to 2006.

The 2007 second quarter gross profit was $63.3 million, which was $44.3 million more than the 2006 second quarter. As compared to the 2006 second quarter, 2007 gross profits increased approximately $8.2 million due to increased sales volumes and approximately $34.2 million from higher prices. The remaining $1.9 million change in gross profit was due to higher natural gas costs, offset by operational efficiencies which lowered operating costs in the 2007 second quarter as compared to the 2006 second quarter. Natural gas costs purchased by the Partnership, including the effects of forward price contracts, during the 2007 and 2006 second quarters were $6.72 per MMBtu and $6.02 per MMBtu, respectively.

Six months ended June 30, 2007 compared with
six months ended June 30, 2006

Volumes and prices for the six-month periods ended June 30, 2007 and 2006 are:


	2007				2006
	Volumes		Unit Price		Volumes		Unit Price
	(000 tons)		($/ton)*		(000 tons)		($/ton)*
Ammonia		164	$	371		120	$	394
UAN		1,205	$	181		998	$	146

*After deducting outbound freight costs

Revenues for the six months ended June 30, 2007 increased $91 million, or 42%, compared with the same 2006 period primarily due to increased sales volumes and higher prices offset by a decline to ammonia prices. The higher volumes and UAN prices were due to stronger demand for nitrogen products primarily as a result of increased planted corn acreage as compared to 2006. Ammonia prices declined from prior year due to lower 2007 first quarter raw material costs, primarily natural gas.

The 2007 first half gross profit was $100.7 million, which was $82.3 million more than the 2006 first half. Increased sales volumes and sales prices raised 2007 first half gross profit by approximately $19.4 million and $32.0 million, respectively, as compared to the 2006 first half. The 2007 first half natural gas costs decreased $28.3 million from the 2006 first half. Natural gas costs purchased by the Partnership, including the effects of forward price contracts, during the 2007 and 2006 first half were $6.56 per MMBtu and $7.94 per MMBtu, respectively.

Capital resources and liquidity

Operating activities for the first six months of 2007 generated $73.2 million of cash, comprised of $99.6 million of cash from operating activities less $26.4 million used to fund working capital increases. The primary working capital needs were to fund $18.5 million of customer prepayment reductions for seasonal customer shipments.

Capital expenditures of $2.9 million during the first six months of 2007 were primarily to fund replacement and stay-in-business additions to plant and equipment.

The Partnership’s principal funding needs are to support its working capital and capital expenditures. The Partnership intends to fund its needs primarily from cash provided by operating activities and, to the extent required, from funds borrowed under the Partnership’s $50.0 million revolving bank credit facility.

In the first quarter of 2007, the Partnership amended the $50.0 million revolving credit facility to extend the expiration date to January 31, 2012. Under the credit facility, the Partnership may borrow an amount generally based on eligible cash balances, 85% of eligible accounts receivable and 60% of eligible finished goods inventory, less outstanding letters of credit. The Partnership’s borrowings under the credit facility are secured by substantially all of its working capital. At June 30, 2007, the Partnership had borrowing availability of $50.0 million and had no outstanding borrowings or letters of credit under the facility. Management expects the facility to be adequate to meet the Partnership’s operating cash needs.

Under the credit facility, the Partnership is subject to the covenants which impose certain limitations on additional debt, capital expenditures, acquisitions, liens, asset sales, investments, prepayments of subordinated indebtedness, changes in lines of business and transactions with affiliates. In addition, if the Partnership’s aggregate borrowing availability falls below $10.0 million, it is required to have generated $25.0 million of operating cash flows or earnings before interest, income taxes, depreciation, amortization and other non-cash items as defined in the credit facility for the preceding four quarters. The Partnership is also required to maintain a minimum aggregate unused borrowing availability of $5.0 million at all times.

The Partnership’s ability to continue to meet the covenants under the credit facility in the future will depend on market conditions, operating cash flows, working capital needs, receipt of customer prepayments and trade credit terms. Failure to meet these covenants, or to obtain a waiver from the lenders, would result in a default by the Partnership such that all outstanding amounts could become immediately due and payable and the Partnership would be unable to borrow additional amounts under the credit facility. Because access to adequate bank facilities may be critical to funding the Partnership’s operating cash needs and purchase of financial derivatives to manage the Partnership’s exposure to natural gas commodity price risk, any default or termination of the revolving bank credit facility could have a material adverse effect on the Partnership.

Quarterly distributions to the partners are based on Available Cash for the quarter as defined in the Agreement of Limited Partnership. Available Cash is defined generally as all cash receipts less all cash disbursements, adjusted for changes in certain reserves established as the General Partner reasonably determines necessary.

The Limited Partner receives 99% of the Available Cash and 1% is distributed to the General Partner, except when cumulative distributions of Available Cash exceed specified target levels above the Minimum Quarterly Distribution (“MQD”) of $0.605 per unit. Under such circumstances, the General Partner is entitled, as an incentive, to larger percentage interests. As of June 30, 2007, the cumulative shortfall on quarterly distributions to holders of Common Units that must be paid before the General Partner receives an incentive payment was $197.7 million, or $10.58 per unit.

The General Partner’s percentage interest in the Partnership’s distributions of Available Cash at various levels follows:


Incremental Distribution	Percentage of Incremental Distribution
per Common Unit	to General Partner
Less than $0.715		1	%
$0.715-$0.825		15	%
$0.825-$1.045		25	%
Greater than $1.045		50	%

The General Partner is required to remit the majority of cash distributions it receives from the Partnership in excess of its one percent Partnership equity interest to an affiliated company.

Distributions paid to the partners for the six-month period ended June 30, 2007 were $47.9 million. There were no distributions for the period ended June 30, 2006.

There were no material changes outside the ordinary course of business to the Company’s contractual obligations presented in Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of the Annual Report on Form 10-K for the period ended December 31, 2006.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The Partnership’s operations are significantly affected by the price of natural gas. It employs derivative commodity instruments related to a portion of its natural gas requirements (primarily futures, swaps and options) for the purpose of managing exposure to commodity price risk in the purchase of natural gas. Changes in the market value of these derivative instruments are expected to have a high correlation to changes in the spot price of natural gas. For more information about how the Partnership manages specific risk exposures, refer to its most recent Annual Report on Form 10-K (which is on file with the Securities and Exchange Commission), Item 7A “Quantitative and Qualitative Disclosures about Market Risk” and Note 6 — Derivative Financial Instruments contained in Item 8.

The volume of natural gas hedged varies from time to time based on management’s judgment of market conditions, particularly natural gas prices and prices for nitrogen products. Management also considers the Partnership’s position related to forward fixed price sales contracts in determining the level of derivatives necessary. Contracts were in place at June 30, 2007 to cover approximately 37% of its natural gas requirements for the succeeding twelve months. The General Partner’s ability to manage the Partnership’s exposure to commodity price risk in the purchase of natural gas through the use of financial derivatives may be affected by limitations imposed by its bank agreement covenants.

ITEM 4. CONTROLS AND PROCEDURES

The Partnership’s Chief Executive Officer and Chief Financial Officer have concluded, based on their evaluation as of the end of the period covered by this report, that the Partnership’s disclosure controls and procedures are effective to ensure that information required to be disclosed in the reports that the Partnership files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission’s rules and forms.

There were no significant changes in the Partnerships’ internal control over financial reporting that occurred during the most recent quarter that have materially affected, or are reasonably likely to materially affect, the Partnerships’ internal control over financial reporting.

FORWARD LOOKING PRECAUTIONS

Information contained in this report, other than historical information, may be considered forward looking. Forward-looking information reflects management’s current views of future events and financial performance that involve a number of risks and uncertainties. The factors that could cause actual results to differ materially include, but are not limited to the following: changes in the financial markets, general economic conditions within the agricultural industry, competitive factors and price changes (principally, sales prices of nitrogen products and natural gas costs), changes in product mix, changes in the seasonality of demand patterns, changes in weather conditions, changes in agricultural regulations, and other risks detailed in the Partnership’s Securities and Exchange Commission filings, in particular Item 1A “Risk Factors” and the “Factors that Affect Operating Results” section of its most recent Form 10-K.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The Partnership is involved in various claims and legal actions arising in the ordinary course of business, including employee injury claims. In the opinion of management, the ultimate disposition of these matters will not have a material adverse effect on the Partnership’s consolidated financial position, results of operations or liquidity and the likelihood that a loss contingency will occur in connection with these claims is remote.

ITEM 1A. RISK FACTORS

There were no significant changes in the Partnership’s risk factors during 2007 as compared to the risk factors identified in the Partnership’s 2006 Form 10-K.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

None

ITEM 5. OTHER INFORMATION

None

ITEM 6. EXHIBITS

(a) Exhibits:


Exhibits *31.1		Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

Exhibits *31.2		Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

Exhibit *32		Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

*filed herewith

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 thereunto duly authorized.


		TERRA NITROGEN COMPANY, L.P.

		By:		TERRA NITROGEN GP INC.
				as General Partner

		By:		/s/ Francis G. Meyer

				Francis G. Meyer
				Vice President (Principal Accounting Officer)

Date: July 31, 2007


Part I — FINANCIAL INFORMATION

Item 1.	Financial Statements
	Consolidated Balance Sheets	3
	Consolidated Statements of Operations	4
	Consolidated Statements of Cash Flows	5
	Consolidated Statements of Partners’ Capital	6
	Notes to Consolidated Financial Statements	8

Item 2.	Management Discussion and Analysis of Financial Condition and Results of Operations	15

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	19

Item 4.	Controls and Procedures	19

Part II — OTHER INFORMATION

Item 1.	Legal Proceedings	20

Item 1A.	Risk Factors	20

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	20

Item 3.	Defaults upon Senior Securities	20

Item 4.	Submission of Matters to a Vote of Security Holders	20

Item 5.	Other Information	20

Item 6.	Exhibits	21

Exhibit 31.1
Exhibit 31.2
Exhibit 32

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

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

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

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

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

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

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

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


/s/ MICHAEL L. BENNETT		/s/ FRANCIS G. MEYER

Michael L. Bennett		Francis G. Meyer
President and Chief Executive Officer		Sr. Vice President and Chief Financial and
Director (Principal Executive Officer)		(Principal Financial Officer)

Dated: July 31, 2007		Dated: July 31, 2007

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	1.		I have reviewed this quarterly report on Form 10-Q of Terra Nitrogen Company, L.P.;

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

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

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

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

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


		/s/ MICHAEL L. BENNETT

		Michael L. Bennett President and Chief Executive Officer and Director (Principal Executive Officer)


		/s/ FRANCIS G. MEYER

		Francis G. Meyer Senior Vice President and Chief Financial Officer (Principal Financial Officer)

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

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