Transportadora de Gas del Sur (TGS) 20-F 2007 FY Annual report (foreign)

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

_____________

FORM 20-F

Report of Foreign Issuer

Pursuant to Rule 13a-16 or 15d-16 of

the Securities and Exchange Act of 1934

For April 20, 2007

Transportadora de Gas del Sur S.A.

Don Bosco 3672, Fifth Floor

1206 Capital Federal

Argentina

Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40-F.

Form 20-F X  Form 40-F 

Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to the Rule 12g3-2(b) under the Securities Exchange Act of 1934.

Yes_  NoX

IF "YES" IS MARKED, INDICATE BELOW THE FILE NUMBER ASSIGNED TO THE REGISTRANT IN CONNECTION WITH RULE 12G3-2(B):

1

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 20-F

(Mark One)

[ ]

REGISTRATION STATEMENT PURSUANT TO SECTION 12(B) OR (G) OF THE SECURITIES EXCHANGE ACT OF 1934

OR

[X]

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

For the fiscal year ended: December 31, 2007

OR

[ ]

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

For the transition period from    to     .

OR

[ ]

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

Date of event requiring this shell company report.

Commission file number: 1-13.396

TRANSPORTADORA DE GAS DEL SUR S.A.

(Exact name of Registrant as specified in its charter)

GAS TRANSPORTER OF THE SOUTH

(Translation of Registrant’s name into English)

Republic of Argentina

(Jurisdiction of incorporation or organization)

Don Bosco 3672

5th Floor

C1206ABF Buenos Aires

Argentina

(Address of principal executive offices)

Leandro Pérez Castaño

(54-11)-4865-9077

inversores@tgs.com.ar

 (Name, telephone, email and/or facsimile number of our contact person)

Securities registered or to be registered pursuant to Section 12(b) of the Act:

Title of each class	Name of each exchange on which registered
American Depositary Shares, representing Class “B” Shares	New York Stock Exchange
Class “B” Shares, par value Ps.1 each	New York Stock Exchange*

*

Not for trading, but only in connection with the registration of American Depositary Shares, pursuant to the requirements of the Securities and Exchange Commission.

Securities registered or to be registered pursuant to Section 12(g) of the Act:

None

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act:

None

Indicate the number of outstanding shares of each of the issuer’s classes of capital or common stock as of the close of the period covered by the Annual Report:

Class “A” Shares, par value Ps.1 each	405,192,594
Class “B” Shares, par value Ps.1 each	389,302,689
	794,495,283

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

1

Yes No X

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.

Yes No X

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.

Yes X No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer.

Large accelerated filer Accelerated filer X Non-accelerated filer

Indicate by check mark which bases of accounting the registrant has used to prepare the financial statements included in this filing:

	U.S. GAAP
	International Financial Reporting Standards as issued by the International Accounting Standards Board
X	Other

If “Other” has been checked in response to the previous questions, indicate by check mark which financial statement item the registrant has elected to follow.

Item 17 Item 18 X

If this is an annual report, indicate by check mark whether the registrant is a shell company.

Yes No X

2

TABLE OF CONTENTS:

		Page
	Presentation of Financial and Other Information	i
	Cautionary Statement Regarding Forward-Looking Statements	ii
	PART I
Item 1.	Identity of Directors, Senior Management and Advisers	1
Item 2.	Offer Statistics and Expected Timetable	1
Item 3.	Key Information	1
Item 4.	Our Information	12
Item 4A.	Unresolved Staff Comments	35
Item 5.	Operation and Financial Review and Prospects	35
Item 6.	Directors, Senior Management and Employees	52
Item 7.	Major Shareholders and Related Party Transactions	65
Item 8.	Financial Information	69
Item 9.	The Offer and Listing	72
Item 10.	Additional Information	73
Item 11.	Quantitative and Qualitative Disclosures About Market Risk	79
Item 12.	Description of Securities Other Than Equity Securities	80
	PART II
Item 13.	Defaults, Dividend Arrearages and Delinquencies	81
Item 14.	Material Modifications to the Rights of Security Holders and Use of Proceeds	81
Item 15.	Controls and Procedures	81
Item 16.	(Reserved)	81
Item 16A.	Audit Committee Financial Expert	81
Item 16B.	Code of Ethics	81
Item 16C.	Principal Accountant Fees and Services	82
Item 16D.	Exemptions from the Listing Standards for Audit Committees	82
Item 16E.	Purchases of Registered Equity Securities of the Issuer by the Issuer and Affiliated Purchasers	82
	PART III
Item 17.	Financial Statements	83
Item 18.	Financial Statements	83
Item 19.	Exhibits	83

1

PRESENTATION OF FINANCIAL AND OTHER INFORMATION

In this annual report on Form 20-F (“Annual Report”), references to “pesos” or “Ps.” are to Argentine pesos, and references to “U.S. dollars”, “dollars” or “US$” are to United States dollars. A “billion” is a thousand million. References to “m³” are to cubic meters. References to “cf” are to cubic feet, to “MMcf” are to millions of cubic feet, to “Bcf” are to billions of cubic feet, to “d” are to day and to “HP” are to horsepower.

Financial Statements

The audited consolidated financial statements (our“Financial Statements”) have been prepared in accordance with accounting principles generally accepted in Argentina (“Argentine GAAP”) and the requirements of Argentina’sComisión Nacional de Valores (the“CNV”), which differ in certain significant respects from accounting principles generally accepted in the United States (“US GAAP”). Such differences involve methods of measuring the amounts shown in the financial statements, as well as additional disclosures required by US GAAP and Regulation S-X of the Securities and Exchange Commission (“SEC”). For a description of the principal differences between Argentine GAAP and US GAAP see Note 12 to our Financial Statements. Our Financial Statements as of and for the year ended December 31, 2007 were audited by Sibille (“KPMG 8;), a member firm of KPMG International, and an independent registered public accounting firm, and as of and for the years ended December 31, 2006, 2005, 2004 and 2003, were audited by Price Waterhouse & Co S.R.L., Buenos Aires, Argentina (“Price”), a member firm of PricewaterhouseCoopers, an independent registered public accounting firm.  The report of KPMG, dated June 12, 2008, related to our Financial Statements is included in this Annual Report.

Our Board of Directors decided to engage KPMG as successor to Price in the role of independent accountant, commencing with year 2007. Price served as our independent accountant beginning with the year ended December 31, 2001, and this change in independent accountant is not the result of any disagreement or dissatisfaction between us and Price. The appointment of KPMG as independent accountant was approved by our Shareholders at a meeting held on April 12, 2007.

As discussed in Note 2(b) to our Financial Statements, our Financial Statements were prepared in constant Argentine pesos, recognizing the overall effects of inflation up to August 31, 1995, when inflation accounting was discontinued by a decree of the Executive Branch (“Executive Branch”) and a resolution of the CNV. Effective January 1, 2002, inflation accounting was reintroduced as part of Argentine GAAP by Resolution No. 3/2002 issued by the Professional Council in Economic Sciences of the Autonomous City of Buenos Aires (“CPCECABA”) and General Resolution No. 415 of the CNV, in view of the resumption of significant inflation in Argentina. However, in view of the relative monetary stability in Argentina during 2003, on March 25, 2003, the Executive Branch, through Decree No. 664/01, suspended the application of inflation accounting for periods ending after such date, and the CNV issued General Resolution No. 441 suspending inflation accounting effective March 1, 2003. We complied with the CNV resolution and accordingly ceased recording the effects of inflation beginning on February 28, 2003. Comparative figures were also restated for inflation as of that date. Since Argentine GAAP required companies to discontinue inflation accounting only as of October 1, 2003, the application of the CNV resolution represented a departure from Argentine GAAP. However, due to the low level of inflation rates during the period from March 2003 to September 2003, such a departure has not had a material effect on our Financial Statements.

As a result of the changes in the application of inflation accounting described above, until February 28, 2003, our Financial Statements were prepared on the basis of general price-level accounting, which reflected changes in the purchasing power of the peso in our historical financial statements using changes in the Argentine Wholesale Price Index (“WPI”), as published by theInstituto Nacional de Estadística y Censos(or“INDEC”), as follows:

(a)

we adjusted non-monetary items and amounts in our consolidated statements of income to reflect the current general purchasing power;

§

we did not adjust monetary items as such items were, by their nature, stated in terms of current general purchasing power in our consolidated financial statements;

§

we recognized monetary gains or losses in our consolidated statements of income, reflecting the effect of holding monetary items; and

§

we included the gain or loss on exposure to inflation (monetary gain or loss) in our consolidated statements of income within financing results.

i

Other Information

Unless otherwise specified, all exchange rate information contained in this Annual Report has been derived from information published byBanco de la Nación Argentina S.A.(“Banco de la Nación”), without any independent verification by us.

Certain amounts shown in this Annual Report are subject to rounding. Accordingly, figures shown as totals in certain tables may not be an exact arithmetic aggregate of the other figures in such table.

References to “we”, “us” and “our” mean Transportadora de Gas del Sur S.A. (“TGS”) and its consolidated subsidiary, Telcosur S.A. (“Telcosur”).

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

Some of the information in this Annual Report, including information incorporated by reference herein, may constitute forward-looking statements within the meaning of the United States Private Securities Litigation Reform Act of 1995, as amended. These forward-looking statements can be identified by the use of forward-looking terminology such as “may,” “will,” “will likely result,” “intend,” “projection,” “should,” “believe,” “expect,” “anticipate,” “estimate,” “continue,” “plan” or other similar words. These statements discuss future expectations, contain projections of results of operations or of financial condition or state other forward-looking information. Forward-looking statements are subject to various risks and uncertainties. When considering forward-looking statements, you sh ould keep in mind the factors described in “Item 3. Key Information—Risk Factors” and other cautionary statements appearing in “Item 5. Operating and Financial Review and Prospects”. “Item 3. Key Information—Risk Factors” and other statements describe circumstances that could cause results to differ materially from those contained in any forward-looking statement.  

Forward-looking statements include but are not limited to the following:

§

statements regarding changes in general economic, business, political or other conditions in Argentina;

§

estimates relating to future tariffs and prices for our transportation services and future prices and volumes for products and services in our non-regulated business;

§

statements relating to the prices of our natural gas liquids (“NGL”) business and estimates of future volumes associated with our NGL business;

§

statements regarding expected future political developments in Argentina and expected future developments regarding our license to provide gas transportation services through the exclusive use of the southern gas transportation system in Argentina (the “License”), the renegotiation process at the Unit for Renegotiation and Assessment of Utilities Contracts (“UNIREN”), regulatory actions byEnte Nacional Regulador del Gas (“ENARGAS”) and any other governmental authorities that may affect us and our business;

§

statements and estimates regarding future pipeline expansion and the cost of, or return to us from, any such expansion;

§

statements concerning the future impact of the creation of the Electronic Gas Market (“MEG”); and

§

estimates of our future level of capital expenditures, including those required by ENARGAS and other governmental authorities.

When considering forward-looking statements, you should keep in mind the factors described in “Risk Factors” and other cautionary statements appearing in “Management’s Discussion and Analysis of Financial Condition and Results of Operations”. These factors and statements, as well as other statements contained herein, describe circumstances that could cause results to differ materially from those contained in any forward-looking statement.

The following important factors could cause actual results to differ materially from any results projected, forecasted, estimated or budgeted by us in our forward-looking statements:

§

the impact of the emergency laws enacted by the Argentine government, which resulted in the amendment of the Convertibility Law No. 23,928 and Decree No. 529/01 (collectively, the “Convertibility Law”) and related laws and regulations;

ii

§

risks and uncertainties related to changes in the peso-U.S. dollar exchange rate and the Argentine domestic inflation rate, which may materially adversely affect our revenues, expenses and reported financial results;

§

risks and uncertainties associated with our non-regulated business, including those related to international and local prices of NGL, taxes and other restrictions imposed on NGL exports, our ability to renegotiate our agreements with customers and possible increased regulation of the NGL industry in the future by the Argentine government;

§

risks and uncertainties resulting from government regulations that affect our business or financial condition or results of operations, such as the prohibition on tariff increases, restrictions on payments abroad and exchange controls;

§

risks and uncertainties associated with unscheduled and unexpected expenditures for the repair and maintenance of our fixed or capital assets or expenditures required or otherwise mandated or initiated by ENARGAS or other governmental authorities for the expansion of our pipeline system or other purposes, including the risk that we may effectively be forced to make investments or take other actions that may not be as commercially attractive as other actions;

§

risks and uncertainties resulting from the prospect of additional government regulation or other governmental involvement in our business;

§

developments in legal and administrative proceedings involving us and our affiliates;

§

changes to or revocation of our License; and

§

risks and uncertainties impacting us as a whole, including changes in general economic conditions, changes in laws and regulations to which we are subject, including tax, environmental and employment laws and regulations, and the cost and effects of legal and administrative claims and proceedings against us;

Our actual results may differ materially from the results anticipated in these forward-looking statements because such statements, by their nature, involve estimates, assumptions and uncertainties. The forward-looking statements contained in this Annual Report speak only as of the date of this Annual Report, and we do not undertake any obligation to update any forward-looking statement or other information to reflect events or circumstances occurring after the date of this Annual Report or to reflect the occurrence of unanticipated events.

iii

PART I

Item 1. Identity of Directors, Senior Management and Advisers

Not applicable.

Item 2. Offer Statistics and Expected Timetable

Not applicable.

Item 3. Key Information

A.

Selected Financial Data

The following selected consolidated financial data is derived from our Financial Statements as of and for the years ended December 31, 2007, 2006, 2005 and 2004, and our Financial Statements as of and for the years ended December 31, 2003, restated in constant pesos as of February 28, 2003. This information should be read in conjunction with and is qualified in its entirety by reference to our Financial Statements, including the independent accountant’ reports thereon and the notes related thereto, and the discussion in “Presentation of Financial and Other Information” and “Item 5. Operating and Financial Review and Prospects” included elsewhere in this Annual Report.

For important information relating to our Financial Statements, including information relating to the preparation and presentation of the audited consolidated financial statements and the following selected financial data, see “Presentation of Financial and Other Information” above.

		As of and for the year ended December 31,
		2007	2006	2005	2004	2003
		(in thousands of pesos, except per share and per ADS amounts and common stock or as otherwise indicated)
Statement of Income Data:
Net revenues(1)		1,257,273	1,309,502	1,064,738	994,084	892,795
Operating income		490,019	570,130	442,897	453,750	406,897
Net financial expense		(193,495)	(189,043)	(209,072)	(260,935)	(219,847)
Net income before income tax		294,520	379,914	230,322	158,494	164,642
Net income for the year		147,508	358,022	217,507	147,928	286,174
Per Share Data:(2)
Net income per share		0.19	0.45	0.27	0.19	0.36
Net income per ADS		0.93	2.25	1.37	0.93	1.80
Balance Sheet Data:
Property, plant and equipment, net		4,170,600	4,217,871	4,274,721	4,318,150	4,408,468
Total current assets		683,173	711,841	720,262	610,659	810,525
Total non-current assets		4,318,511	4,427,401	4,476,968	4,534,812	4,642,704
Total assets		5,001,684	5,139,242	5,197,230	5,145,471	5,453,229
Total current liabilities		312,741	378,748	339,459	354,959	3,383,493
Total non-current liabilities		1,759,395	1,978,363	2,433,664	2,583,912	11,064
Total liabilities		2,072,136	2,357,111	2,773,123	2,938,871	3,394,557
Minority interest		1	2	-	-	-
Shareholders’ equity (net assets)		2,929,547	2,782,129	2,424,107	2,206,600	2,058,672
Other Data:
Common stock (nominal value)		794,495	794,495	794,495	794,495	794,495
Additions to property, plant and equipment (includes work in progress)(3)		189,061	156,411	171,530	109,385	44,245
Depreciation and amortization		198,923	192,887	197,575	197,899	200,454
US GAAP Information:
Net income		219,556	405,582	270,620	151,634	597,714
Shareholders’ equity		2,158,423	1,935,498	1,527,763	1,257,386	1,103,950
Net income per share(2)		0.28	0.51	0.34	0.19	0.75
Net income per ADS(2)		1.38	2.55	1.70	0.95	3.76
	(1)Includes Ps. 509,501; Ps. 491,996; Ps. 460,008; Ps. 434,343 and Ps. 422,093 of gas transportation net revenues and Ps. 747,772; Ps. 817,506;Ps. 604,730; Ps. 559,741 and Ps. 470,702 of NGL production and commercialization and other services net revenues for the years ended December 31, 2007, 2006, 2005, 2004 and 2003, respectively. (2) Net income (loss) per share under Argentine GAAP and US GAAP have been calculated using the weighted average shares outstanding. Each American Depositary Share (“ADS”) represents five shares.
	(3) Represents additions to property, plant and equipment. For more information, see Note 3 (Consolidated Business Segment Information) to our Financial Statements, included elsewhere herein.

Dividends

Dividends may be lawfully declared and paid only out of our retained earnings reflected in our annual financial statements and approved by a Shareholders’ Meeting as described below. We have not paid dividends in the last five years, except for the dividend payment of Ps. 32.0 million (approximately US$ 10.0 million) made on May 7, 2008, approved at the annual meeting of our Shareholders held on April 10, 2008.

We may pay dividends as long as (i) no default exists under our debt obligations and (ii) immediately after giving effect to such dividend payment, (a) the consolidated coverage ratio (ratio of our consolidated adjusted EBITDA to our consolidated interest expense (each as defined in our new debt obligations issued on May 14, 2007 (the “New Debt Obligations”)) would be greater than or equal to 2.0:1; and (b) the consolidated debt ratio (ratio of our consolidated total indebtedness to our consolidated adjusted EBITDA (as each of the terms is defined in the New Debt Obligations)) would be less or equal to 3.75:1 (see “Item 10. Additional Information—C. Material contracts—New Debt Obligations”).

Our Board of Directors may declare interim dividends, in which case the members of the Board of Directors and of the Supervisory Committee are jointly and severally liable for such distribution, if such declaration is not in accordance with the Commercial Companies Law No. 19,550, as amended (the “Commercial Companies Law”) and our By-laws.

Our Board of Directors regularly submits our Financial Statements for the preceding year, together with reports thereon by the Supervisory Committee, to the Shareholders at the Annual Ordinary Shareholders’ Meeting for approval. According to Argentine law, this Ordinary Shareholders’ Meeting must be held to approve the financial statements and determine the allocation of our net income for such year. Under the Commercial Companies Law, the Shareholders are required to allocate a legal reserve equal to 5% of each year’s net income, as long as there is no unappropriated retained deficit. If there is such a retained deficit, 5% should be calculated on any excess of the net income over the unappropriated retained deficit. This appropriation is legally required until such reserve equals 20% of the sum of (i) “Common stock nominal value” plus (ii) “Cumulative inflation adjustment to common stock”, as sh own on our Consolidated Statement of Changes in Shareholders’ Equity. If the legal reserve falls below the 20% required amount, dividends may not be paid until the legal reserve has been restored to at least the required 20% threshold. The amount represented by the legal reserve is not available for distribution as dividends. Under our By-laws, after the allocation to the legal reserve has been made, an amount will be allocated to pay dividends on preferred stock, if any, and an amount equal to 0.25% of the net income for the year will be allocated to pay the participation in earnings of employee profit-sharing certificates. The remainder of the retained earnings for the year may be distributed as dividends on common stock or retained as a voluntary reserve, as determined at the Shareholders’ Meeting. Dividends must be paid within 30 days of their declaration. For information on dividend taxation, see “Item 10. Additional Information—E. Taxation—Argentine Taxes.”

Exchange Rate Information

1

Fluctuations in the exchange rate between pesos and U.S. dollars would affect the U.S. dollar equivalent of the peso price of our Class B Shares on the Buenos Aires Stock Exchange (“BASE”) and, as a result, would likely affect the market price of our ADSs as well. In addition, such fluctuations will affect the dollar equivalent of peso amounts reported in this Annual Report. Currency fluctuations would also affect the U.S. dollar amounts received by holders of American Depositary Receipts (“ADRs”) on conversion by the Depositary of cash dividends paid in pesos on the underlying Class B Shares.

The following table sets forth, for the periods indicated, high, low, average and period-end exchange rates between the peso and the U.S. dollar, as reported by Banco de la Nación. The Federal Reserve Bank of New York does not publish a noon buying rate for the peso. The average rate is calculated by using the average of Banco de la Nación reported exchange rates on each day during the relevant monthly period and on the last day of each month during the relevant annual period.

2

	Pesos per U.S. dollar
	High	Low	Average	Period end
Most recent six months:
December, 2007	3.1490	3.1320	3.1393	3.1490
January, 2008	3.1580	3.1280	3.1453	3.1580
February, 2008	3.1690	3.1510	3.1585	3.1610
March, 2008	3.1690	3.1460	3.1560	3.1680
April, 2008	3.1840	3.1530	3.1671	3.1640
May, 2008	3.1840	3.0990	3.1504	3.0990
June, 2008 (through June, 12)	3.0990	3.0530	3.0681	3.0530
Year ended December 31,
2003	3.3500	2.7600	2.9489	2.9300
2004	3.0600	2.8030	2.9414	2.9790
2005	3.0400	2.8590	2.9236	3.0320
2006	3.1070	3.0300	3.0747	3.0620
2007	3.1800	3.0580	3.1158	3.1490

For your convenience and except as we specify otherwise, this Annual Report contains translations of peso-denominated amounts to U.S. dollars at the reported exchange rate on December 31 of each year. These translations should not be construed as representations that the amounts actually represent such U.S. dollar amounts or could be or have been converted into U.S. dollars at the rates indicated or at any other rates. On June 12, 2008, the reported exchange rate was Ps. 3.0530=US$1.00.

Our results of operations and financial condition are highly susceptible to changes in the peso-U.S. dollar exchange rate because more than 40% of our revenues are peso-denominated and our primary assets are based in Argentina while substantially all of our liabilities and capital expenditures are U.S. dollar-denominated.

B.

Capitalization and Indebtedness

Not applicable.

C.

Reasons for the Offer and Use of Proceeds

Not applicable.

D.

Risk Factors

You should carefully consider the following risks and uncertainties, and any other information appearing elsewhere in this Annual Report. The risks and uncertainties described below are intended to highlight risks and uncertainties that are specific to us. Additional risks and uncertainties, including those generally affecting Argentina and the industry in which we operate, risks and uncertainties that we currently consider immaterial or risks and uncertainties generally applicable to similar companies in Argentina may also impair our business, results of operations, the value of our securities, and our ability to meet our financial obligations.

The information in this Risk Factors section includes forward-looking statements that involve risks and uncertainties. Our actual results could differ materially from those anticipated in these forward-looking statements as a result of numerous factors, including those described in “Cautionary Statement Regarding Forward-Looking Statements” above.

Risks Relating to Argentina

Overview

We are asociedad anónima and most of our operations and nearly all of our assets are located in Argentina. More than 40% of our revenues are peso-denominated. Conversely, substantially all of our indebtedness is U.S. dollar-denominated. Accordingly, our financial condition and results of operations depend

3

to a significant extent on economic, regulatory and political conditions prevailing in Argentina and on the exchange rate between the peso and the U.S. dollar. As further described below, in the past several years, Argentine economy has recovered from a severe recession and political crisis, which began in 2001 and caused devaluation of the peso against major international currencies. These conditions have adversely affected, and may continue to adversely affect, our financial condition and results of operations, and they may impair our ability to make payments of principal and/or interest on our financial indebtedness.

Political and economic instability in Argentina have adversely affected, and may continue to adversely affect, our financial condition and results of operations.

Fluctuations in the Argentine economy and actions adopted by the Argentine government have adversely affected, and may continue to adversely affect, Argentine entities, including us. Specifically, we have been adversely affected and may continue to be adversely affected by inflation, interest rates, the value of the peso against foreign currencies, price controls, business and tax regulations and in general by the political and economic environment in Argentina and in other countries that may affect Argentina.

The Argentine economy has experienced significant volatility in recent decades, characterized by periods of low or negative growth, high and variable levels of inflation and currency devaluation. During 2001 and 2002, Argentina went through a period of severe political and economic crisis. The crisis had significant and adverse consequences on our company, including (i) losses derived from the effects of the peso devaluation on us and our net borrowing position, substantially all of which was denominated in U.S. dollars, (ii) the pesification, at a rate of Ps. 1 to US$1, of our U.S. dollar-denominated gas transportation tariffs, (iii) our default on our financial indebtedness and (iv) the elimination of tariff adjustments for public utilities based on non-Argentine indexes or other indexation methods. Although the economy has recovered significantly over the past five years, uncertainty remains as to whethe r the current growth and relative stability is sustainable.

The Argentine economy could be adversely affected if developing challenges are not solved in the short term. These challenges include the confrontation between farmers and the Argentine government, growing inflation, the increasing net capital outflow, and an expanding deficit in the supply of energy.

Although the economy has recovered significantly over the past five years, uncertainty remains as to whether the current growth and relative stability is sustainable. The Argentine political and economic situations have quickly deteriorated in the past, and may quickly deteriorate in the future, and we cannot assure you that the Argentine economy will continue to grow. Sustainable economic growth is dependent on a variety of factors, including international demand for Argentine exports, the stability and competitiveness of the peso against foreign currencies, confidence among consumers and foreign and domestic investors and a stable and relatively low rate of inflation. As in recent years, Argentina’s economy may suffer if political and social pressures inhibit the implementation by the Argentine government of policies designed to maintain price stability, generate growth and enhance consumer and investor confidence. Further, Argentine government actions concerning the economy, including those related to inflation, interest rates, price controls, foreign exchange controls and taxes, have had, and might continue to have, a material adverse effect on Argentine entities, including us. We cannot provide any assurance that future economic, social and political developments in Argentina, over which we have no control, will not adversely affect our financial condition or results of operations.

Fluctuations in the value of the peso may adversely affect the Argentine economy and our financial condition, results of operations and ability to service our debt.

Since the end of U.S. dollar-peso parity in January 2002 under the Public Emergency Law No. 25,561 (the“Public Emergency Law”), the peso has fluctuated significantly in value. As a result, the Argentine Central Bank (“BCRA”) has taken several measures to stabilize the exchange rate and preserve its reserves. The marked devaluation of the peso in 2002 had a negative impact on the ability of the Argentine government and Argentine companies, including us, to honor their foreign currency-denominated debt, led to very high inflation initially and had a negative impact on businesses whose success is dependent on domestic market demand, including public utilities.

The significant peso devaluation during 2002 adversely affected our results and financial position. Substantially all of our financial debt was, and is, denominated in U.S. dollars. Before the enactment of the Public Emergency Law, our cash flow, generally denominated in U.S. dollars or dollar-adjusted, provided a natural hedge against exchange rate risks. The Argentine regulatory framework after the enactment of the Public Emergency Law, however, limited our ability to mitigate the impact of the peso devaluation. Particular aspects of

4

the regulatory framework that adversely affected us included the pesification of our tariffs at a rate of Ps. 1 to US$1 compared with an average market exchange rate since then of approximately Ps. 3 to US$1, regulatory issues related to the renegotiation of our tariffs, new taxes and other restrictions on exports of propane and butane (“LPG”).

If the peso devalues significantly, all of the negative effects on the Argentine economy related to such devaluation could recur, with adverse consequences to our business. On the other hand, a substantial increase in the value of the peso against the U.S. dollar also presents risks for the Argentine economy since it may lead to a deterioration of the country’s current account balance and the balance of payments.

We are unable to predict whether, and to what extent, the value of the peso may further depreciate or appreciate against the U.S. dollar and how any such fluctuations would affect the demand for our products and services. Moreover, we cannot assure you that the Argentine government will not make regulatory changes that prevent or limit us from offsetting the risk derived from our exposure to the U.S. dollar and, if so, what impact these changes will have on our financial condition and results of operations.

Despite the stability of the peso-U.S. dollar exchange rate in recent years, because substantially all of our indebtedness is and will continue to be U.S. dollar-denominated, potential future devaluation of the peso will negatively affect our revenues expressed in U.S. dollars while increasing the relative cost, in peso terms, of expenses and other financial obligations denominated in foreign currencies, thereby decreasing our cash-generating ability and having a material adverse effect on our liquidity and our ability to service our debt.

At May 31, 2008, the total amount of principal and interest under our consolidated U.S. dollar-denominated indebtedness was the equivalent of US$501.6 million.

Substantial inflation has occurred since the repeal of the Convertibility Law and could continue in the future, resulting in a material adverse effect on our results of operations and financial condition.

In the past, inflation has undermined the Argentine economy and the government’s ability to stimulate economic growth. Argentina experienced significant inflation from December 2001 through January 31, 2003, with cumulative changes in the Consumer Price Index (“CPI”)of 42.8% and in the WPI of 118.9%. This level of inflation reflected both the effect of the peso devaluation on production costs as well as a substantial modification of relative prices, partially offset by the elimination of public utility rate (“tariff” or “rate”) adjustments and the large drop in demand resulting from the severe recession. Inflation slowed in 2003, with the CPI increasing by 3.7% and the WPI increasing by 2.0% for the year. Further, during 2004, the CPI increased by 6.1% and the WPI increased by 7.9%. Despite the lower relative level of inflation from 2003 to 2006, inflationary pressures have increased since January 2007, resulting in greater price instability in the Argentine economy. Inflation rates reported by the INDEC since January 2007 have not reflected these increasing inflationary pressures and the INDEC numbers are considered by economic analysts to underestimate the current rate of inflation.

The unpredictability of Argentina’s inflation rate makes it impossible for us to foresee how our business and results of operations may be affected in the future by inflation. Continued inflation in Argentina without significant increase in our tariffs would have a material adverse effect on our business, results of operations and financial condition.

Argentina’s ability to stimulate sustained economic growth, appease social unrest and repay its debt may depend on external financial assistance, which has been limited and may continue to be limited in the future.

In 2001, as a result of the suspension of lending arrangements with Argentina by the International Monetary Fund (“IMF”) and Argentina’s default on approximately US$65.4 billion of its then-outstanding sovereign debt, international rating agencies downgraded the rating of Argentina’s sovereign debt to default status. The Argentine government launched a process to restructure its sovereign debt on January 14, 2005, and, on March 18, 2005, announced that 76.15% of its bondholders had accepted the restructuring offer. The Argentine government issued new bonds to the accepting holders in April 2005 and paid overdue interest accrued from December 2003. For this reason, Standard & Poor’s Rating Services increased the short and long term sovereign qualification of Argentina from “SD” to “B-”. In addition, on December 15, 2005, President Kirchner announced the early payback of the deb t to the IMF, and on January 3, 2006, a disbursement was made by the Argentine government for an amount of US$9.5 billion.

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Several legal actions have been filed in the U.S., Italy and Germany by holders of Argentina’s sovereign debt who did not participate in the restructuring, which delayed settlement of the exchange offer associated with the restructuring. A judgment against the Argentine government in such cases could result in a reduction in funding sources and investment capital, which could have a significant effect on the Argentine government’s capacity to implement reforms and reinstate sustainable economic growth, all of which could adversely affect us. In addition, the Argentine government has yet to renegotiate the terms and conditions of its defaulted debt of more than US$ 6 billion with the Club of Paris, which prevents potential European investors from borrowing money in order to do business in Argentina.

There can be no assurance that the Argentine government will not default on its obligations under the new bonds in the future. In addition, the Argentine government must continue to honor principal and interest payments to credit providers, including the World Bank, without subsequent new loans in order to avoid a default on the indebtedness owed to such providers. All such events could also impair Argentina’s capacity to maintain the current economic recovery and could result in a recession, higher inflation, unemployment and social discontent.

The BCRA has imposed restrictions on the transfer of funds outside of Argentina in the past and may do so in the future, which could prevent us from making payments on our foreign currency-denominated indebtedness.

Since the amendment of the Convertibility Law in December 2001, the Argentine government has imposed several temporary restrictions on the transfer of U.S. dollars outside of Argentina. Prior to January 2003, we were required to obtain the prior approval of the BCRA before we could transfer U.S. dollars outside Argentina to make payments of dividends and principal and interest on our debt obligations. Although current regulations do not require prior BCRA approval for these of payments, the BCRA may reinstate transfer of funds restrictions at any time. In such case, we cannot assure you that the BCRA will approve the transfer of funds outside Argentina for payments required under the terms of our foreign currency-denominated indebtedness. In addition, there may be a significant delay before payments required under the terms of our foreign currency-denominated indebtedness may be made.

We cannot assure you as to how long the current, more flexible regulations will be in effect or whether they will become more restrictive again in the future. If the Argentine government decides once again to tighten the restrictions on the transfer of funds, we may be unable to make dividend payments and principal or interest payments on our debt when they become due, which could have a material adverse effect on us.

The Argentine financial market and economy may be adversely affected by the deterioration of other emerging markets.

The Argentine financial and securities markets are, to varying degrees, influenced by economic and market conditions in other emerging market countries. Although economic conditions are different in each country, investor reaction to developments in one emerging market can have significant effects on the securities of issuers in other emerging markets, including Argentina. These developments, as well as the devaluation of various Asian, Mexican and Brazilian currencies, have adversely affected the securities markets in many emerging markets, including Argentina. The increased market volatility in these securities markets has also been attributed, at least in part, to the effect of these and other similar events. There can be no assurance that the Argentine financial and securities markets will not continue to be adversely affected by events elsewhere, especially in other emerging markets. Such events can be expected to adversely af fect the Argentine economy, which could have a material adverse effect on us.

Because the Argentine standards for corporate disclosure and accounting differ from those of the United States, information about us may not be as detailed or comprehensive as that of non-Argentine companies, including that of companies in the United States.

We are subject to the periodic reporting requirements of the Securities Exchange Act of 1934, as amended (“Exchange Act”). However, the periodic disclosure required of foreign issuers under the Exchange Act is more limited than the periodic disclosure required of companies in the United States. Furthermore, there is less extensive regulation of the Argentine securities markets and of the activities of investors in such markets as compared with the securities markets in the United States and certain other developed countries. We prepare our Financial Statements in accordance with Argentine GAAP and the regulations of the CNV, which differ in certain significant respects from US GAAP. See Note 12 to our Financial Statements for a description of the

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material differences between Argentine GAAP and US GAAP as they relate to us and for a quantification of the impact of those differences on net income for the year and our Shareholder’s equity.

Risks Relating to Our Business

Because we receive a significant portion of our net revenues from public service contracts which tariffs are no longer stated in dollars or subject to indexing, our net revenues and liquidity have been harmed as a result of inflation and the devaluation of the peso.

All of our net revenues from our gas transportation segment (which represented approximately 41% and 38% of total net revenues during 2007 and 2006, respectively) are attributable to public service contracts, which are subject to Argentine government regulation. We entered into these public service contracts primarily with natural gas distribution companies in connection with the privatization of Gas del Estado S.E. (“GdE”). Prior to the passage of the Public Emergency Law, our tariffs were stated in dollars and subject to indexing, based on semi-annual changes in the U.S. Producer Price Index (“PPI”), with adjustments every five years, based on the efficiency of, and investments in, our gas transportation operations. The Public Emergency Law, however, eliminated tariff indexation.

In accordance with the Public Emergency Law, in January 2002, public service tariffs were converted into pesos and fixed at an exchange rate of Ps. l.00=US$l.00 even as the peso was allowed to devalue against the U.S. dollar. Future gas transportation regulated tariffs may not be increased or, if increased, may not be increased to a rate that we believe is high enough to adequately compensate us. As a result, our net revenues from our gas transportation segment have been and may continue to be materially adversely affected.  

Our results of operations may be adversely affected because our License with the Argentine government is subject to renegotiation.

The Public Emergency Law authorizes the Argentine government to renegotiate public service contracts, tariffs and licenses with public utility companies on its own initiative, using the following criteria:

§

the impact of the rates on the competitiveness of the economy and on income distribution;

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the quality of the services and the investment programs contractually provided for in the service contract;

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the interests of users, as well as service access conditions;

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the operational safety of the systems concerned; and

§

the profitability of a company.

Since the enactment of the Public Emergency Law, there has not been significant progress with respect to the renegotiation of our public service contracts. In July 2003, UNIREN was created under the joint jurisdiction of theMinistry of Economy and Production and the Ministry of Federal Planning and Public Investment and Utilities (“MPFIPyS”). Little progress has been made to date in the renegotiation process with UNIREN. We cannot at this time provide any assurances with regard to the terms or the timing of any renegotiation of our License or the tariffs for our public service contracts. The deadline for the renegotiation of the public works and utilities contracts has been extended until December 31, 2008.

If our public service contracts are renegotiated, the new terms of such contracts may be less favorable than the current terms of these public service contracts, and consequently our results of operations and financial condition may be materially adversely affected. Even if our public service contracts are renegotiated on more favorable terms, those terms nonetheless may be insufficient to avoid a material adverse effect on our results of operations and financial condition. See “Item 4. Our Information—B. Business Overview—Gas Transportation—Regulatory Framework—Adjustment of Rates” below for more information.

Enron Corp. (“Enron”), the parent corporation of certain Shareholders of Compañía de Inversiones de Energía S.A. (“CIESA”), our controlling shareholder, has filed a claim with the International Centre for the Settlement of Investment Disputes (“ICSID”) against the Government of Argentina under the Bilateral

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Investment Treaty between the United States and Argentina. We understand that the claim argues that the pesification of tariffs and other unilateral changes to our regulatory structure affected by the Public Emergency Law and related laws and decrees violate the requirement of fair and equitable treatment under the treaty. On May 22, 2007, ICSID decided in favor of Enron and ordered the Argentine government to pay US$106.2 million to Enron. In two similar claims, the Argentine government is seeking the annulment of the awards in favor of the claimants. It is possible that the continued pursuit of such claim by Enron could adversely affect the timing and/or terms of any renegotiated tariff structure applicable to our gas transportation activities. The proposal of UNIREN for the renegotiation of our License requires us, and our present and former shareholders, including Enron and its affiliates, to abandon any claim or lawsuit we or they may have agai nst the Argentine government resulting from the effects of the Public Emergency Law applicable to the License and the PPI tariff adjustments that were not applied in 2000 and 2001. Additionally, the proposal would require us to hold the Argentine government harmless from any claim or lawsuit filed by any of our present or former shareholders or any compensation in favor of such shareholders and to reimburse the Argentine government for any amount paid by it to our shareholders in connection with any such claim or lawsuit. If our shareholders or shareholders of CIESA are unwilling to abandon such claims and lawsuits, our ability to secure tariff increases, and accordingly our revenues from gas transportation, may be adversely affected.

Even if our shareholders and CIESA’s shareholders abandon such claims, there is no certainty regarding when the License renegotiation process will be completed. Other similarly situated public utility companies have complied with the UNIREN requirement. Some of these companies have been able to sign agreements with UNIREN that contemplate, among other things, an initial tariff increase and a tariff adjustment scheme for the future. However, the process for future tariff increases for these companies have been significantly delayed, due to their potential impact on inflation.

In 2007, ENARGAS authorized the gas distribution company Gas Natural BAN S.A. (“BAN”), to implement an initial tariff increase of 15%. This adjustment was retroactively applicable to November 1, 2005. The resolution also includes a scheme for future adjustments. Although the adjustment could prove to be a useful benchmark in connection with further negotiations between UNIREN and the Company, no assurance can be given as to ultimate terms on which the Company may be able to secure a tariff adjustment.

Our regulated business is dependent on our ability to maintain our License, which is subject to revocation under some circumstances.

We conduct our natural gas transportation business pursuant to the License, which authorizes us to provide gas transportation services through the exclusive use of the southern gas transportation system in Argentina. The Executive Branch may revoke our License in certain circumstances based on the recommendation of ENARGAS, the governmental body charged with the regulation of the transportation, distribution, marketing and storage of natural gas. Reasons for which our License may be revoked include:

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repeated failure to comply with the obligations of our License and failure to remedy a significant breach of an obligation in accordance with specified procedures;

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total or partial interruption of service for reasons attributable to us that affects transportation capacity during the periods stipulated in our License;

§

sale, assignment or transfer of our essential assets or the placing of encumbrances thereon without ENARGAS’s prior authorization, unless such encumbrances serve to finance extensions and improvements to the gas pipeline system;

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our bankruptcy, dissolution or liquidation;

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ceasing and abandoning the provision of the licensed service, attempting to assign or unilaterally transfer our License in full or in part without the prior authorization of ENARGAS, or giving up our License, other than in the cases permitted therein; and

§

delegation of the functions granted in such contract without the prior authorization of ENARGAS, or the termination of such agreement without regulatory approval of a new contract.

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If our License were revoked, we would be required to cease providing gas transportation services. The impact of a loss of our License on our business, financial condition and results of operations would be material and adverse.

Our creditors may not be able to enforce their claims against us in Argentina.

We are a stock corporation with limited liability, orsociedad anónima, organized under the laws of Argentina. Substantially all of our assets are located in Argentina.

Under Argentine law, foreign judgments may be enforced by Argentine courts, provided that the requirements of Articles 517 through 519 of the Federal Code of Civil and Commercial Procedure are met. Foreign judgments cannot violate principles of public policy (orden público) of Argentine law, as determined by Argentine courts. It is possible that an Argentine court would deem the enforcement of foreign judgments ordering us to make a payment in a foreign currency outside of Argentina to be contrary to Argentine public policy if at that time there are legal restrictions prohibiting Argentine debtors from transferring foreign currency outside of Argentina.

Under Argentine law, attachment prior to execution and attachment in aid of execution will not be ordered by an Argentine court with respect to property located in Argentina and determined by such courts to be utilized for the provision of essential public services. A significant portion of our assets may be considered by Argentine courts to be dedicated to the provision of an essential public service. If an Argentine court were to make such determination with respect to any of our assets, unless the Argentine government ordered the release of such assets, such assets would not be subject to attachment, execution or other legal process as long as such determination stands and the ability of any of our creditors to realize a judgment against such assets may be adversely affected.

In order to mitigate the energy crisis, the Argentine government has initiated new strategies, measures and programs with respect to the gas transportation industry, including the expansion of our pipeline and the interruption of firm transportation service (including the diversion of natural gas from the Cerri Complex), which could materially adversely affect our business, results of operations and financial condition.

Since 2002, the gas industry has experienced a sharp increase in natural gas demand as a consequence of: (i) the recovery of certain industries in the Argentine economy, (ii) the 2002 devaluation of the peso and pesification of transportation and distribution tariffs and the elimination of both tariff and wellhead gas price adjustments, making this fuel relatively inexpensive for consumers as compared to other types of fuel the prices of which are affected by inflation and (iii) the growth of gross domestic product between 2003 and 2007. However, notwithstanding this increase in demand, these conditions have severely and negatively impacted the profitability of companies providing services relating to the production, transportation and distribution of natural gas.

Specifically, distribution companies have been prohibited from passing through price increases to consumers. Producers of natural gas, therefore, have been limited, if not unable, to implement wellhead gas price adjustments from 2002 until May 2004, which has caused such producers to suffer a sharp decline in their rate of return on investment activities. As a result, natural gas producers have limited their investments in exploration and production of natural gas. Likewise, the elimination of tariff adjustments for transportation companies has caused transportation companies to suffer a decrease in their profitability and, therefore, such companies have limited their investments in pipeline expansion activities. These events have contributed to the energy crisis in the natural gas industry in Argentina, where demand is exceeding available capacity.

In light of these events, the Argentine government has decided to initiate a number of strategies, measures and programs aimed at mitigating the energy crisis and supporting the recovery of the Argentine economy generally. With respect to the natural gas industry, these strategies, measures and programs include, among others, the expansion of our pipeline, through the creation of financial trust funds as vehicles to facilitate those investments. In order to finance such expansions, Law 26,095 was passed to provide for the creation of additional tariff surcharges (“cargos específicos”), which are special contributions to the gas trust fund made by the potential or actual beneficiaries of the improved gas transportation systems.

In 2005, a trust fund was created to carry out the expansion of the San Martín pipeline, resulting in a transportation capacity increase of 102 MMcf/d. In addition, in April 2006, the MPFIPyS, the Federal Energy Bureau and gas transporters, among others, signed a Letter of Intent to carry out a second, significantly larger

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expansion of the gas pipeline system. This new expansion will increase the aggregate transportation capacity of our system and the system of Transportadora de Gas del Norte S.A. (“TGN”) by 883 MMcf/d, of which almost 332 MMcf/d pertain to our system. The investment will be financed by the shippers who subscribe to the additional capacity.  It is expected that the first stage, which consists of an expansion of 78 MMcf/d, will be in operation in winter of 2008. The second stage, which will complete the total expansion, is expected to be finished in 2009. These works include the expansion of the pipeline which crosses the Magellan Straits.

Although the San Martín pipeline expansion project has not adversely affected our results of operations or financial condition, we cannot assure you that expansion projects will not in the future have such adverse effects.

Additionally, the legality of the additional tariff surcharges used to finance the gas trust fund has been challenged by users of the gas distribution system who have been charged with such tariff surcharges. Some users claim that they are not direct beneficiaries of the pipelines to be constructed and that the tariff surcharges represent a covert increase in the gas tariff. Other users claimed that there was no public hearing as stipulated in the regulations. In the event that these claims are successful, new gas pipeline expansions could be impaired and our business adversely affected.

On April 9 and April 16, 2007, we received two requests from an Argentine Federal Criminal and Correctional Court to provide information and documents relating to the role we had in the 2005 pipeline expansion project. These requests were made in connection with an investigation regarding alleged improper payments made by a sub-contractor hired by another party (other than us) engaged by the Gas Trust in connection with the construction of a portion of the 2005 expansion project, which increased the capacity of both the northern and southern gas transportation pipeline systems of Argentina. Other companies involved in the expansion of the gas transportation systems have received similar requests for information. We have complied with the requests and provided all the information and documentation requested to the extent known by or available to us. No allegations have been made against us, and we have not engaged in any illegal or improper conduct in connection with the expansion project. The investigation may, however, create a distraction for management and could potentially affect the structure or timing of the larger expansion project commenced in 2006.

Also, in 2004, the Executive Branch issued Decree No. 181/04 directing the Federal Energy Bureau to establish a system of priority pursuant to which power stations and gas distribution companies (for their residential clients) could receive natural gas in priority to other users, even those with firm transportation and firm gas supply contracts. On March 23, 2005, we received a notice from the Federal Energy Bureau that provides that from time to time, as necessary, it can require us to interrupt transportation service (including those with firm transportation contracts) to our customers in order to service power stations and gas distribution companies and that ENARGAS will set the priority of transportation in such cases.

During the winter of 2007, natural gas demand from residential users continued growing and the demand from power plants was higher than in previous years, resulting from a combination of factors that included economic growth, lower hydroelectric generation and intense cold weather recorded during this season. Natural gas production could not meet this higher demand but at no time did transportation capacity constitute a bottleneck for the supply of available natural gas to the market. However, the transportation system was affected because the Argentine government expressly instructed us to redirect gas deliveries to supply power plants, residential users and vehicles in a first rank of priority during the emergency without considering if they have firm or interruptible contracts of natural gas supply and/or transportation.

Since February 2008, the gas delivery has been managed by a committee (formed by government officials from the Domestic Commerce Bureau, the MPFIPyS and the ENARGAS), who make adjustments to the daily natural gas deliveries considering the availability of natural gas and the demand of residential consumers and power plants (the latter provided by Compañía Administradora del Mercado Mayorista Eléctrico S.A. which administers the electricity market). If there is not sufficient natural gas availability, this committee decides how to allocate the available volumes among the different types of consumers by interrupting the natural gas exports and the supply to certain big industries (mainly petrochemicals companies including the Cerri Complex), without considering if they have firm or interruptible contracts of natural gas supply and/or transportation.

Our NGL production could be adversely affected if the volume of natural gas transported by us declines, or especially if demand for natural gas continues to increase and new gas processing plants are built upstream from the Cerri Complex.

A sharp increase in natural gas demand occurred as a consequence of: (i) the recovery of certain industries in the Argentine economy, (ii) the 2002 devaluation of the peso and pesification of transportation and distribution tariffs and the elimination of both tariff and wellhead gas price adjustments, making this fuel relatively inexpensive for consumers as compared to other types of fuel the prices of which are affected by inflation and (iii) the growth of gross domestic product between 2003 and 2007. Natural gas became, by far, the cheapest fuel due to the pesification of transportation and distribution tariffs and the lack of adjustments of both these tariffs and wellhead gas prices. As a consequence, there are high rates of substitution of natural gas for other fuels, principally in power plants and vehicles. In addition, the low price of natural gas has discouraged oil and gas producers from making investments in exploration, resulting in reduced production of natural gas and a reduction in the levels of natural gas reserves.

In 2007, supply to industrial consumers, including the Cerri Complex, which has firm gas supply contracts, was restricted when high demand from firm transportation users resulting from economic growth, low hydroelectric generation and cold temperatures in winter prompted the Argentine government to instruct us to redirect firm transportation supply to power plants, residential users and vehicles. During the winter of 2007, the Cerri Complex processing was interrupted for 27 days, not including days with partial interruptions. As a result, NGL production in 2007 was the lowest in the last six years. In April and May 2008, the Cerri Complex suffered additional interruptions due to the low temperatures recorded on several days and a reduced availability of natural gas as producers performed maintenance in such months. Therefore, we are and will be adversely affected by a decrease in the natural gas supply necessary to replace our attr ibutable share of the natural gas shrinkage, fuel and losses associated with the extraction of liquids from the gas (see “Item 4.— Our Information—B. Business Overview—NGL Production and Commercialization” below).

Additionally, we could also be adversely affected by additional competition in our NGL business. In 2000, a gas processing plant was built upstream of the Cerri Complex (see “Item 4.— Our Information—B. Business Overview—NGL Production and Commercialization—Competition” below). Any other project that eventually may be developed upstream of the Cerri Complex, could adversely affect our revenues from NGL production and commercialization services.

Our NGL business is volatile and fluctuations in international prices may materially adversely affect our results of operations and financial condition.

As a result of the deterioration of our gas transportation segment and the significant increase in international prices of LPG and natural gasoline, operations relating to NGL production and commercialization have represented more than 50% of our total net revenues since 2003. Any significant decline in international prices of LPG, which have fluctuated significantly over the last ten years, or natural gasoline may materially adversely affect our results of operations and financial condition.

A significant increase in the price of natural gas may adversely affect the profitability of the NGL production and commercialization business segment.

The cost of NGL production and commercialization for our own account (see “Item 4.— Our Information—B. Business Overview—NGL Production and Commercialization” below) may increase significantly, as a consequence of the natural gas price deregulation since March 2006 and the tariff surcharges (see “Item 4.— Our Information— B. Business Overview—Gas Transportation—The Argentine Natural Gas Industry—Historical Background” below) and a situation, in which Argentina currently finds itself, where natural gas production is not enough to satisfy the current demand. Because we extract and market a significant quantity of NGL for our own account, an increase in the Argentine natural gas price may have the effect of increasing our costs, and reducing our profit, from these activities.

The affirmative and restrictive covenants in our currently outstanding indebtedness could adversely restrict our financial and operating flexibility and subject us to other risks.

Our currently outstanding indebtedness contains numerous affirmative and restrictive covenants that limit our ability to, among other things, create liens; incur additional debt; pay dividends, acquire shares of stock and make payments on subordinated debt; enter into transactions with affiliates; sell assets; or consolidate, merge or sell substantially all of our assets.

These restrictions may limit our ability to operate our businesses and may prohibit or limit our ability to enhance our operations or take advantage of potential business opportunities as they arise. The breach of any of these covenants by us or the failure by us to meet any of these conditions could result in a default under any or all of such indebtedness. Our ability to comply with these covenants may be affected by events beyond our control, including prevailing economic, financial and industry conditions and the renegotiation of public works and licenses process. In addition, if we are unable to generate sufficient cash flow from operations, we may be required to refinance outstanding debt or to obtain additional financing. We cannot assure you that a refinancing would be possible or that any additional financing would be obtained on acceptable terms.

CIESA, as principal shareholder, exercises significant control over matters affecting us.

Our controlling shareholder, CIESA, is in a position to direct our management, to control the election of a majority of the Board of Directors, to determine our dividend and other policies and to generally determine the outcome of any matter put to a vote of our shareholders. Pursuant to the procedures established by the Argentine government under which CIESA made its investment in us, there are restrictions on the ability of CIESA to reduce its shareholding in us below 51% of the share capital.

In addition, CIESA is facing a debt restructuring process (see “Item 4.— Our Information—A. Our History and Development—General” below). If the proposed Restructuring Agreement is not approved by the CNV, ENARGAS and the Argentine Antitrust Authority (Comisión Nacional de Defensa de la Competencia or“CNDC”), or any other aspect of the restructuring plan fails, CIESA may be forced into bankruptcy.

Item 4. Our Information

A.

Our History and Development

General

Transportadora de Gas del Sur S.A. commenced commercial operations on December 29, 1992, as the largest company created in connection with the privatization of GdE, the Argentine state-owned gas company, whose integrated operations included gas transportation and distribution. GdE was divided into ten companies; two transportation companies and eight distribution companies.

We are asociedad anónima, incorporated with limited liability under Argentine law on December 1, 1992. Our registered offices are located at Don Bosco 3672, 5th Floor, Buenos Aires (C1206ABF), Argentina, our telephone number is (54 11) 4865-9050 and our web address iswww.tgs.com.ar.

We are currently the largest transporter of natural gas in Argentina, delivering approximately 59% of the  total gas transported in Argentina, through 4,997 miles of pipeline, of which we own 4,682 miles. Substantially all of our transportation capacity, approximately 2.6 Bcf/d in 2007, is subscribed for under firm long-term transportation contracts. Gas transportation subscribers with firm contracts pay for the contracted pipeline capacity regardless of actual usage. Our natural gas transportation business is regulated by ENARGAS, and revenues from this business represented approximately 41% and 38% of our total net revenues in 2007 and 2006, respectively.

We conduct our natural gas transportation business pursuant to the License, which is currently scheduled to expire in 2027, extendable for an additional ten-year period at our option if certain conditions are met. This License gives us the exclusive right to operate the existing southern Argentine gas transportation pipeline system. Our system connects major gas fields in southern and western Argentina with both distributors and large consumers of gas in those regions as well as in the greater Buenos Aires area, the principal population center of Argentina.

We are also the largest processor of natural gas and one of the largest marketers of NGL in Argentina. We operate the General Cerri gas processing complex and the associated Galván loading and storage facility in Bahía Blanca in the Buenos Aires Province (the“Cerri Complex”) where NGL are separated from gas transported through our pipeline system and stored for delivery. Our NGL production and commercialization business is not subject to regulation by ENARGAS, and revenues from this segment represented approximately 53% and 55% of our total net revenues during the years ended 2007 and 2006, respectively. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

Our controlling shareholder is CIESA, which holds approximately 55.3% of our common stock. Local and foreign investors hold the remainder of our common stock. CIESA is owned 50% by Petrobras Energía S.A. (“Petrobras Energía”) (directly and indirectly through its subsidiary Petrobras Hispano Argentina S.A., which together with Petrobras Energía, we refer to herein as“Petrobras”), 40% by a trust for which ABN AMRO BANK N.V. acts as trustee (the“Trust”), and 10% by a subsidiary of Enron Pipeline Company Argentina S.A. (“EPCA”).

On April 16, 2004, Petrobras and Enron signed the Master Settlement and Mutual Release Agreement (the“Settlement Agreement”), which contemplates a two-stage reorganization of CIESA’s ownership. The first stage of the reorganization was carried out on August 29, 2005. In this first stage, Enron Argentina CIESA Holding S.A. (“EACH”) and EPCA transferred 40% of the outstanding share capital of CIESA to the Trust, and Petrobras transferred Class “B” common shares (representing 7.35% of our outstanding share capital), which it held directly and not through CIESA, to EPCA and EACH.

The second stage of CIESA’s reorganization will be implemented through the Restructuring Agreement, dated September 1, 2005, among CIESA, its current shareholders and its creditors. The Restructuring Agreement provides for a second stage in two steps. The first step, which has been completed, was the partial refinancing of CIESA’s indebtedness (due in April 2002) for approximately US$23 million. The second step, which will be completed after approval by the ENARGAS and the CNDC, will consist of (a) the cancellation of CIESA’s remaining indebtedness (the principal amount of which is US$201 million) in exchange for CIESA’s transfer to its creditors of TGS class “B” common shares that account for approximately 4.3% of TGS’s common stock, which will be simultaneously exchanged for the 10% of CIESA’s outstanding shares held by EPCA, (b) the issuance of new CIESA shares in such a manner t hat the creditors will hold 50% of the common stock of CIESA and (c) the transfer by the Trust of its CIESA shareholding to Petrobras, leaving Petrobras with the remaining 50% of CIESA’s shares.

During the last three years, our aggregate capital expenditures amounted to approximately Ps. 516.9 million. Such capital expenditures include Ps. 171.4 million related to our gas transportation system expansions (of which Ps. 80 million were financed by advances from customers), Ps. 192.7 million related to improvements to our gas transportation system, Ps. 102.9 million related to NGL production and commercialization activities and Ps. 49.9 million related to other services activities. Information relating to the size and financing of future investments is included in “Item 5. Operating and Financial Review and Prospects”.

Our most significant capital expenditure during the last three years was the finalization of our gas transportation system expansion. This project was implemented within the framework of a Trust Fund constituted by the Executive Branch of the Argentine government for the purpose of financing gas pipeline systems expansions. The expansion generated a transportation capacity increase in the General San Martín Pipeline of 102 MMcf/d and required an aggregate investment of US$ 351 million, of which US$ 311 million was financed by the investors in the Trust Fund and approximately US$ 40 million (including Value Added Tax,“VAT”) was provided by us. Eighty percent of the revenues obtained from the expanded transportation capacity will be applied towards repaying our investment.

Aside from the expansions carried out under the gas trust fund framework, we also conducted an expansion project in order to meet new firm transportation requirements for an additional capacity of 56 MMcf/d, which capacity was subscribed by Aluar Aluminio Argentino S.A.C.I. (“Aluar”) and certain natural gas producers. This expansion project involved the construction of 50 miles of loops along the San Martín pipeline and the renovation of a compressor plant. This expansion, which cost approximately Ps. 80 million, was financed by means of advance payments from the customers, which are being cancelled through the effective rendering of services. These expansions allowed an increase in our gas transportation revenues of approximately Ps. 26 million annually.

In April 2008, we conducted a new open bidding process for firm transportation capacity and our clients requested between 71 MMcf/d and 81 MMcf/d effective in 2008 and 2009, subject to the approval of ENARGAS. It is expected that the transportation expansion needed to satisfy these requests will require us to invest approximately between US$ 87 and US$ 99 millions, depending on the final contracted capacity. The investment will be totally financed by advances from clients.

B.

Business Overview

GAS TRANSPORTATION

As a transporter of natural gas, we receive gas owned by a shipper, typically a gas distributor, at one or more intake points on our pipeline system for transportation and delivery to the shipper at specified delivery points along the pipeline system. Under applicable law and our License, we are not permitted to buy or sell natural gas except for our own consumption and to operate the pipeline system. See “—Regulatory Framework” below for more information.

Our pipeline system connects major gas fields in southern and western Argentina with distributors of gas in those areas and the greater Buenos Aires area. TGN, the only other natural gas transportation operating company that supplies the Argentine market, holds a similar license with respect to the northern pipeline system, which also provides gas transportation services to the greater Buenos Aires area.

Gas transportation services accounted for approximately 41%, 38% and 43% of our total net revenues in 2007, 2006 and 2005, respectively. In 2007, approximately 93% of our average daily gas deliveries were made under long-term firm transportation contracts. (See “—Customers and Marketing” below). Firm transportation contracts are those under which capacity is reserved and paid for regardless of actual usage by the customer. All of our firm contracted capacity is currently subscribed for at the maximum tariffs allowed by ENARGAS.  During 2007, the amount of net revenues derived from firm transportation contracts was approximately Ps. 465.7 million, representing 91% of the total net revenues for the gas transportation segment.  Substantially all of our remaining gas deliveries were made under interruptible transportation contracts entered into predominantly with four gas distribution companies and industrial c ustomers. Interruptible contracts provide for the transportation of gas subject to available pipeline capacity.

Customers and Marketing

Our principal service area is the greater Buenos Aires region in central-eastern Argentina. We also serve the more rural provinces of western and southern Argentina. Our service area contains approximately 5.0 million end-users, including approximately 3.5 million in greater Buenos Aires. Direct service to residential, commercial, industrial and electric power generation end-users is mostly provided by four gas distribution companies in the area, all of which are connected to our pipeline system:MetroGas S.A. (“MetroGas”), BAN, Camuzzi Gas Pampeana S.A. (“Camuzzi Pampeana”) and Camuzzi Gas del Sur S.A. (“Camuzzi Sur”). These distribution companies serve in the aggregate approximately 67% of the distribution market in Argentina. The other five Argentine distribution companies are located in and serve northern Argentina and are not connected directly to our pipeline sy stem.

The table below contains certain information for 2007, as it relates to the distribution companies that are connected to our pipeline system:

Company	Annual Deliveries (Bcf)	% of Market Served	No. of End-Users (in million)	% of deliveries received from us
MetroGas(1)	280.7	25%	2.1	90%
Camuzzi Pampeana(1)	173.1	15%	1.1	98%
Camuzzi Sur	158.6	14%	0.5	100%
BAN(1)	144.8	13%	1.4	69%
		67%	5.1

(1)

Also connected to the TGN system.

Source: ENARGAS

The firm average contracted capacity for our four largest distribution customers, and for all other customers, as a group, at December 31, 2007, 2006 and 2005, together with the corresponding net revenues derived from firm gas transportation services during such years and the net revenues derived from interruptible services during such years are set forth below:

	December 31,
	2007		2006		2005
Firm:	Average firm contracted capacity (MMcf/d)	Net revenues (million of pesos)	Average firm contracted capacity (MMcf/d)	Net revenues (million of pesos)	Average firm contracted capacity (MMcf/d)	Net revenues (million of pesos)
MetroGas	777	176.9	795	175.4	796	172.8
Camuzzi Pampeana	452	86.3	507	87.7	388	81.3
BAN	346	68.6	366	69.5	325	64.0
Camuzzi Sur	371	20.6	363	20.5	345	19.1
Others	621	113.3	495	95.7	556	91.2
Total firm	2,567	465.7	2,526	448.8	2,410	428.4
Interruptible and others:		43.8		43.2		31.6
Total	2,567	509.5	2,526	492.0	2,410	460.0

Step-down Rights. We are required by the ENARGAS to grant all shippers of natural gas step-down rights, which permit the shippers to reduce some of their committed capacity in the zones where, as a result of open bidding, new shippers of natural gas subscribed for firm transportation capacity, so long as we do not suffer any economic harm. ENARGAS’s intention is to promote more efficient use of the pipeline system, avoiding over-subscribed capacity at levels above market demands.

Pipeline Operations

Pipeline Deliveries.The following table sets forth our average daily firm and interruptible transportation deliveries for 2007, 2006 and 2005:

	December 31,
	2007	2006	2005
Firm:	Average daily deliveries (MMcf/d)	Average daily deliveries (MMcf/d)	Average daily deliveries (MMcf/d)
MetroGas	710	699	685
Camuzzi Pampeana	364	350	335
Camuzzi Sur	261	237	222
BAN	297	286	268
Others	431	445	374
Subtotal firm	2,063	2,017	1,884
Subtotal interruptible	166	145	148
Total	2,229	2,162	2,032
Average annual load factor(1)	87%	86%	84%
Average winter heating season load factor(1)	93%	94%	92%
(1) Average daily deliveries for the period divided by average daily firm contracted capacity for the period, expressed as a percentage

Since privatization of the pipeline system, we have succeeded in increasing peak-day delivery capability, as reflected in the pipelines’ increase in average three-day peak deliveries, from 1.5 Bcf/d in 1991, as measured by GdE (no statistical data is available for 1992), to 2.4 Bcf/d in 2001, representing an increase of 55%. From 2001 to 2007 the average three-day peak deliveries has increased only slightly to 2.7 Bcf/d, representing an increase of 13% and reflecting the unfavorable investment climate since late 2001.  

Pipeline Expansions. As a result of increased availability, we have conducted several open biddings designed to provide all potential shippers with the opportunity to secure additional firm transportation capacity.

In light of the lack of expansions of the natural gas transportation system over recent years (as a consequence of the “pesification” of tariffs and the fact that the renegotiation of the License is still pending) and a growing gas demand in all segments of the Argentine economy, the Argentine government established - through Executive Branch Decree No. 180/04 and Resolution No. 185/04 issued by the MPFIPyS - the framework for the creation of a trust fund (the“Gas Trust”) with the aim of financing gas transportation system expansions.

In 2005, the first Gas Trust was constituted with the purpose of financing the expansion of the San Martín pipeline transportation capacity for approximately 102 MMcf/d. The expansion was achieved through the construction of approximately 316 miles of pipeline and a compression capacity increase of 30,000 HP through the construction of a new compressor plant and the revamping of some existing units. The work, which was finished in August 2005, partially came into service in July 2005.  

The Gas Trust invested approximately US$311 million, which will be repaid by applying 20% of the revenues generated by the additional firm contracted capacity plus a surcharge, which is ultimately paid by industries, power plants and compressed natural gas (“CNG”) suppliers for whom gas transportation supply is made under firm contracts. We invested approximately US$40 million in the expansion (including VAT in the amount of US$7 million), which we will recover through our right to collect 80% of the revenues obtained from the additional transportation capacity based on ourcurrent tariff rate (but not to the extent of any increased rate that may apply in the future). These amounts represent annual revenues of approximately Ps. 23 million. This amount is expected to be fully repaid at the end of the license period.

In April 2006, the MPFIPyS, the Federal Energy Bureau and gas transportation companies, among others, signed a letter of intent to carry out a second and much more significant expansion of the gas transportation pipeline system. The letter of intent was ratified by the Executive Branch through decree No. 660/08, issued on April 17 2008. This new expansion will increase the transportation capacity of our system and TGN’s system by a total of 883 MMcf/d, of which approximately 332 MMcf/d pertain to our system. In December 2006, the gas trust fund contracts and a project management agreement among the Federal Energy Bureau, Nación Fideicomisos S.A and us(the“Management Agreement”) was signed. Under the Management Agreement, we will receive Ps. 50 million plus VAT as a consideration for the services to be rendered for the first 247 MMcf/d of capacity.  The expansion works managemen t fee for the remaining 85 MMcf/d has not yet been determined. The expansion shall be deemed the property of a gas trust fund and the investment would be financed by other gas trust funds, whose trustors are the shippers who subscribed the additional capacity. The cost of the project will be repaid principally through the levy of a new surcharge on the industries, power plants and large and medium-size businesses, other than users of CNG for vehicles.It is expected that the first stage, which consists of an expansion of 78 MMcf/d, will be in operation in winter of 2008. The second stage, which will complete the total expansion, is expected to be finished in 2009. These works include the expansion of the pipeline which crosses the Magellan Straits.

Additionally, as we described above, we conducted the work on an expansion of our pipeline system (see “- Our history and development – General”), in order to meet new firm transportation requirements subscribed by Aluar and gas producers.

In April 2008, we conducted a new open bidding process for firm transportation capacity and our clients requested between 71 MMcf/d and 81 MMcf/d effective in 2008 and 2009, subject to the approval of ENARGAS. It is expected that the transportation expansion needed to satisfy these requests will require us to invest approximately between US$ 87 and US$ 99 millions, depending on the final contracted capacity. The investment will be totally financed by advances from clients.

System Improvements. In 2007, 2006 and 2005, we made capital expenditures in the aggregate amount of approximately Ps. 28.2 million to continue the enhancement of the pipeline system’s safety and reliability. We operate our pipelines in accordance with Argentine gas transmission safety regulations, which are substantially similar to U.S. federal regulations. We believe that, based on the pipeline inspection reports we have received to date and the pipeline repairs and/or replacements being made to the General San Martín and Neuba I pipelines, the current operation of the pipeline system poses no significant safety risks. Since the commencement of our operations in late 1992, we have implemented measures to ensure that the service would not be interrupted in any relevant consumption center; in the last five years we had not had significant ruptures in our system’s pipeline.

We conduct hydrostatic tests of our pipeline in order to identify any Stress Corrosion Cracking (“SCC”) that may occur, which tests traditionally require interruption of gas transportation service for approximately one month. Currently, this is impracticable due to high gas transportation demand. Therefore, in 2004, we contacted a Russian internal inspection service supplier, who offered us an internal inspection tool that would permit the detection of SCC without interruption of gas transportation service. In 2007, we used this tool to test 261 miles of Neuba I pipeline, obtaining positive results in the detection of SCC. In 2008, this tool will be adjusted to improve its performance and will be used to inspect 725 miles of pipeline in the Neuba I and San Martín pipelines.

Moreover we are carrying out precise diggings with a susceptibility model developed by us in order to find cracks in the area of Dolavon.

In addition, during 2007, 2006 and 2005, internal inspections were successfully carried out through 1,992 miles of pipelines in order to detect failures and damages produced by rust and corrosion, which cost amounted to approximately US$ 4.9 million. The total miles to be inspected through 2008 were established jointly with the ENARGAS.

These inspections have been performed by a supplier under a five-year agreement, which will expire in December 2008. As a result of these inspections, it will be necessary to do specific repairs, some of which included the replacement of small sections of pipelines.

Technical Assistance Agreement. As part of its bid to purchase a 70% interest in us from the Argentine government, CIESA was required to have an investor-company with experience in natural gas transmission that would serve as our technical operator. In late 1992, we entered into a Technical Assistance Agreement with EPCA, an indirect, majority-owned subsidiary of Enron. The term of the Technical Assistance Agreement was for eight years from December 28, 1992, renewable automatically upon expiration for an additional eight-year periods. The Settlement Agreement, mentioned in “—Our History and Development—General”, includes a term which provides for the assignment of the Technical Assistance Agreement to Petrobras Energía. This assignment, which was approved by ENARGAS in June 2004, was carried out on July 15, 2004. Since that date, Petrobras Energía has been our technical operator and is i n charge of providing services related to, among others, the operation and maintenance of the gas transportation system and related facilities and equipment in order to ensure that the performance of the system is in conformity with international gas transportation industry standards and in compliance with certain Argentine environmental standards.

The Technical Assistance Agreement sets out the services to be provided by Petrobras Energía to us, at the request of our Chief Executive Officer (“CEO”), in return for payment of an annual technical assistance fee equal to the greater of (i) Ps. 3 million or (ii) 7% of the amount obtained after subtracting Ps. 3 million from net income before financial income (expense) and holding gains (losses) and income taxes. The services to be provided by Petrobras Energía to us under the Technical Assistance Agreement include assisting us in the following matters to the extent that they arise in the ordinary course of business: (i) replacement, repair and renovation of facilities and equipment to ensure that the performance of the system is in accordance with international gas transportation industry standards; (ii) preparation of performance evaluations, operating cost analyses, construction assessments and advice related to budget control; (iii) advice regarding safety, reliability and efficiency of system operation and gas industry services; (iv) advice regarding compliance with applicable laws and regulations relating to safety and health, pollution and environmental protection of the system; (v) routine and preventive maintenance of the system; (vi) staff training; (vii) design and implementation of the procedures necessary to accomplish the aforesaid services; and (viii) design and implementation of a management information and inspection system for all major aspects of natural gas transportation and NGL production.

The Argentine Natural Gas Industry

Historical Background. Prior to the privatization of GdE, the Argentine natural gas industry was effectively controlled by the Argentine government. In addition, prior to its privatization, Repsol-YPF S.A. (“Repsol-YPF”) or its predecessors held exclusive rights over the development and production of all new hydrocarbon reserves in Argentina.

In 1992, the Natural Gas Act and Decrees Nos. 1,189/92 and 1,738/92 of the Executive Branch were passed providing for the privatization of GdE. The Natural Gas Act and the related decrees provided for, among other things, the transfer of substantially all of the assets of GdE to two transportation companies and eight distribution companies. The transportation assets were divided into two systems on a broadly geographical basis, the northern and southern trunk pipeline systems, designed to give both systems access to gas sources and to main centers of demand, including the greater Buenos Aires area. As a result of the division, our transportation system is connected to the two distribution systems serving the greater Buenos Aires area, one serving Buenos Aires Province (excluding the greater Buenos Aires area) and one serving southern Argentina. TGN is connected to five distribution systems serving northern Argentina. TGN is also co nnected to the distribution systems serving the greater Buenos Aires area and, to a limited extent, the distribution system serving Buenos Aires Province (excluding the greater Buenos Aires area). In the two instances where we are directly connected to a distribution system with TGN, we are the principal supplier of gas transportation services.

The Natural Gas Act and the related decrees granted each privatized gas transportation company a license to operate the transferred assets, established a regulatory framework for the privatized industry based on open, non-discriminatory access, and created ENARGAS to regulate the transportation, distribution, marketing and storage of natural gas. The Natural Gas Act also provided for the regulation of wellhead gas prices in Argentina for an interim period. Prior to deregulation, the regulated price was set at US$0.97/million British thermal units (“MMBtu”) at the wellhead, which had been the regulated price since 1991. Pursuant to Decree No. 2,731/93, gas prices were deregulated as of January 1, 1994.

On February 13, 2004, the Executive Branch signed two decrees related to the natural gas market in order to secure the adoption of measures to normalize the supply of natural gas. The Executive Branch, through Decree No. 180/04, established the creation of the MEG with the purpose of improving the transparency of financial and operating performance, the coordination of daily transactions both of the gas spot market and the transportation and distribution to secondary markets along with the shaping of efficient prices through free offer and demand interaction. To that purpose, all firm transportation capacity non-allocated for the following day is to be marketed through the MEG and the proceeds used at the discretion of the Federal Energy Bureau. Non-allocated capacity includes remaining capacity not used in any of the transportation systems or pipelines. This implies that we are bound to offer daily non-allocated capacity, which mi ght have a material impact on our interruptible transportation revenues. Despite the MEG’s commencement of operations in August 2005, it has not begun overseeing or requiring such transactions.

In spite of the devaluation of the peso, from early 2002 until May 2004 wellhead gas prices remained unchanged. This was the indirect consequence of the government prohibition on distribution companies passing through price increases implemented by producers, which made it impossible for producers to implement any increase in the wellhead gas price. From May 2004 until August 2005, wellhead gas prices increased in a range from 105% to 180% (depending on the gas basins) for power plants, industries and large businesses. For such large consumers (except for power plants), the wellhead gas price has been deregulated since March 31, 2006. Nevertheless, the natural gas price for these large consumers can not be higher than the export parity price (net of tax on exports). These adjustments were complemented by lower increases in the price of natural gas for CNG vehicles, and without any increase yet in the price of natural gas for reside ntial consumers.

Demand for Natural Gas.Natural gas consumption in Argentina has increased more than 60% from approximately 787.0 Bcf in 1993 to 1,360.7 Bcf in 2007, representing a compound annual rate of growth in consumption of approximately 4.0%. Natural gas has experienced a significant increase in market share in Argentina in recent years reaching approximately 53% of total national energy consumption in 2006 (the most recent year for which data is available), which is greater than the comparable percentage for worldwide energy consumption. Despite the relatively high market share for natural gas in Argentina as compared to other countries, significant additional potential demand for natural gas exists as a result of recent growth in the Argentine economy and the constraints on the supply of natural gas resulting from governmental restrictions on increases in the wellhead price of natural gas, as well as limits on increases in t he transportation and distribution tariffs.

The graphic below sets forth the consumption of natural gas in Argentina by class of user, stated as a percentage of total consumption, for the year ended December 31, 2007, the most recent year for which such information is available:

Source:ENARGAS

A sharp increase in natural gas demand occurred as a consequence of: (i) the recovery of certain industries in the Argentine economy, (ii) the 2002 devaluation of the peso and pesification of transportation and distribution tariffs and the elimination of both tariff and wellhead gas price adjustments, making this fuel relatively inexpensive for consumers as compared to other types of fuel the prices of which are affected by inflation and (iii) the growth of gross domestic product between 2003 and 2007. Natural gas became, by far, the cheapest fuel due to the pesification and lack of adjustment of transportation and distribution tariffs and the limited increases of wellhead gas prices. As a consequence, there are high rates of substitution of natural gas for other fuels in industries, power plants and vehicles. Likewise, the rising demand for gas also has been based on the recovery of many industrial segments of the Argentine econ omy, and the lack of availability of natural gas to meet current demand represents a challenge for continued industrial growth at the rates achieved in recent years.

The Argentine government has decided to play a decisive role in the natural gas industry through a set of measures designed to address the combination of rising demand and lower investments in exploration, production, transportation and distribution of natural gas. The goal of the measures set forth below is to reduce the impact of the energy crisis on the recovering Argentine economy:

·

creation of Energía Argentina S.A. (“ENARSA”) for the purposes of restoring levels of reserves, production and supply of natural gas and meeting the infrastructure needs of the gas transportation and electricity industries;

·

approval of graded price increases of natural gas at the wellhead, except for residential customers;

·

establishment of a framework for the constitution of trust fund vehicles to finance gas pipeline expansions;

·

creation of the MEG to improve the transparency and efficiency of daily operations through the free interaction of the offer and demand of natural gas;

·

implementation of different programs to stimulate savings of gas and electricity consumption in order to apply them in industrial activities;

·

importation of natural gas from Bolivia, electricity from Brazil and Uruguay and fuel oil and gas oil from Venezuela and others countries - the latter as an alternative fuel to natural gas - and to reduce natural gas exports to Chile and Brazil;

·

completion of the expansion work in Yacyretá Hydroelectric Plant and Atucha II Nuclear Power Plant;

·

construction of a new pipeline to transport the import of 978 MMcf/d of natural gas from Bolivia;

·

construction of two thermal power plants financed by the Argentine government and power plants; and

·

creation of tariff charges to be paid by all consumers other than residential consumers in order to finance gas and electricity expansions.

The lack of progress in the renegotiation of utility companies’ services contracts led to a failure on the part of natural gas licensees to make the investments necessary to expand pipeline capacity so as to meet increasing demand in the industry. To address this issue, the Argentine government promoted the creation of financial trust funds, such as the Gas Trust, as vehicles to facilitate those investments. Although this alternative investment structure may prove successful in addressing demand problems in the next few years, management believes that it may not be a feasible solution for financing infrastructure investments in the long-term because trust-sponsored expansions of the pipeline system are likely to be designed to permit investors in the trust to recover their investments in the short term. As a result, this structure requires significant tariff increases that are borne by a relatively small number of parties (e.g. , large industrial companies, power plants, CNG suppliers and other important commercial companies). Management believes that the capacity of all of these groups of customers to absorb tariff increases may be limited.

The financing approach taken during the 1990s by privatized companies not only resulted in a significant increase of gas transportation capacity and distribution in the gas transportation systems but also the introduction of new technologies and the development of optimal operative maintenance conditions of the systems. The excellent maintenance conditions that were developed have enabled the privatized companies to continue delivering quality in gas transportation and distribution services and respond to a growing demand, despite the inability of such companies to make additional capital investments in the systems during the Argentine economic crisis earlier this decade. However, the deterioration of the tariff regime and abrogation of the adjustment mechanism specified in the private companies’ licenses, as well as the Argentine peso devaluation, have turned Argentina into the Latin American country with the lowest cost of ga s, making it difficult for companies to raise sufficient capital to implement the expansion projects necessary to address high gas demand growth rates.

Despite the government efforts, the measures described above are insufficient to satisfy, in the short-term, the increasing demand. Furthermore it is expected that Bolivia will not be able to provide the 272 MMcf/d of natural gas that the Argentine government agreed with the Bolivian government to import. In addition, the Government of Bolivia recently announced that the additional 706 MMcf/d agreed to be supplied in 2010 should be rescheduled.

The Argentine government, through the national company ENARSA, is currently assessing the advisability of building two liquefied natural gas regasification plants (in Bahía Blanca and in Uruguay) intended to cover the natural gas market deficit. In the meantime, the Argentine government, through ENARSA, has contracted a liquefied natural gas regasification ship, which will allow the import of around 283 MMcf/d in order to cover the natural gas deficit in winter of 2008 and the following years until the plants are built. ENARGAS assigned TGS the responsibility of controlling the operation and maintenance of certain new facilities constructed to connect the regasification ship to the existing transportation pipeline.

The Argentine government is also assessing the possibility of increasing the natural gas supply in the Austral Basin, which will depend on the expansion of our gas pipeline in the Strait of Magellan scheduled for 2009. See “Item 4. Our Information—B. Business Overview—Gas Transportation—Pipeline Operations—Pipeline Expansions” above for more information.

In addition, the Argentine government has announced a new measure that will allow natural gas producers to market, at higher prices, natural gas extracted from new fields or fields that require more expensive extraction techniques.

Gas Supply. For the most part, Argentina’s gas reserves were discovered as a result of exploration for oil reserves. There are 19 known sedimentary basins in the country, ten of which are located entirely onshore, six of which are combined onshore/offshore and three of which are entirely offshore. Production is concentrated in five basins: Noroeste in northern Argentina, Neuquén and Cuyo in central Argentina, and Golfo San Jorge and Austral in southern Argentina. Approximately 64% of the gas transported by our system in 2007 originated in the Neuquén basin with the remainder coming primarily from the Austral basin. Our pipeline system is connected to the Neuquén, Austral and Golfo San Jorge basins. We are not connected to the Cuyo or Noroeste basins. Set forth in the table below is the location of the principal gas producing basins by province, their proved natural gas reserves estimated as of Dece mber 2006, production in 2006 (the last year for which information is available) and the calculated reserve life for each basin:

10

Basin	Location by province	Proved Gas  Reserves(1)(2)	Production 2006	Reserve Life(3)
		Bcf	Bcf	(years)
Neuquén	Neuquén, Río Negro, La Pampa, Mendoza (south)	6,491.8	1,050.1	6.2
Austral	Tierra del Fuego, Santa Cruz (south), and offshore	4,121.6	360.7	11.4
Golfo San Jorge	Chubut, Santa Cruz (north)	1,294.5	162.6	7.9
Cuyo	Mendoza (north)	15.2	2.2	7.5
Noroeste	Salta, Jujuy, Formosa	2,424.7	248.9	9.7
Total		14,347.8	1,824.5	7.9

 ⁽¹⁾

Estimated as of December 31, 2006. There are numerous uncertainties inherent in estimating quantities of proven reserves. The accuracy of any reserve estimate is a function of the quality of available data and engineering and geological interpretation and judgment. Results of drilling, testing and production after the date of the estimate may require substantial upward or downward revisions. Accordingly, the reserve estimates could be materially different from the quantity of gas that ultimately will be recovered.

⁽²⁾

Reserve figures do not include significant reserves located in certain Bolivian basins to which TGN is connected.

⁽³⁾

Weighted average reserve life for all basins, at 2006 production levels.

Source: Federal Energy Bureau

Neuquén Basin. The largest of the gas basins and the major source of gas supply for our system is the Neuquén basin, located in west central Argentina. The TGN system also accesses the Neuquén basin. Of the transported gas coming from the Neuquén Basin approximately 65% was transported by us and approximately 35% by TGN for the year ended December 31, 2007.

Austral and Golfo San Jorge Basins. Natural gas provided by these basins, located in the southern region of Argentina, was transported mainly by us (Camuzzi Sur also transports gas through regional pipelines). In the Austral basin, exploration has centered in and around the basin’s existing gas fields and on other fields located offshore. The Golfo San Jorge basin is primarily an oil-producing basin.

Regulatory Framework

Industry Structure. The Natural Gas Act, together with Decree No. 1,738/92, other regulatory decrees,El Pliego de Bases y Condiciones para la Privatizacion de Gas del Estado S.E.(the“Pliego”), the transfer agreements and the licenses of the newly privatized companies establish the legal framework for the transportation and distribution of gas in Argentina. Law No. 17,319 (the “Hydrocarbons Law”) regulates the midstream gas industry, under a competitive and partially deregulated system. The Public Emergency Law and related laws and regulations have had the practical effect of significantly altering the regulatory regime under which we operated until 2002. See “Item 3. Key Information—D. Risk Factors—Risks Relating to Our Business.”

Natural gas transportation and distribution companies operate in an “open access”, non-discriminatory environment under which producers and certain third parties, including distributors, are entitled to equal and open access to the transportation pipelines and distribution system in accordance with the Natural Gas Act, applicable regulations and the licenses of the privatized companies. In addition, a regime of concessions under the Hydrocarbons Law is available to holders of exploitation concessions to transport their own gas production.

The Natural Gas Act prohibits gas transportation companies from also being merchants in natural gas. Also, (i) gas producers, storage companies, distributors, and consumers who contract directly with producers may not own a controlling interest (as defined in the Natural Gas Act) in a transportation company, (ii) gas producers, storage companies and transporters may not own a controlling interest in a distribution company, and (iii) merchants in natural gas may not own a controlling interest in a transportation or distribution company.

Contracts between affiliated companies engaged in different stages in the natural gas industry must be approved by ENARGAS. ENARGAS may reject these contracts if it determines that they were not entered into on an arm’s-length basis.

ENARGAS, which was established by the Natural Gas Act, is an autonomous entity responsible for enforcing the provisions of the Natural Gas Act, the applicable regulations and the licenses of the privatized companies. Under the provisions of the Natural Gas Act, ENARGAS is required to be governed by a Board of Directors composed of five full-time directors appointed by the Executive Branch subject to confirmation by the Congress. However, since 2004 ENARGAS has been governed by three directors who were not confirmed by the Congress and, currently, ENARGAS is administered by an inspector appointed by the Executive Branch through Decree No. 571/07. Executive Branch intervention is due to investigation of ENARGAS’ possible involvement in alleged improper payments made by a sub-contractor hired by a third party engaged by the Gas Trust in connection with the construction of a portion of the 2005 expansion project, that increased th e capacity of both the northern and southern gas transportation pipeline system of Argentina. ENARGAS, which operates within the purview of the Ministry of Economy and Production and the MPFIPyS, has broad authority to regulate the operations of the transportation and distribution companies, including the ability to set rates. ENARGAS has its own budget which must be included in the Argentine National Budget and submitted to Congress for approval. ENARGAS is funded principally by annual control and inspection fees that are levied on regulated entities in an amount equal to the approved budget, net of collected penalties, allocated proportionately to each regulated entity based on its respective gross regulated revenues, excluding natural gas purchase and transportation costs in the case of distribution companies. ENARGAS also collects the fines imposed for violations of the Natural Gas Act on each company’s license.

Most of the electrical power stations do not have firm gas supply agreements and, as a result of the gas shortage in Argentina, have increasingly used imported natural gas and used alternative fuels that are more expensive than natural gas produced in Argentina. In 2004, the Executive Branch issued Decree No. 181/04, directing the Federal Energy Bureau to establish a system of priority pursuant to which power stations and gas distribution companies (for their residential clients) could receive natural gas in priority to other users, even those with firm transportation and firm gas supply contracts. On April 21, 2004, the MPFIPyS issued Resolution No. 208/04 that ratified an agreement between the Federal Energy Bureau and gas producers to give effect to this new system.  

On March 23, 2005, we received a notice from the Federal Energy Bureau that provides that, in the event there is insufficient gas available in the market to supply power stations, we can be required to interrupt transportation services (including those with firm transportation contracts) to our customers in order to give priority to gas distribution companies and power plants that have not entered into firm transportation contracts. In any such case, ENARGAS will set the priority of transportation.

Under these circumstances and our License, if ENARGAS asks us to interrupt firm transportation contracts, we will be exposed to potential claims from, among others, our customers. Therefore, we have requested that in connection with these new procedures, ENARGAS submit to us in writing instructions for any such firm transportation service interruption request. However, if ENARGAS does not accept our petition and we do not comply with ENARGAS instructions, if any, in order to avoid future claims from our customers, Resolution No. 208/04 will require us to pay the price difference between natural gas and the alternative fuel used by power stations in order to offset the loss resulting from our failure to comply with the instructions.

At the end of May 2007, due to a rise in demand resulting from unusually low temperatures throughout the country, ENARGAS and the Federal Energy Bureau utilized their authority under this resolution for the first time. ENARGAS honored our petition, and submitted written instructions to us. We complied with these instructions and do not believe that our compliance will result in legal action by any of our firm transportation clients. We have not received any judicial claims from any of our firm transportation clients as of date of issuance of this Annual Report.

During the winter of 2007, natural gas demand from residential users continued growing and the demand from power plants was higher than in previous years, resulting from a combination of factors that included economic growth, lower hydroelectric generation and intense cold weather recorded during this season. Natural gas production could not meet this higher demand, but at no time did transportation capacity constitute a bottleneck for the supply of available natural gas to the market. However, the transportation system was affected because the Argentine government expressly instructed us to redirect gas deliveries to supply power plants, residential users and vehicles in a first rank of priority during the emergency without considering if they have firm or interruptible contracts of natural gas supply and/or transportation. These governmental measures did not have a material impact on our results.

Since February 2008, the gas delivery has been managed by a committee (formed by government officials from the Domestic Commerce Bureau, the MPFIPyS and the ENARGAS), who make adjustments to the daily natural gas deliveries considering the availability of natural gas and the demand of residential consumers and power plants (the latter provided by Compañía Administradora del Mercado Mayorista Eléctrico S.A. which administers the electricity market). If there is not sufficient natural gas availability, this committee decides how to allocate the available volumes among the different types of consumers by interrupting the natural gas exports and the supply to certain big industries (mainly petrochemicals companies including the Cerri Complex), without considering if they have firm or interruptible contracts of natural gas supply and/or transportation.

Our License. Our License authorizes us to provide the public service of gas transportation through the exclusive utilization of the southern gas transportation system. Our License does not grant us an exclusive right to transport gas in a specified geographical area and licenses may be granted to others for the provision of gas transportation services in the same geographical area. TGN operates the northern gas transportation system under a license containing substantially similar terms to those described below and elsewhere herein.

Our License was granted for an original term of 35 years beginning on December 29, 1992. However, the Natural Gas Act provides that we may apply to ENARGAS for a renewal of our License for an additional ten-year term. ENARGAS is required at that time to evaluate our performance and make a recommendation to the Executive Branch. If ENARGAS determines that we are in substantial compliance with all our obligations arising under the Natural Gas Act, related regulations and our License, the renewal must be granted by the Executive Branch. ENARGAS would have the burden of proving that we had not complied with the obligations described above and, therefore, should not be granted a renewal. At the end of the 35-year or 45-year term, as the case may be, the Natural Gas Act requires that a new competitive auction be held for the license, in which we would have the option, if we have complied substantially with our obligations described above , to match the best bid offered to the Argentine government by any third party. To the extent that we were found not to have complied with the obligations described above or chose not to seek renewal of our License, we would be entitled to certain specified compensation. See “—Certain Restrictions with Respect to Essential Assets” below.

Our License also places certain other rights and obligations on us relating to the services we provide. These include:

§

operating and safety standards;

§

terms of service, including general service conditions such as specifications regarding the quality of gas transported, major equipment requirements, invoicing and payment procedures, imbalances and penalties, and guidelines for dispatch management;

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contract requirements, including the basis for the provision of service, e.g., “firm” or “interruptible”;

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mandatory capital investments to be made over the first five-years of the license term; and

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applicable rates based on the type of transportation service and the area serviced.

Our License establishes a system of penalties in the event of a breach of our obligations thereunder, including warnings, fines and revocation of our License. These penalties may be assessed by ENARGAS based, among other considerations, upon the severity of the breach or its effect on the public interest. Fines of up to Ps. 500,000 may be levied for persistent breaches. Revocation of our License may only be declared by the Executive Branch upon the recommendation of ENARGAS. Our License specifies several grounds for revocation, including the following:

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repeated failure to comply with the obligations of our License and failure to remedy a significant breach of an obligation in accordance with specified procedures;

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total or partial interruption of the service for reasons attributable to us, affecting completely or partially transportation capacity during the periods stipulated in our License;

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sale, assignment or transfer of our essential assets or otherwise encumbering such assets without ENARGAS’s prior authorization, unless such encumbrances serve to finance extensions and improvements to the gas pipeline system;

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bankruptcy, dissolution or liquidation; and

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ceasing and abandoning the provision of the licensed service, attempting to assign or unilaterally transfer our License in full or in part without the prior authorization of ENARGAS, or giving up our License, other than in the cases permitted therein.

Our License also prohibits us from assuming debt of CIESA, or from granting credit to, creating security interests in favor of, or granting any other benefit to, creditors of CIESA.

Generally, our License may not be amended without our consent. As part of the renegotiation process under the Public Emergency Law, however, the terms of our License may be changed or our License may be revoked. In addition, ENARGAS may alter the terms of service annexed to our License. If any such alteration were to have an economic effect on us, ENARGAS could modify our rates to compensate for such effect or we could request a change in the applicable rates.

Regulation of Transportation Rates—Actual Rates.The gas transportation rates established under each transportation company’s license must be calculated in U.S. dollars and converted into pesos at the time of billing pursuant to the terms of such license. However, the Public Emergency Law eliminated tariff indexing covenants based on U.S. dollar exchange rate fluctuations and established a conversion rate of one peso equal to one U.S. dollar for tariffs.

The transportation rate for firm transportation services consists of a capacity reservation charge and is expressed as a maximum monthly charge based on the cubic meters per day of reserved transportation capacity. The rate for interruptible transportation service, which is expressed as a minimum (from which no discounts are permitted) and a maximum rate per 1,000 m³ of natural gas transported, is equivalent to the unit rate of the reservation charge for the firm service based on a load factor of 100%. For both firm and interruptible transportation services, customers are obligated to provide a natural gas in-kind allowance, expressed as a maximum percentage of gas received, equivalent to the gas consumed or lost in rendering the transportation service. The rates for all services reflect the rate zone(s) traversed from the point of receipt to the point of delivery.

The table below sets out our local firm and interruptible rates by pipeline and zones, in effect as of the date of this Annual Report (which have not changed since January 1, 2000):

			Firm	Interruptible
Rate Zones			Reservation Charge(1) (Ps.m3/d)	Minimum Charge(2) (Ps.1,000 m3/d)	Compression Fuel and Losses(3) (%)
Receipt	Delivery
From Tierra del Fuego to:	Tierra del Fuego		0.076	2.541	0.49
	Santa Cruz Sur		0.154	5.123	0.98
	Chubut Sur		0.392	13.068	3.38
	Buenos Aires Sur		0.462	15.396	5.60
	Bahía Blanca		0.707	23.583	8.40
	La Pampa Norte		0.705	23.500	8.60
	Buenos Aires		0.828	27.593	10.35
	Greater Buenos Aires		0.929	30.959	11.27
From Santa Cruz Sur to:	Santa Cruz Sur		0.077	2.575	0.49
	Chubut Sur		0.315	10.508	2.89
	Buenos Aires Sur		0.385	12.841	5.11
	Bahía Blanca		0.632	21.071	7.91
	La Pampa Norte		0.632	21.067	8.11
	Buenos Aires		0.753	25.093	9.86
	Greater Buenos Aires		0.854	28.470	10.78
From Chubut to:	Chubut Sur		0.077	2.554	0.49
	Buenos Aires Sur		0.144	4.788	2.71
	Bahía Blanca		0.383	12.768	5.51
		La Pampa Norte	0.402	13.406	5.71
		Buenos Aires	0.498	16.598	7.46
		Greater Buenos Aires	0.594	19.790	8.38
From Neuquén to:	Neuquén		0.068	2.334	0.49
	Bahía Blanca		0.331	11.018	2.80
	La Pampa Norte		0.356	11.868	3.15
	Buenos Aires		0.448	14.923	3.91
	Greater Buenos Aires		0.548	18.315	4.86

(1)

Monthly charge for every cubic meter per day of reserved transportation capacity.

(2)

Minimum charge equal to the unit rate of the firm reservation charge at a 100% load factor.

(3)

Maximum percentage of total transported gas which customers are required to replace in-kind to make up for gas used by us for compressor fuel or losses in rendering transportation services.

Source:  ENARGAS Resolution No. 2,496/02 (gross receipts tax is not included in such transportation rates)

Adjustment of Rates. Under our License, we may be permitted to adjust rates semi-annually to reflect changes in PPI and every five years in accordance with efficiency and investment factors to be determined by ENARGAS and, subject to ENARGAS’s approval, from time to time to reflect cost variations resulting from changes in the tax regulations (other than income tax) applicable to us, and for objective, justifiable and non-recurring circumstances. However our ability to make these adjustments has been repealed by the Argentine government as part of the Public Emergency Law.

The Natural Gas Act requires that in formulating the rules that apply to the setting of future rates, ENARGAS must provide the transportation companies with (i) an opportunity to collect revenues sufficient to recover all proper operating costs reasonably applicable to service, taxes and depreciation, and (ii) a reasonable rate of return, determined in relation to the rate of return of businesses having comparable risk taking into account the degree of efficiency achieved and the performance of the company in providing the service. No assurances can be given that the rules to be promulgated by ENARGAS will result in rates that will enable us to achieve specific earnings levels in the future.

Since January 1, 2000, adjustments to tariffs to reflect PPI variations were suspended, first through an agreement with the Executive Branch and later by a court decision arising from a lawsuit started to determine the legality of tariff adjustment through indexes. In light of this situation, we continued recording the higher incomes derived from semi-annual PPI increases until December 31, 2001. However, since the approval of the Public Emergency Law, we deemed that tariff adjustment to reflect PPI—which was legitimate according to the regulatory framework agreed upon in the privatization—had become unlikely, as the possibility of its recovery was subject to future events beyond our control. Therefore, in 2001, we recorded a loss of Ps. 126.7 million related to the deferral of semi-annual PPI adjustments accrued during 2000 and 2001, and, since 2002, we have discontinued such accrual. This does not mean that we waive the rights and the actions we are entitled to under the regulatory framework. We intend to continue to maintain and exercise such rights and actions in every available legal and administrative venue, including the renegotiation process under the Public Emergency Law.

As mentioned above, tariff adjustments contemplated within the regulatory framework are no longer effective since the approval of the Public Emergency Law in early 2002, which among other provisions eliminated tariff indexing increases based on U.S. dollar exchange rate fluctuations, foreign price indexes or any other indexing procedure and established a conversion rate of one peso to one U.S. dollar for tariffs. The Public Emergency Law also granted the Executive Branch power to renegotiate contracts entered into with private utility companies, pursuant to the framework included in the Public Emergency Law. The Public Emergency Law has been extended until December 31, 2008.

In July 2003, UNIREN was created under the joint jurisdiction of the Ministry of Economy and Production and the MPFIPyS. This unit, which is the successor of the former Committee for the Renegotiations of Public Services and Works Contracts, will conduct the renegotiation of contracts related to utilities and public works, and is empowered to reach total or partial agreements with the licensees and submit proposals regulating the transitory adjustment of tariffs and prices, among other things. No progress was made in the renegotiation process until December 2003, when we discussed preliminary documents with UNIREN, including (i) the renegotiation guidelines, which determined the preparation of an agenda and a schedule for its discussion, (ii) a draft agenda which was outlined in order to deal with main issues such as costs, investments programs and financing, rates of return and tariffs, etc. and (iii) a schedule, which settled for the renegotiation of the regulatory framework.

In July 2004, UNIREN submitted to us a proposal for the adjustment of the contractual terms and conditions of our License, which provides for, among other things, a tariff increase of 10% effective as from January 2005 and an overall tariff review to become effective beginning 2007. Further, it requires our abandonment and the abandonment of our shareholders of any claim or lawsuit resulting from the effects of the Public Emergency Law on our License prior to the effectiveness of a renegotiation of our License, as well a requirement that we hold the Argentine government harmless from any claim or lawsuit filed by our shareholders or reimburse the Argentine government for any amount paid by it to our shareholders in connection with any such claim or lawsuit.

As this proposal differed from discussions we previously had with UNIREN, we rejected it, choosing instead to seek to reach an overall agreement with UNIREN by the end of 2004 (in line with what had been originally outlined by UNIREN in the “Preliminary Renegotiation Guidelines”) and to carry out the process of obtaining approval from the National Congress during the first semester of 2005.

On March 10, 2005, UNIREN called for a public hearing, which was held on April 27, 2005, to discuss its proposal presented in July 2004. During the hearing, UNIREN reaffirmed its offer of a 10% tariff increase and its proposal to continue the process of the overall tariff revision, so that the resulting tariff adjustments would come into effect during 2006. Regarding the abandonment of claims against the Argentine government resulting from the Public Emergency Law, UNIREN outlined a first stage that included the postponement of the potential claims by us and our shareholders, prior to a renegotiation of our License, to be followed by the abandonment of any such claims by us or our shareholders to any claim or lawsuit, and our agreement to hold harmless the Argentine government. We informed UNIREN that, regarding the original proposal, it has the imperative to negotiate an overall agreement of our License and, since some points of t he UNIREN proposal required improvement, we expressed our willingness to continue discussing it.

In June and November 2005, we received two proposals from UNIREN which were in line with the previous one. These proposals also established, as an additional condition, the Company’s, and any of our shareholders, abandonment of any future claim or lawsuit regarding the PPI tariff adjustments which were not applied in 2000 and 2001. We responded to the proposals by declaring that the original 10% increase was insufficient. We did commit not to make any administrative, arbitration or judicial claim or lawsuit in Argentina or abroad, as long as a reasonable renegotiation agreement is reached. Moreover, we stated our intention to make our best efforts to obtain similar commitments from our investors.

In November 2005, in response to the request made by the UNIREN, CIESA and Petrobras Energía Holding (as CIESA’s shareholder) confirmed that they have not initiated nor do they have the intention of initiating in the future a claim against the Argentine Republic. However, Ponderosa Assets L.P. (“Ponderosa”) as a controlling company of EPCA and EACH (both our shareholders at that time, and in the case of EPCA, currently CIESA’s minority shareholder), gave information regarding the existence of a claim which, jointly with Enron, has been initiated against the Argentine Republic before the ICSID. Ponderosa stated it would consider withdrawing its claim only in the event it was fairly compensated. On May 22, 2007, ICSID decided against the Argentine government and ordered it to pay US$106.2 million to Enron.

During 2006, the UNIREN made two new proposals to us with the same guidelines established in the previous proposals, reflecting no significant progress in the tariff renegotiation process. Since then, although negotiations continued between the UNIREN and us, we have not arrived at an agreement on tariff re-composition.

Certain Restrictions with Respect to Essential Assets. A substantial portion of the assets transferred by GdE were defined in our License as essential to the performance of the licensed service. Pursuant to our License, we are required to segregate and maintain the essential assets, together with any future improvements thereon, in accordance with certain standards defined in our License.

We may not for any reason dispose of, encumber, lease, sublease or lend essential assets for purposes other than the provision of the licensed service without ENARGAS’s prior authorization. Any extensions or improvements that we may make to the gas pipeline system may only be encumbered to secure loans that have a term of more than one year to finance such extensions or improvements.

Upon expiration of our License, we will be required to transfer to the Argentine government or its designee the essential assets specified in our License as of the expiration date, free of any debt, encumbrance or attachment, receiving compensation equal to the lower of the following two amounts:

§

the net book value of the essential assets determined on the basis of the price paid by CIESA for shares of our common stock plus the original cost of subsequent investments carried in U.S. dollars in each case adjusted by the PPI, net of accumulated depreciation in accordance with the calculation rules to be determined by ENARGAS (since the enactment of Public Emergency Law, this provision may no longer be valid); or

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the net proceeds of a new competitive bidding.

Under Argentine law, an Argentine court will not permit the enforcement of a judgment on any of our property located in Argentina which is determined by the courts to provide essential public services. This may adversely affect the ability of a creditor to realize a judgment against our assets.

Under a transfer agreement we entered into in connection with the privatization of GdE (the “Transfer Agreement”), liabilities for damages caused by or arising from the GdE assets are allocated to either GdE or us depending whether any such damage arose or arises from the operation of the assets prior to or following the commencement of our operations (“Takeover Date”). Also, pursuant to the Transfer Agreement, we are responsible for any defects in title to such assets, although any such defects are not expected to be material. The Transfer Agreement further provided that GdE was responsible for five years until December 1997 for the registration of easements related to the system which were not properly recorded and for the payment to property owners of any royalties or fees in respect thereof. Since 1998, we have been responsible for properly recording any remaining easement agreements and for ma king payments of royalties or fees related to such easements. See “Item 8. Financial Information.”

Competition

Our gas transportation business faces only limited direct competition. Although there are no regulatory limitations on entry into the business of providing gas transportation services in Argentina, the construction of a competing pipeline system would require substantial capital investment and the approval of ENARGAS. Moreover, as a practical matter, a direct competitor would have to enter into agreements with distribution companies or end-users to transport a sufficient quantity of gas to justify the capital investment. In view of our current firm transportation contracts with our distribution company customers, and the other characteristics of the markets in which we operate, management believes that it would be very difficult for a new entrant to the transportation market to pose a significant competitive threat to us, at least in the short to intermediate term. In the longer term, the ability of new entrants to successfully pen etrate our market would depend on a favorable regulatory climate, an increasing and unsatisfied demand for gas by end-users, and sufficient investment in downstream facilities to accommodate increased delivery capacity from the transportation systems.

To a limited extent we compete with TGN on a day-to-day basis for interruptible transportation services and from time-to-time for new firm transportation service made available as a result of expansion projects to the distribution companies to whom both we and TGN are either directly or indirectly connected (Camuzzi Pampeana, MetroGas and BAN). We compete directly with TGN for the transportation of gas from the Neuquén basin to the greater Buenos Aires area. The following chart shows the contracted firm capacity by Camuzzi Pampeana, Metrogas and BAN from the Neuquén basin with us and TGN:

	TGS	TGN
	Bcf/d
Camuzzi Pampeana	451.4	8.8
MetroGas	778.2	89.7
BAN	346.9	152.2

Additionally, this situation will be affected by the operation of the MEG, which by Decree requires that all firm transportation capacity not allocated for the following day must be marketed through the MEG and the proceeds from that capacity sale must be used in accordance with the Federal Energy Bureau’s requirements. For further information, see “Item 4. Business Overview—Gas Transportation—The Argentine Natural Gas Industry.”

The cost of gas relative to competing fuels may also affect the demand for transportation services in the long term. The delivery cost of gas to end-users in Argentina, based on energy content, is currently significantly lower than other alternative fuels, except for hydroelectric power.

Currently theNoreste pipeline is the most important pipeline project, lead by the Argentine government, which may connect the Bolivian natural gas basins with the northeastern region of Argentina and the greater Buenos Aires region. The capacity of this pipeline is anticipated to be approximately 978 MMcf/d. Construction of this gas pipeline is expected to start in 2008, with the pipeline beginning operation in 2010. However, there are some uncertainties when the natural gas supply from Bolivia to be transported in this new pipeline will be available. The Bolivian government has expressed its desire to reschedule the initiation of the supply of the committed 706 MMcf/d.

In addition, the Argentine government, through the national company ENARSA, is currently assessing the advisability of building two liquefied natural gas regasification plants (in Bahía Blanca and in Uruguay) intended to cover the natural gas market deficit.

These large new projects might reduce future investments in the exploration of fields from which we transport gas and consequently could decrease the volumes transported, adversely affecting our revenues from the gas transportation and NGL production and commercialization business segments.

NGL PRODUCTION AND COMMERCIALIZATION

NGL production and commercialization activities are not subject to regulation by ENARGAS. However, over recent years, in order to guarantee sufficient supply of LPG for local market at low prices, the Argentine government enacted Law No. 26,020, which is described in further detail below.

Our NGL production and commercialization activities are conducted at our Cerri Complex, which is located near the city of Bahía Blanca. In the Cerri Complex, ethane, LPG and natural gasoline are extracted from the natural gas, which arrives through three main pipelines from the Neuquén and Austral gas basins. The owners of the extracted NGL are required to make in-kind deliveries of additional gas to replace their attributable share of the natural gas shrinkage, fuel and losses associated with the extraction of liquids from the gas. We operate our NGL business under two different types of contractual arrangements:

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NGL production and commercialization for our own account: Under this type of arrangement, the NGL products obtained at Cerri belong to us. We make in-kind deliveries of additional gas to replace thermal units consumed in the NGL production process and agree with the natural gas distributors and certain producers on the payment of richness contribution incentives in order to maximize the NGL production in the Cerri Complex. This category of our NGL business is most important in terms of revenue, percentage of transactions and profit.

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NGL production and commercialization on behalf of third parties: We also process natural gas and market the NGL products in exchange for a commission based on a percentage on the sale price. In some cases we process the natural gas and deliver the NGL products to the gas producers who pay us a percentage on average monthly sale price obtained from our sales in the domestic or international markets (depending on the contract).

In the local market, we sell our production of LPG to marketers at prices semi-annually set by the Federal Energy Bureau.

Our export sales of LPG are sold to Petrobras International Finance Company (“PIFCo”), a subsidiary of Petrobras Petróleo Brasileiro S.A., under a 36-month term agreement which will expire on August 31, 2009. The contract provides for sales of approximately 242,506 short tons per year at the price quoted in Mont Belvieu, Texas, less a fixed discount per metric ton. Natural gasoline is also sold to PIFCo under an agreement expiring on December 31, 2009. This agreement provides for sales of approximately 9,921 short tons per month at NWE Ara price, less a fixed discount per metric ton.

Ethane is sold to PBB Polisur S.A. (“PBB”) under a 10-year agreement that will expire on December 31, 2015. The minimum volume of ethane committed by us to sell PBB is 370,376 short tons per year. The price is fixed until December 31, 2007, and then will be adjusted based on various factors including the PPI, the natural gas price, the quality of the ethane shipped by us and the transportation tariffs and charges.

This business segment also comprises storage and dispatch by truck and subsequent shipment of the NGL extracted at the Cerri Complex in facilities located in Puerto Galván. LPG and natural gasoline are transported via two eight-inch pipelines to the loading terminal at Puerto Galván. Ethane is piped via an eight-inch pipeline to the PBB olefins plant, which is the sole outlet for ethane from the Cerri Complex. Any ethane extracted in the Cerri Complex which can not be sold to PBB is reinjected into the pipeline.

The NGL production and commercialization segment increased its percentage of our total revenues from 19% in 2001 to 53% in 2007, as a consequence of the adverse change in the regulated gas transportation segment, and the rises in the international prices of LPG and natural gasoline experienced during recent years, which generated principally higher revenues from exports.

The annual sales for the Cerri Complex for 2007, 2006 and 2005 in short tons were as follows:

	2007	2006	2005
Ethane	336,947	419,131	376,678
LPG	460,474	592,657	498,542
Natural gasoline	101,727	126,491	108,260
Total	899,148	1,138,279	983,480

In addition, our management anticipates that future expansions on the pipeline system will provide new opportunities in the NGL production and commercialization business and lead to related increases in revenues from our gas transportation and NGL production and commercialization businesses.

A sharp increase in natural gas demand occurred as a consequence of: (i) the recovery of certain industries in the Argentine economy, (ii) the 2002 devaluation of the peso and pesification of transportation and distribution tariffs and the elimination of both tariff and wellhead gas price adjustments, making this fuel relatively inexpensive for consumers as compared to other types of fuel the prices of which are affected by inflation and (iii) the growth of gross domestic product between 2003 and 2007. Natural gas became, by far, the cheapest fuel due to the pesification of transportation and distribution tariffs and the lack of adjustments of both these tariffs and wellhead gas prices. As a consequence, there are high rates of substitution of natural gas for other fuels, principally in power plants and vehicles. In addition, the low price of natural gas has discouraged oil and gas producers from making investments in exploration, resulting in reduced production of natural gas and a reduction in the levels of natural gas reserves.

In 2007, supply to industrial consumers, including the Cerri Complex, which has firm gas supply contracts, was restricted when high demand from firm transportation users resulting from economic growth, low hydroelectric generation and cold temperatures in winter prompted the Argentine government to instruct us to redirect firm transportation supply to power plants, residential users and vehicles. During the winter of 2007, the Cerri Complex processing was interrupted for 27 days, not including days with partial interruptions. As a result, NGL production in 2007 was the lowest in the last six years. In April and May 2008, the Cerri Complex suffered additional interruptions due to the low temperatures recorded on several days and a reduced availability of natural gas as producers performed maintenance in such months.

Law No. 26,020, enacted in April 2005, set the framework through which the Federal Energy Bureau establishes regulations meant to cause LPG suppliers to guarantee supply and price stability of said products in the domestic market. Consequently, we shall not be able to select freely the markets to allocate LPG production and we need a written authorization from Federal Energy Bureau for each export operation. As we are effectively required to meet domestic demand before exporting significant amounts of LPG, we are not able to take full advantage of rising international prices, and consequently run the risk of relinquishing revenues from foreign markets with higher prices than those established for local consumers, which have remained fixed since September 2005 by the Federal Energy Bureau, in order to satisfy the minimum market demand stated by the Federal Energy Bureau.

Since 2002, LPG and natural gasoline exports have been subject to a tax on export. In May 2004, the effective tax rate for LPG exports was increased from 4.76% to 16.67%. On May 24, 2007, it was increased to 20%.

Currently, a variable export tax regime is in force, with a minimum effective tax rate of 31.03% when LPG and natural gasoline international prices are lower than US$ 663 and US$ 920 per metric ton, respectively. See “Item 5. Operating and Financial Review and Prospects. A. Operating results—Discussion of results of operations for the three years ended December 31, 2007, 2006 and 2005” for more information.

Competition

Repsol-YPF, together with Petrobras Petroleo Brasileiro and Dow Chemical, created Compañía MEGA S.A. (“MEGA”), which, at the end of 2000, finished building and began operation of a gas processing plant with a capacity of approximately 1.3 Bcf/d, located in the Province of Neuquén. Any resulting lower production associated with gas with lower liquids content arriving at the Cerri Complex, as well as any other project that eventually may be developed upstream of the Cerri Complex, could adversely affect our revenues from NGL production and commercialization services. To minimize the revenue impact of any project developed upstream of the Cerri Complex, during 2000 and 2001, we signed agreements with gas producers and distributor customers to maximize the richness of the gas to be processed at the Cerri Complex in order to have access to the associated liquids. Also, in December 2005, we agreed with major gas producers from the Austral basin to process their natural gas in the Cerri Complex for a ten year term, and we obtained their commitment to not build gas processing plants upstream of the Cerri Complex during this term.

OTHER SERVICES

Other services activities are not subject to regulation by ENARGAS

Our other services are mostly comprised of midstream activities and telecommunication services. Our midstream activities consist of gas treatment at the wellhead, which include the separation and removal of impurities such as water, carbon dioxide and sulfur from the natural gas stream. Small diameter pipes from the wellheads form a network, or gathering system, carrying the gas stream to larger pipelines where field compression is sometimes needed to inject the gas into our large diameter gas pipelines. In addition, we also provide services related to pipeline construction, inspection and maintenance.

In March 2006, we finalized the construction of a treatment and compression plant which belongs to Sipetrol Argentina S.A. (a subsidiary of Chile’s national oil company Empresa Nacional del Petróleo - ENAP) at its Tierra del Fuego reception base, which receives gas from the offshore area CAM2A/south of the Poseidón platform. Further to the construction service, we render treatment and compression services to this new plant for a five-year term. As a result of the agreements mentioned above, we were able to obtain a contract for the natural gas supply of 11 MMcf/d for our liquids business.

In 2006, we also completed the construction of a 14-inch link pipeline for a length of 9 miles, with a transportation capacity of 106 MMcf/d, that links the Agua del Cajón field (operated by Capex S.A.) to the main pipeline Neuba I, in the province of Neuquén.

In April 2007, we finalized the construction of a 16-inch link pipeline for a length of 35 miles in the province of Chubut for Aluar, which is designed  to increase gas volume to meet the operative needs of its plant expansion.

Also, during 2007, we renewed many of our service contracts related to other services, which will help to ensure the performance of the business in the mid-term.

We will continue to pursue the development of new projects both in the domestic and regional markets, to add value to potential customers who may benefit from our know-how and experience both in the natural gas market and our by-products.

Telcosur (Telecommunications System)

We own 99.98% of Telcosur, a telecommunications company formed in September 1998 for the purpose of providing value-added and data transportation services through the use of our existing telecommunications infrastructure (which was installed for purposes relating to our gas transportation system).

During 2001, we completed a capacity expansion project of our telecommunication system by investing US$ 26 million in a start up modern microwave digital system with synchronous digital hierarchy (or SDH) technology.

Additionally, to meet an increasing demand for cellular phone lines and internet broadband connections, and due to the expansion of our network between Bahía Blanca and Río Grande, in 2006, Telcosur increased the volume of existing business with operators and corporate clients, both by attracting new clients and renegotiating existing business agreements to enlarge the scope of the rendered services, provide for tariff increases and extend the term of such agreements.

In 2007, Telcosur implemented an expansion of our network capacity from Bahía Blanca to Comodoro Rivadavia through an investment of US$ 0.9 million. Currently, Telcosur is implementing the expansion of our network capacity from Comodoro Rivadavia to Río Gallegos with a cost of US$ 0.8 million, which we expect to complete in September 2008. Due to Telcosur’s commitment to safety and environmental protection, Moody International Group certified in December 2006 Telcosur’s Quality Management System in line with ISO 9001 standards and Telcosur’s Environmental Management System along with ISO 14001 standards.

C.

Organizational Structure

The following is a summary diagram of our subsidiaries and affiliates as of the date of this Annual Report, including information about ownership and location:

⁽¹⁾ Incorporated in Argentina

⁽²⁾Incorporated in Uruguay

⁽³⁾Incorporated in Brazil

The following table sets forth certain information, with respect to each shareholder known to us to own more than five percent of our common stock as of April 30, 2008:

Name of Beneficial Owner	Number of Shares	% TotalCommon Shares	Class
CIESA	405,192,594	51.0000	A
CIESA	34,133,200	4.2962	B
D.E. Shaw Laminar Emerging Markets L.L.C. (“D.E. Shaw”)	60,803,041	7.653	B

As of April 30, 2008 a total of 19,012,058 ADRs, representing 95,060,290 Class B shares, were held by approximately 60 institutional investors and mutual funds. Because certain of these ADRs are held by nominees, the number of record holders may not be representative of the number of beneficial owners.

D.

Property, Plant and Equipment

Gas Transportation

The principal components of the pipeline system we operate are as follows:

Pipelines. We render gas transportation service through a pipeline system of 4,997 miles long, of which we own 4,682 miles. The system consists primarily of large diameter, high pressure pipelines intended for the transportation of large volumes of gas at a pressure of approximately 60-70 kg/cm². Line valves are installed on the pipeline at regular intervals, permitting sections of the pipeline to be isolated for maintenance and repair work. Gas flow regulating and measurement facilities are also located at various points on the system to regulate gas pressures and volumes. In addition, a cathodic protection system has been installed to protect the pipeline from corrosion and significantly reduce metal loss. All of the pipelines are located underground or underwater.

Maintenance bases. Maintenance bases are located adjacent to the gas pipeline system in order to maintain the pipeline and related surface facilities and to handle any emergency situations which may arise. Personnel at these bases periodically examine the pipelines to verify their condition and inspect and lubricate pipeline valves. Personnel at the bases also carry out a cathodic protection system to ensure that adequate anti-corrosion systems are in place and functioning properly. They also maintain and verify the accuracy of measurement instruments to ensure that these are functioning within appropriate industry standards and in accordance with the specifications contained in our service regulations.

Compressor plants. Compressor plants along the pipelines recompress the gas volumes transported in order to restore pressure to optimal operational levels, thereby ensuring maximum use of capacity as well as efficient and safe delivery. Compressor plants are spaced along the pipelines at various points (between 62 and 124 miles) depending upon certain technical characteristics of the pipelines and the required pressure for transport. Compressor plants include turbine-driven compressors or motor-driven compressors which use natural gas as fuel, together with electric power generators to supply the complementary electrical equipment (control and measurement devices, pumping, lighting, communications equipment, etc.).

We transport gas through four major pipeline segments: General San Martín, Neuba I, Neuba II and Loop Sur, as well as several smaller gas pipelines. Information with respect to certain aspects of our main gas pipelines as of December 31, 2007, is set out in the table below:

Major Pipeline	Length Miles	Diameter (inches)	Maximum Pressure (kg/cm2)	Compressor Units	Operative Compressor Plants	HP Output
General San Martín	2,081	24/30	60	54	17	372,800
Neuba I/Loop Sur	731	24/30	60	11	4	52,550
Neuba II	1,064	30/36	70	18	6	145,980
Other(1)	806	Various	Various	6	3	7,760
Total	4,682			89	30	579,090

(1)

Includes 247 miles of transfer pipelines throughout the pipeline system, as well as the Cordillerano pipeline, with a length of 239 miles.

General San Martín. This pipeline was built in three stages, completed in 1965, 1973 and 1978, and transports gas from the extreme southern portion of Argentina to the greater Buenos Aires area in east-central Argentina. It originates in San Sebastián (Tierra del Fuego), passes through the Straits of Magellan and the Provinces of Santa Cruz, Chubut, Río Negro and Buenos Aires (including the Cerri Complex located near the city of Bahía Blanca in central Argentina), and terminates at the high pressure transmission ring around the city of Buenos Aires. The pipeline receives natural gas from the Austral basin at the extreme south in Tierra del Fuego, from the same basin further north at El Cóndor and Cerro Redondo, in the Province of Santa Cruz and from the San Jorge basin in northern Santa Cruz and southern Chubut provinces. The pipeline serves principally the districts and cities of Buenos Aires, La Pl ata, Mar del Plata, Bahía Blanca and Comodoro Rivadavia. We have expanded this pipeline significantly over the years, most recently in August 2005. See “Item 4. Our Information—B. Business Overview—Gas Transportation—Pipeline Operations—Pipeline Expansions” for more information.

Neuba I (Sierra Barrosa-Bahía Blanca). Neuba I was built in 1970 and was expanded by us in 1996. It is one of our two main pipelines serving our principal source of gas supply, the Neuquén basin. The pipeline originates in west-central Argentina at Sierra Barrosa (Province of Neuquén), passes through the provinces of Río Negro, La Pampa and Buenos Aires, and terminates at the Cerri Complex. This pipeline transports the gas received from the Neuquén basin, particularly from the Sierra Barrosa, Charco Bayo, El Medanito, Fernández Oro, Lindero Atravesado, Centenario, Río Neuquén and Loma de la Lata gas fields. The gas delivered from Neuba I is subsequently compressed and injected into the Loop Sur and the General San Martín pipelines for transportation north to the greater Buenos Aires area.

Loop Sur. This gas pipeline was built in 1972 as an extension of Neuba I and runs parallel to a portion of the General San Martín gas pipeline. Located in the province of Buenos Aires, it transports gas from the terminus of Neuba I at the Cerri Complex at Bahía Blanca and terminates at the high pressure transmission ring around Buenos Aires, which we also operate. The gas delivered by this gas pipeline constitutes a portion of the gas supply for the greater Buenos Aires area. Loop Sur is also connected to the TGN system and allows us to deliver gas to or receive gas from TGN. Such transfers occur occasionally during periods of high demand for gas.

Neuba II.Our newest pipeline, Neuba II, was built in 1988, was expanded four times between 1996 and 2000 and is our other pipeline serving the Neuquén basin. Neuba II begins at Repsol-YPF’s Loma de la Lata gas treatment plant in the western portion of the basin and runs through the provinces of Neuquén, Río Negro, La Pampa and Buenos Aires (through the Cerri Complex), up to its terminal station located at Ezeiza just outside of Buenos Aires. Neuba II is a principal source of gas for the Federal District and the greater Buenos Aires area.

Other Pipelines. Our other pipelines include the Cordillerano pipeline, built in 1984, which receives gas from the Neuquén Basin and supplies it mainly to three tourist centers in southern Argentina. In addition, we operate other minor pipelines, the high pressure transmission ring around Buenos Aires, the Chelforó-Conesa pipeline and other pipelines known as gas transfer pipelines.

Information regarding gas transportation system expansion is included in “Item 4. Our Information—B. Business Overview—Gas Transportation—Pipeline Operations—Pipeline Expansions.”

Ancillary Facilities

Cathodic Protection System

Currently, we operate more than 200 cathodic protection devices, which are located along our main pipelines. The objective of this system is to mitigate the corrosion process on the pipes’ surface. The corrosion process causes metal loss, which, depending on the severity of the damage, may cause pipeline ruptures. Cathodic protection equipment includes thermic, turbine-driven, motor-driven or even solar electric generators in locations where no electric lines are available. The system also includes an impressed current-deep anode, which facilitates circulation of electricity through the circuit formed by the generator, the anode itself, the pipe and the land.

Gas Control System

Located at our Buenos Aires headquarters, the gas control system controls scheduled gas injections and deliveries and allows us to follow gas flows in real time. Data is received from compressor stations by phone and automatically from remote terminal units (“RTUs”) installed in the receipt and delivery points equipped with the EFM system. The information is normally collected by the Supervisory Control and Data Acquisition (“SCADA”) system (which has an ad-hoc database that is updated every 30 seconds on average) and is then consolidated into other databases. In order to control gas injection and deliveries, we have developed a software system calledSolicitud, Programación, Asignación y Control(“SPAC”), which, among other things, allows us to control actual volumes and projected future injections to determine producer deviations. As part of this system, we opera te meteorological equipment and receive daily weather information from various sources, which is used for the purpose of forecasting gas demand.

Gas Measurement

Shipped and delivered gas is measured through primary field facilities that are connected with RTUs. Such RTUs transmit the data to the Buenos Aires headquarters. This data is utilized to prepare reports for clients, shippers, producers and ENARGAS. Energy balances are also prepared in order to control our system efficiency.

NGL production and commercialization

Our NGL production and commercialization activities are conducted at our Cerri Complex. It is located near the city of Bahía Blanca and is connected to each of our main pipelines. The Cerri Complex consists of an ethane extraction plant to recover ethane, LPG and natural gasoline, together with a lean oil absorption plant to recover LPG and natural gasoline. The facility also includes compression, power generation and storage facilities. The Cerri Complex processing capacity is approximately 1.6 Bcf/d.

In 2007, the expansion works of one of the Cerri Complex plants were concluded, resulting in a production capacity increase of 33,069 short tons of propane, butane and natural gasoline, through the ability to process higher natural gas volumes of 106 MMcf/d.

As part of the Cerri Complex, we also maintain at Puerto Galván a storage and loading facility for the natural gas liquids extracted at the Cerri Complex. The Cerri Complex, including the Puerto Galván facility, is currently capable of storing 60,450 short tons. In 1998, we completed the expansion of the processing and storage facilities of the Cerri Complex. For a more detailed description of the expansion, see “—Business Overview—NGL Production and Commercialization” above.

Midstream

As part of this business segment, we provide services relating to natural gas including treatment, gathering and gas compression, which are rendered at four treatment plants located in the gas fields with a total capacity of 240 MMcf/d and four gas compression plants with a total capacity of 39,400 HP. The following chart shows summary information regarding the treatment and compression plants’ capacity:

	Treatment capacity (in MMcf/d)	Compression capacity (in HP)
Río Neuquén	85	27,000
Plaza Huincul	28	5,200
BRTF	21	3,400
Cornejo – Ramos	106	3,800
Total	240	39,400

Telecommunication

We own two interconnected networks which consists of: (i) a flexible and modern microwave digital network with SDH technology and more than 2,858 miles, which covers the routes: Buenos Aires – Bahía Blanca – Neuquén to the West and Buenos Aires – Bahía Blanca – Comodoro Rivadavia – Río Grande to the South, and (ii) a dark fiber optic network, with more than 1,056 miles., which covers the route: La Plata – Buenos Aires – Rosario – Córdoba – San Luis – Mendoza.

Environmental Matters  

We believe that our current operations are in compliance with applicable laws and regulations related to the protection of the environment.

Over the past decade, we have consistently studied, monitored and improved our policies with regard to environmental issues.

Regarding our commitment to quality, environment and safety, outlined in our Quality, Environment, Safety and Occupational Health Policy, the most significant activities in 2007 are detailed below:

ü

We successfully passed Moody International Group’s surveillance Audit of the ISO 9,001, ISO 14,001 and OHSAS 18,001. receiving its recommendation for their recertifications.

ü

We completed the construction of the second gathering pool to collect industrial runoff in the Cerri Complex.

ü

We continued our online public consulting system through our web site, through which people living nearby may find information about the projects undertaken by us and perform enquiries about the environmental impact assessment.

ü

We continued with the implementation of the Behavior-Based Safety Process at the Cerri Complex, which seeks to identify probable operational accident risks to reinforce prevention.

ü

In 2007, to improve the fire fighting system at the Cerri Complex, we acquired a fully equipped fire-truck.

We have established an environmental and industrial safety investment plan for the period of 2008-2010 with a budget of approximately US$ 22.0 million.

Insurance

We maintain insurance, subject to deductibles, against third-party liability, damage to our pipeline assets that pass under rivers or other bodies of water and the Straits of Magellan and business interruption. We believe this coverage is consistent with standards for international natural gas transportation companies. The terms of the policies related to the regulated assets have been approved by ENARGAS. In addition, we have obtained insurance coverage for our directors and officers.

Item 4A. Unresolved Staff Comments

We do not have any unresolved staff comments.

Item 5. Operating and Financial Review and Prospects

A. Operating results

The following Operating and financial review and prospects should be read in conjunction with “Item 3. Key Information—A. Selected Financial Data” and our Financial Statements as of December 31, 2007 and 2006 and for the years ended December 31, 2007, 2006 and 2005 and the report of our registered public accounting firm included elsewhere herein. Such financial statements have been prepared in accordance with Argentine GAAP and the regulations of the CNV. See Note 12 to our Financial Statements for a description of the main differences between Argentine GAAP and US GAAP as they relate to us, and a reconciliation to US GAAP of net income and total shareholders’ equity. The differences involve methods of measuring the amounts shown in the consolidated financial statements as well as additional disclosures required by U.S. GAAP and Regulation S - X of the SEC.

This Operating and Financial Review and Prospects discussion contains forward-looking statements that involve certain risks, uncertainties and assumptions. These forward-looking statements can be identified by the use of forward-looking terminology such as “may,” “will,” “will likely result,” “intend,” “projection,” “should,” “believe,” “expect,” “anticipate,” “estimate,” “continue,” “plan” or other similar words. Our actual results may differ materially from those identified in these forward-looking statements. For more information on forward-looking statements, see “Cautionary Statement Regarding Forward-Looking Statements.” In addition, for a discussion of important factors, including, but not limited to, the pesification of our tariffs and other factors that could cause actual results to differ mater ially from the results referred to in the forward-looking statements, see “Item 3. Key Information—D. Risk Factors.”

For information relating to the presentation of financial information see “Presentation of Financial and Other Information”.

Critical accounting policies and estimates

Except as further discussed under “Presentation of Financial and Other Information,” we prepare our financial statements in pesos and in accordance with Argentine GAAP and the regulations of the CNV, which differ in certain significant respects from US GAAP. For a description of the principal differences between Argentine GAAP and US GAAP as they relate to us and a reconciliation to US GAAP of net income and shareholders equity as of December 31, 2007 and 2006 and for the years ended December 31, 2007, 2006 and 2005, see Note 12 to our Financial Statements.

In connection with the preparation of our Financial Statements included in this Annual Report, we have relied on assumptions derived from historical experience and various other factors that we deemed reasonable and relevant. Although we review these assumptions in the ordinary course of our business, the presentation of our financial condition and results of operations often requires management to make judgments regarding the effects of matters that are inherently uncertain. Actual results may differ from those estimated as a result of these different assumptions. We have described each of the following critical accounting policies and estimates in order to provide an understanding about how our management forms judgments and views with respect to such policies and estimates, as well as the sensitivity of such policies and estimates:

·

impairment of long-lived assets;

·

provision for allowances and contingencies; and

·

credit on assets tax.

Impairment of Long-Lived Assets

As a matter of policy, we evaluate the carrying value of our long-lived assets on a segment-by-segment basis in December of each year. In addition, we periodically evaluate the carrying value of our long-lived assets for impairment when events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

Prior to January 1, 2006, both under Argentine GAAP and US GAAP, we considered the carrying value of a long-lived asset to be impaired when the expected cash flows, undiscounted and without interest, from such asset were separately identifiable and less than its carrying value. In that event, a loss was recognized based on the amount by which the carrying value exceeded the fair market value of the long-lived asset. We determined the fair market value primarily using projected cash flows discounted at a rate commensurate with the risk involved or independent appraisals, as appropriate.

Effective January 1, 2006, as a result of the adoption of new accounting standards by the CNV, under Argentine GAAP, we consider the carrying value of a long-lived asset to be impaired when the expected cash flows from such asset are separately identifiable and less than its net carrying value. Expected cash flows are determined primarily using the anticipated cash flows discounted at a rate commensurate with the risk involved. The adoption of this accounting standard has had no impact in our results of operations or financial position.

Under US GAAP, we continue to apply the provisions of Statement of Financial Accounting Standard (“SFAS”) No. 144, “Accounting for the Impairment or Disposal of Long-lived Assets.” As indicated above, under SFAS No. 144, the carrying value of a long-lived asset is considered impaired when the expected undiscounted cash flows from the asset are separately identifiable and less than its carrying value. In that event, a loss is recognized based on the amount by which the carrying value exceeds the market value of the long-lived asset.

As of December 31, 2007, under Argentine GAAP and US GAAP, we have recorded an impairment of Ps. 19.6 million in order to expense the total carrying amount of certain turbines as they became obsolete. No impairment losses have been recognized for 2006 and 2005.

Under Argentine GAAP, a previously recognized impairment loss should only be reversed when there is a subsequent change in estimates used to compute the fair market value of the asset. In that event, the new carrying amount of the asset should be the lower of its fair market value or the net carrying amount the asset would have had if no impairment had been recognized. Both the impairment charge and the impairment reversal are recognized in earnings. US GAAP prohibits the reversal of a previously recognized impairment charge.

We believe that our accounting policy relating to the impairment of long-lived assets is a “critical accounting policy” because:

§

It requires our management, in determining fair market value, to make estimates and assumptions (such as, future revenues and cost of revenues) that are highly susceptible to change from period to period.

§

The impact that recognizing or reversing an impairment would have on assets reported on our consolidated balance sheet as well as on the results of our operations could be material. Estimates about future revenues require significant judgment because actual revenues have fluctuated in the past and are expected to continue to do so, especially due to the pending tariff renegotiation process.

§

In order to project future cash flows, we have made certain estimates in connection with the tariffs adjustments we expect we will have in the future. However, due to the uncertainties surrounding the tariff renegotiation process, these estimates are highly uncertain and there is a substantial risk that these estimates could prove to be materially different from actual future tariffs. In addition, the volatility of the Argentine economy also makes the selection of an appropriate discount rate a highly subjective process.

Provision for Allowances and Contingencies

We provide for losses relating to trade receivable accounts. The allowance for losses is based on management’s evaluation of various factors, including the credit risk of customers, historical trends and other information. While management uses the most current information available to make its evaluations, future adjustments to the allowance may be necessary if future economic conditions differ substantially from the estimated economic conditions used in making these evaluations. Management considers all events and transactions that it believes are relevant to our business and believes it has made reasonable estimates.

We have certain contingent liabilities with respect to legal and regulatory proceedings. We accrue liabilities when it is probable that future costs will be incurred and such costs can be reasonably estimated. Such accruals are based on developments as of the time the accruals are made, estimates of the outcomes of these matters and our lawyers’ experience in contesting, litigating and settling other matters. As the scope of the liabilities becomes better defined, there may be changes in estimates of future costs, which could have a material effect on our financial condition and results of operations.

We believe that our accounting policy relating to the provision for allowances and contingencies is a “critical accounting policy” because:

§

It requires our management to make estimates and assumptions that are highly susceptible to change from period to period.

§

The impact that recognizing or reversing provisions for allowances and contingencies would have on our consolidated balance sheet as well as on the results of our operations could be material.

Credit on Assets Tax

We have also recorded an asset of Ps. 113.9 million as of December 31, 2007, for the value of our tax credit related to asset tax. In the opinion of management, it is more likely than not that we will utilize such asset against future income tax charges within the recoverable term of ten years (which began in 2002 and expires in 2012), and as a result, no valuation allowance was recognized.

We believe that our accounting policy relating to Credit on Assets Tax is a “critical accounting policy” because:

§

It requires our management to make estimates and assumptions that are highly susceptible to change from period to period.

§

The impact that recognizing or reversing an allowance would have on our consolidated balance sheet as well as on the results of our operations could be material. Estimates about taxable incomes require significant judgment because actual taxable incomes have fluctuated in the past and are expected to continue to do so.

Differences between Argentine GAAP and US GAAP

Our Financial Statements and the information shown in this section have been prepared in accordance with Argentine GAAP, which differs in certain significant respects from US GAAP. Such differences involve methods of measuring the amounts shown in the financial statements, as well as additional disclosures required by US GAAP and Regulation S-X promulgated by the SEC. The following is a list of the principal differences, other than with regard to inflation accounting, between Argentine GAAP and US GAAP, as they relate to us, that affect the reported amounts under Argentine GAAP of our total shareholders’ equity as of December 31, 2007, and 2006 and net income for the years ended December 31, 2007, 2006 and 2005:

§

the capitalization of interest costs;  

§

the capitalization of exchange differences arising from the devaluation of the Argentine peso under Argentine GAAP, which are treated as expenses under US GAAP;

§

the accounting for derivatives and hedging activities;

§

the deferral of certain pre-operating and organizational expenses under Argentine GAAP, which are expensed as incurred under US GAAP;

§

the accounting for income taxes;

§

the accounting for the effects of our 2004 debt restructuring;

§

the impact of US GAAP adjustments on equity investees;

§

the accounting for current investments;

§

the accounting for vacation expenses; and

§

the present-value accounting of certain assets and liabilities.

Note 12 to our Financial Statements, included elsewhere in this Annual Report, provides a description of the main differences between Argentine GAAP and US GAAP as they relate to us and a reconciliation to US GAAP of shareholders’ equity at December 31, 2007, and 2006 and net income for the years ended December 31, 2007, 2006 and 2005. Net income under Argentine GAAP for the years ended December 31, 2007, 2006 and 2005 was approximately Ps. 147.5 million, Ps. 358.0 million and Ps. 217.5 million, respectively, as compared to approximately Ps. 219.6 million, Ps. 405.6 million and Ps. 270.6 million, respectively, under US GAAP. Shareholders’ equity under Argentine GAAP as of December 31, 2007, and 2006 was Ps. 2,929.5 million and Ps. 2,782.1 million, respectively, as compared to approximately Ps. 2,158.4 million and Ps. 1,935.5 million, respectively, under US GAAP.

New accounting pronouncements under Argentine GAAP

In 2007, no Argentine GAAP accounting pronouncement has been issued.

Accounting pronouncements issued but not yet adopted under US GAAP

The following is a summary of recent changes in US GAAP. We do not believe any of these changes will have a material impact on US GAAP reconciliation of our reported financial results:

1.

Fair value measurements

In September 2006, the Financial Accounting Standards Board (“FASB”) issued SFAS No. 157 “Fair value measurements” establishing a framework for measuring fair value in generally accepted accounting principles (GAAP), and expanding disclosures about fair value measurements. This Statement applies under other accounting pronouncements that require or permit fair value measurements, the FASB having previously concluded that fair value is the relevant measurement attribute. Accordingly, this Statement does not require any new fair value measurements. The changes to current practice resulting from the application of this Statement relate to the definition of fair value, the methods used to measure fair value, and the expanded disclosures about fair value measurements. A single definition of fair value, together with a framework for measuring fair value, should result in increased consistency and comparability in fair value measurements. The expanded disclosures about the use of fair value to measure assets and liabilities should provide users of financial statements with better information about the extent to which fair value is used to measure recognized assets and liabilities, the inputs used to develop the measurements, and the effect of certain of the measurements on earnings (or changes in net assets) for the period. This Statement is effective for financial statements issued for fiscal years beginning after November 15, 2007, and interim periods within those fiscal years. In February 2008, the FASB approved FSP FAS 157-2, which grants a one-year deferral of SFAS No. 157 fair value measurement requirements for non-financial assets and liabilities, except for items that are recognized or disclosed at fair value on a recurring basis. We are currently evaluating the impact of SFAS No. 157 on our financial position and result of operations.

2.

Fair value option  for financial assets and financial liabilities

In February 2007, the FASB issued SFAS No. 159, “The fair value option for financial assets and financial liabilities”, or SFAS No. 159. SFAS No. 159 establishes a fair value option under which entities can irrevocably elect to report certain financial asset and liabilities at fair value, with changes in fair value recognized in earnings at each subsequent reporting date. SFAS No. 159 is effective for fiscal years beginning after November 15, 2007. We will evaluate the impact of SFAS No. 159 on our financial statements.

3.

Non-controlling interest in consolidated financial statements

In December 2007, the FASB issued SFAS No. 160, “Noncontrolling interest in consolidated financial statements”. This statement amends Accounting Research Bulletin No. 51, “Consolidated financial statements” to establish accounting and reporting standards for the non-controlling interest in subsidiaries and requires non-controlling interest to be treated as a separate component of equity. SFAS No. 160 shall be effective for fiscal years, and interim periods within those fiscal years, beginning on or after December 15, 2008. Earlier adoption is prohibited. This statement shall be applied prospectively as of the beginning of the fiscal year in which it is initially adopted, except for the presentation and disclosure requirements which shall be applied retrospectively. We will evaluate the impact of SFAS No. 160 on our financial statements.

4.

Disclosures about derivative instruments and hedging activities an amendment of SFAS No. 133

In March 2008, the FASB issued SFAS No. 161, “Disclosures about derivative instruments and hedging activities an amendment of SFAS No. 133”. This Statement requires enhanced disclosures about an entity’s derivative and hedging activities to provide information about (a) how and why an entity uses derivative instruments, (b) how derivative instruments and related hedged items are accounted for under SFAS No. 133 and its related interpretation, and (c) how derivative instruments and related hedged items affected an entity’s financial position, financial performance, and cash flows. This Statement is effective prospectively for financial statements issued for fiscal years and interim periods beginning after November 15, 2008, with early application encouraged. We will evaluate the impact of SFAS No. 161 on our financial statements.

5.

The hierarchy of generally accepted accounting principles

In May 2008, SFAS No. 162 “The hierarchy of generally accepted accounting principles” was issued by the FASB. This sets out the framework for selecting accounting principles to be used in preparing financial statements that are presented in conformity with US GAAP. Up to now, the US GAAP hierarchy has been defined in the US auditing literature. Because of the interrelationship with the auditing literature, SFAS 162 will be effective 60 days following the SEC’s approval of the PCAOB’s amendments to their auditing standards. We will evaluate the impact of SFAS No. 162 on our financial statements.

Factors affecting our consolidated results of operations

Since the onset of the severe economic crisis in Argentina, which began in late 2001, our revenue composition has changed significantly, mainly as a consequence of (i) the substantial devaluation of the peso as compared to the U.S. dollar, (ii) high inflation that occurred in 2002, and (iii) the suspension, pursuant to the Public Emergency Law, of adjustments of the regulated tariff for the transportation and distribution of natural gas. In 2002, the peso was devalued against the U.S. dollar by 237.0% and Argentina experienced a cumulative rise in the CPI of 40.7% and in the WPI of 118.2% from December 2001 through December 2002.

Under CNV rules, our results of operations for the year ended December 31, 2002 and for the two-month period ended February 28, 2003 were adjusted to account for the effects of inflation in Argentina during those periods. For the periods subsequent to February 28, 2003, the inflation adjustments were no longer applied to our financial statements, as inflation reported by INDEC returned to normalized levels, as illustrated in the table below.

	December 31,
	2007	2006	2005	2004	2003
	(annual % change)
Wholesale price index	14.4	7.2	10.6	7.9	2.0
Consumer price index	8.5	9.8	12.3	6.1	3.7
Devaluation / (Appreciation) of pesos vs. U.S. dollar	2.8	1.0	1.8	1.7	(13.1)

Source:INDEC, Banco de la Nación

Inflation rates reported by the INDEC since January 2007 have not reflected currently increasing inflationary pressures, and the INDEC numbers are considered by economic analysts to underestimate the current rate of inflation.

Laws and regulations currently governing the Argentine economy may continue to change in the future and these changes may adversely affect our business, financial condition or results of operations. For more information, see “Item 3. Key Information—D. Risk Factors”. Our Financial Statements do not include any adjustments or reclassifications that might result from the outcome of the uncertain economic and political environment in Argentina.

Year to year fluctuations in our net income are a result of a combination of factors, including principally:

·

The volume of NGL products we produce and sell;

·

Changes in international prices of LPG and natural gasoline;

·

Changes in the prices of natural gas and compensation for its richness;

·

Fluctuation in the Argentine peso / US dollar exchange rate;

·

Local inflation; and

·

Changes in laws or regulation affecting our operations, including tax matters.

11

Discussion of results of operations for the three years ended December 31, 2007, 2006 and 2005

The following table presents a summary of our consolidated results of operations for the years ended December 31, 2007, 2006 and 2005, stated in millions of pesos, and the increase or decrease and percentage of change between the periods presented:

	Years ended December 31,		Year ended December 31, 2007 compared to year ended December 31, 2006		Year ended December31,	Year ended December 31, 2006 compared to year ended December 31, 2005
	2007	2006	Variation	Percentage change	2005	Variation	Percentage change
Gas Transportation	509.5	492.0	17.5	3.6%	460.0	32.0	7.0%
NGL production and commercialization	667.4	726.4	(59.0)	(8.1%)	546.3	180.1	33.0%
Other services	80.4	91.1	(10.7)	(11.7%)	58.4	32.7	56.0%
Net revenues	1,257.3	1,309.5	(52.2)	(4.0%)	1,064.7	244.8	23.0%
Operating costs	(442.3)	(434.9)	(7.4)	1.7%	(332.4)	(102.5)	30.8%
Depreciation and amortization	(196.4)	(189.0)	(7.4)	3.9%	(194.7)	5.7	(2.9%)
Costs of sales	(638.7)	(623.9)	(14.8)	2.4%	(527.1)	(96.8)	18.4%
Gross profit	618.6	685.6	(67.0)	(9.8%)	537.6	148.0	27.5%
Administrative and selling expenses	(128.6)	(115.4)	(13.2)	11.4%	(94.7)	(20.7)	21.9%
Operating income	490.0	570.1	(80.2)	(14.1%)	442.9	127.2	28.7%
Other expenses, net	(2.6)	(0.7)	(1.9)	271.4%	(6.1)	5.4	(88.5%)
Gain / (loss) on related companies	0.6	(0.4)	1.0	(250.0%)	2.6	(3.0)	(115.4%)
Net financial expense	(193.5)	(189.0)	(4.5)	2.4%	(209.1)	20.1	(9.6%)
Income tax expense	(147.0)	(21.9)	(125.1)	571.2%	(12.8)	(9.1)	71.1%
Net income	147.5	358.0	(210.5)	(58.8%)	217.5	140.5	64.6%

Year 2007 compared to year 2006

Net revenues

Regulated gas transportation segment. Gas transportation service is our main business activity measured by the invested capital and the resources involved in its operation; however, it is not as significant as our NGL production and commercialization business in our total net revenues because of the pesification of regulated tariffs at an exchange rate of US$ 1=Ps. 1 implemented by the Public Emergency Law. The gas transportation segment represented approximately 41% and 38% of total net revenues earned during the years ended December 31, 2007 and 2006, respectively. A substantial portion of our gas transportation service revenues are derived from firm contracts, under which pipeline capacity is reserved and paid for, regardless of actual usage by the shipper. We also provide interruptible transportation services subject to available pipeline capacity.

Gas transportation revenues for the year ended December 31, 2007 increased by 3.6% as compared to 2006. This increase was principally a consequence of additional revenue generated by new firm transportation contracts signed with Aluar and natural gas producer clients, which became effective in March and May 2007. For that purpose, between the end of 2006 and the beginning of 2007, a 57 MMcf/d expansion was carried out for approximately Ps. 80 million, financed by said clients. The works consisted of construction of a 50 mile loop in San Martín Pipeline and the revamping of a compressor plant. These expansions are expected to generate annual revenues of approximately Ps. 26 million. See “Item 4. Our Information —Business Overview — Gas Transportation — Pipeline Operations — Pipeline Expansion.”

In April 2006, MPFIPyS, the Federal Energy Bureau and gas transportation companies, among others, signed a Letter of Intent to carry out a second, much more significant expansion of the gas pipeline system. The letter of intent was ratified by the Executive Branch through decree No. 660/08, issued on April 17, 2008. This new expansion will increase the aggregate transportation capacity of our system and TGN’s system by 883 MMcf/d, of which almost 332 MMcf/d pertain to our system. Under a management agreement signed in connection with this second expansion, we will receive Ps. 50 million plus VAT as consideration for management services to be rendered for the first 247 MMcf/d of capacity. The fee for management services that we will earn in connection with the remaining 85 MMcf/d has not yet been determined. It is expected that the first stage, which consists of an expansion of 78 MMcf/d, will be in operation in winter of 2008 in Argentina. The second stage, which will complete the total expansion, is expected to be finished in 2009. These works include the expansion of the pipeline which crosses the Magellan Straits.

In April 2008, we conducted a new open bidding process for firm transportation capacity and our clients requested between 71 MMcf/d and 81 MMcf/d effective in 2008 and 2009, subject to the approval of ENARGAS. It is expected that the transportation expansion needed to satisfy these requests will require us to invest approximately between US$ 87 and US$ 99 millions, depending on the final contracted capacity. The investment will be totally financed by advances from clients.

The Executive Branch, through Decree No. 180/04 issued on February 16, 2004, established an electronic market for natural gas trading known as the MEG with the purpose of improving the transparency of financial and operating performance, the coordination of daily transactions in both the gas spot and the transportation and distribution secondary markets along with producing efficient prices through offer and demand free interaction. To that end, all firm transportation capacity not allocated for the following day must be marketed through the MEG and the proceeds from that capacity sale will be used in accordance with the Federal Energy Bureau’s requirements. Non-allocated capacity includes remaining capacity not used in any of the transportation systems or pipelines. Revenues related to the interruptible transportation service might, therefore, be affected in the future due to the operation of the MEG (for further information, see “Item 4. Our Information – B. Business Overview – Gas Transportation – The Argentine Natural Gas Industry – Historical Background”). Revenues related to interruptible transportation service amount to Ps. 32.9 million and Ps. 34.9 million for the years ended December 31, 2007 and 2006, respectively.

We are still in the process of renegotiating our tariffs, and our tariff rates were unchanged in 2007 from 2006. For more information see “Item 4. Our Information—B. Business Overview—Gas Transportation—Regulatory Framework—Adjustment of Rates”.

NGL production and commercialization segment. Unlike the gas transportation segment, the NGL production and commercialization segment is not subject to regulation by ENARGAS. However, over recent years, in order to guarantee sufficient supply of LPG for local market at low prices, the Argentine government enacted Law No. 26,020, which is discussed further below.

Net revenues from the NGL production and commercialization segment represented approximately 53% and 55% of our total net revenues during the years ended December 31, 2007 and 2006, respectively.

The NGL production and commercialization segment revenue decreased by Ps. 59.0 million in the year ended December 31, 2007 in comparison to 2006, caused mostly by a decline of NGL produced in the Cerri Complex. The lower production level resulted from an unusual and extremely cold winter, which affected the whole country, pushing the Cerri Complex to by-pass natural gas for several days in a row to satisfy the higher demand from residential households and the electric power plants. However, the effect in revenues caused by higher NGL international reference prices recorded in 2007 partially offset the fall in revenues generated by the 21% reduction in the volumes sold.

NGL production and commercialization activities are conducted at the Cerri Complex, which is located near Bahía Blanca and connected to each of our main pipelines. At the Cerri Complex, we recover ethane, LPG and natural gasoline for both our own account and on behalf of our customers. In 2007, we sold approximately 54% of our production of LPG in the local market to LPG marketers (53% in 2006). The remainder of these products and all of our natural gasoline are exported to PIFCo, a subsidiary of Petrobras Petróleo Brasileiro S.A. under a long-term contract that provides for pricing based on international market prices. All of the Cerri Complex’s ethane output is sold in the domestic market to PBB at agreed prices under a long-term contract. We process and sell some of the NGL for our own account, some on behalf of our customers, and some on a fee basis, collecting a commission for the extracted liquids delivered to our customers.

The total annual sales for the Cerri Complex for 2007 and 2006 in short tons, which include NGL sales made on behalf of third parties, from which we withhold fees for production and commercialization, were as follows:

	Years ended December 31,		Year ended December 31, 2007 compared to year ended December 31, 2006
	2007	2006	Decrease	Percentage change
Local market
Ethane	336,947	419,131	(82,184)	(19.6%)
LPG	258,587	316,824	(58,237)	(18.4%)
Natural Gasoline	2,963	4,529	(1,566)	(34.6%)
Subtotal	598,497	740,484	(141,987)	(19.2%)
Exports
LPG	201,886	275,833	(73,947)	(26.8%)
Natural Gasoline	98,764	121,962	(23,198)	(19.0%)
Subtotal	300,650	397,795	(97,145)	(24.4%)
Total	899,147	1,138,279	(239,132)	(21.0%)

A sharp increase in natural gas demand occurred as a consequence of: (i) the recovery of certain industries in the Argentine economy, (ii) the 2002 devaluation of the peso and pesification of transportation and distribution tariffs and the elimination of both tariff and wellhead gas price adjustments, making this fuel relatively inexpensive for consumers as compared to other types of fuel the prices of which are affected by inflation and (iii) the growth of gross domestic product between 2003 and 2007. Natural gas became, by far, the cheapest fuel due to the pesification of transportation and distribution tariffs and the lack of adjustments of both these tariffs and wellhead gas prices. As a consequence, there are high rates of substitution of natural gas for other fuels, principally in power plants and vehicles. In addition, the low price of natural gas has discouraged oil and gas producers from making investments in exploration, resulting in reduced production of natural gas and a reduction in the levels of natural gas reserves.

In 2007, supply to industrial consumers, including the Cerri Complex, which has firm gas supply contracts, was restricted when high demand from firm transportation users resulting from economic growth, low hydroelectric generation and cold temperatures in winter prompted the Argentine government to instruct us to redirect firm transportation supply to power plants, residential users and vehicles. During the winter of 2007, the Cerri Complex processing was interrupted for 27 days, not including days with partial interruptions. As a result, NGL production in 2007 was the lowest in the last six years. In April and May 2008, the Cerri Complex suffered additional interruptions due to the low temperatures recorded on several days and a reduced availability of natural gas as producers performed maintenance in such months.

Law No. 26,020 set the framework through which the Federal Energy Bureau establishes regulations requiring LPG suppliers to guarantee supply and price stability of such products in the domestic market. As a consequence of this law, we are not able to choose the markets to which we sell our LPG production, and we need a written authorization from the Federal Energy Bureau for each export operation. Because we are effectively required to meet domestic demand (at a price below the international market price) before exporting significant amounts of LPG, we are not able to take full advantage of rising international prices for these commodities.

The results of our NGL production and commercialization segment are subject to risks associated with commodity price changes. We do not currently hedge against commodity price risk.

Over recent years NGL’s export tax rates have suffered several increases. In May 2004, the effective tax rate for LPG exports was increased from 4.76% to 16.67%. On May 24, 2007, it was increased to 20%.

Currently, a variable export tax regime is in force, with a minimum effective tax rate of 31.03% when LPG and natural gasoline international prices are lower than US$ 663 and US$ 920 per metric ton, respectively. If international prices exceed these amounts, the marginal tax rate applicable to the excess is 100%. As a result of this export tax regime, we are unable to obtain post-tax prices of more than US$ 457 and US$ 634 per metric ton of LPG and natural gasoline, respectively.

The chart below is a sensitivity analysis estimation which states the annual impact of this new variable export tax regime compared with the previous regime, calculated based on the short tons sold in 2007 and considering different LPG and natural gasoline international prices. The average LPG and natural gasoline international prices in May 2008 were US$ 913 and US$ 987, respectively.

LPG average international price	Additional annual tax  (in million of US$)	Natural gasoline international price	Additional annual tax  (in million of US$)
US$600	10	US$800	13
US$700	16	US$900	14
US$800	28	US$1,000	19
US$900	41	US$1,100	25
US$1,000	53	US$1,200	31

Other services. This segment includes midstream and telecommunications services. Midstream services include gas treatment, separation and removal of impurities from the natural gas stream and compression services, which are generally rendered to the natural gas producers at wellhead, as well as activities related to construction, operation and maintenance of pipelines and compressor plants. These services are rendered by us or through our affiliates Gas Link S.A. (“Link”), Transporte y Servicios de Gas en Uruguay S.A. (“TGU”) and Emprendimientos de Gas del Sur S.A (“EGS”). Telecommunications services are provided by Telcosur, a 99.98%-owned subsidiary. Telcosur provides telecommunications services to leading telecommunication operators and corporate customers.

Net revenues from the other services segment accounted for approximately 6% and 7% of total net revenues for the years ended December 31, 2007 and 2006, respectively. Of net revenues from the other services segment, 26% and 23% corresponded to telecommunications services for December 31, 2007 and 2006, respectively. Revenues from other services segment decreased by Ps. 10.7 million in the year ended December 31, 2007 as compared to 2006. This variation is due primarily to lower sales in 2007 relating to construction services.

Costs of sales

Costs of sales for the year ended December 31, 2007, rose by Ps. 14.8 million, or approximately 2.4%, compared to the year 2006. This increase is mostly attributable to: (i) higher maintenance costs of Ps. 19.6 million and (ii) a Ps. 14.4 million increase in labor costs. These effects were partially compensated by lower easement expenses of Ps. 14.2 million and lower costs of construction of Ps. 8.1 million related to other services business segment.

Administrative and selling expenses

Administrative and selling expenses for the year ended December 31, 2007, increased by approximately Ps. 13.2 million, or approximately 11.4%, as compared to the year 2006. This increase was primarily the result of: (i)higher labor costs of Ps. 4.9 million and (ii) Ps. 8.4 million in export taxes associated with the increase in our export sales.

Other expenses, net

The detail of other expenses, net for the years ended December 31, 2007 and 2006, is as follows:

	2007	2006
	(in millions of Pesos)
Increase inallowances and provisions	(15.3)	(26.1)
Reversal of allowances and provisions	17.3	-
Insurance liquidation associated with the damage of a facility located at the Cerri Complex	-	24.7
Others	(4.6)	0.7
Total	(2.6)	(0.7)

Gain /(Loss) on related companies

In 2007, we recorded a gain on related companies of Ps. 0.6 million, compared to the loss of Ps. 0.4 million recorded in 2006. The positive variation was due to increased earnings on our investment in EGS.  

Net financial expense

Net financial expense for the years ended December 31, 2007, and 2006 is as follows:

		Years ended December 31,
		2007		2006
Generated by assets		(In millions of pesos)
Interest income		34.1	30.6
Foreign exchange gain		8.4	13.4
Impairment of property, plant and equipment		(19.6)	-
Other financial results, net		-	1.7
Total		22.9	45.6
	Generated by liabilities
	Interest expense	(156.7)	(193.7)
	Foreign exchange loss	(42.6)	(26.5)
	Result of the debt prepayment	10.6	-
	Other expenses and financial charges	(27.7)	(14.5)
	Total	(216.4)	(234.7)
	Total net financial expense	(193.5)	(189.0)

Net financial results for the year ended December 31, 2007 showed a negative variation of Ps. 4.5 million as compared to 2006. This variation is mostly attributable to a higher exchange rate loss of Ps. 21.1 million principally generated by a higher Peso devaluation against the US dollar in 2007 compared to 2006, and a Ps. 19.6 million impairment of some gas transportation assets recorded in 2007. These two effects were compensated by a Ps. 37.0 million lower interest expense, principally associated with a more than US$ 200 million decrease in the average indebtedness.

In February 2005, we were served notice by the CNV that certain notes that we issued in December 2004 in the amount of US$178 million did not fulfill the requirements of Article 56 of Chapter VI of the CNV regulations and CNV Resolution No. 470. If the CNV’s interpretation is upheld, those notes would not be entitled to the benefits of the exemption from income tax withholding provided by Law No. 23,576, and we, therefore, would be exposed to a contingency for the payment of withholding amounts associated with the income tax payable on interest paid in respect of those notes from their issue date in December 2004. The amount of such contingency is an uncertain amount of between US$6 million and US$17 million as of December 31, 2007 (including interest to December 31, 2007) and will depend on the applicable withholding tax rates determined by the country of residence of the note holders at the date of each interest pa yment. We do not have information that permits the identification of the country of residence of each note holder on each interest payment date. We believe that we have sufficient legal grounds to defend our position that no withholding tax was required, and accordingly, we have not recorded any provision in respect of this proceeding.  See “Item 8. Financial Information — A. Consolidated Statements and Other Financial Information — Legal and Regulatory Proceedings.”

Income Tax

In 2007, income tax expense increased by Ps. 125.1 million compared to 2006 which is due primarily to the reversal of the remaining balance of the tax loss carryforward allowance of Ps. 144.5 million recorded in 2006, which was partially offset by a lower income tax charge registered in 2007.

Year 2006 compared to year 2005

Net revenues

Regulated gas transportation segment. The gas transportation segment represented approximately 38% and 43% of total net revenues earned during the years ended December 31, 2006 and 2005, respectively.

Gas transportation revenues for the year ended December 31, 2006 increased by 7% as compared to the year 2005. This increase was principally due to a Ps. 21.2 million impact derived from the new firm transportation contracts, some of which came into effect as a consequence of the San Martín pipeline expansion completed in August 2005, which increased the transportation capacity of the pipeline by 102 MMcf/d.

This expansion of the San Martín pipeline was carried out within the gas trust fund framework more fully described in “Item 4—Our information—B. Business overview—Gas transportation—Pipeline expansions.” In connection with this first expansion, the Gas Trust, created by the Argentine government for this expansion, financed US$311 million from a total amount of US$351 million. The Gas Trust will be repaid over a period of eight years with 20% of the revenues generated by transportation tariffs applicable to the additional firm contracted capacity plus an additional surcharge paid by industries, power plants and CNG suppliers with firm transportation contracts and representing an 81.6% increase in the current tariffs. In connection with the expansion, we invested approximately US$40 million (including US$7 million in VAT) for the purchase and installation of compression equipment on the new pipeline. The cost of our investment (which is reflected as fixed assets on our consolidated balance sheet) will be recovered through collection of tariffs at a rate equal to 80% of our current tariff rate (but not to the extent of any increased rate that may in the future be applicable to the additional transportation capacity), or approximately Ps. 23 million annually (or US$7.5 million annually at the December 31, 2006 exchange rate). The expansion financed by this means is owned by the Gas Trust.

Revenues related to interruptible transportation service amount to Ps. 34.9 million and Ps. 24.9 million for the years ended December 31, 2006 and 2005, respectively.

NGL production and commercialization segment. Net revenues from the NGL production and commercialization segment represented approximately 55% and 51% of our total net revenues during the years ended December 31, 2006 and 2005, respectively. This increase in NGL production and commercialization of Ps. 180.1 million in additional revenues for the year ended December 31, 2006, comprised: (i) Ps. 64.0 million due to an increase of 16% in volume sold in 2006 (ii) Ps. 55.6 million attributable to a higher sale price of ethane agreed with PBB in an agreement effective for ten years, starting from January 2006, and (iii) Ps. 25.9 million due to higher international reference prices on exports. NGL production and commercialization activities are conducted at the Cerri Complex, which is located near Bahía Blanca and connected to each of our main pipelines. In 2006, we sold approximately 53% of our production of LPG in the local market to LPG marketers (77% in 2005).

The total annual sales for the Cerri Complex for 2006 and 2005 in short tons, which includes NGL sales made on behalf of third parties, from which we withhold fees for production and commercialization, were as follows:

	Years ended December 31,		Year ended December 31, 2006 compared to year ended December 31, 2005
	2006	2005	Increase (Decrease)	Percentage change
Local market
Ethane	419,131	376,678	42,453	11.3%
LPG	316,824	278,205	38,619	13.9%
Natural Gasoline	4,529	5,429	(900)	(16.6%)
Subtotal	740,484	660,312	80,172	12.1%
Exports
LPG	275,833	220,337	55,496	25.2%
Natural Gasoline	121,962	102,831	19,131	18.6%
Subtotal	397,795	323,168	74,627	23.1%
Total	1,138,279	983,480	154,799	15.7%

Effective March 1, 2002, the Argentine government imposed a 5% export tax on LPG and natural gasoline exports. Effective May 2004, the tax rate for LPG exports was increased to 20% and, on May 24, 2007, the export tax rate increased to 25%.

Other services. Net revenues from the other services segment accounted for approximately 7% and 6% of total net revenues for the years ended December 31, 2006 and 2005, respectively. Of net revenues from the other services segment, 23% and 27% corresponded to telecommunications services for December 31, 2006 and 2005, respectively. Revenues from the other services segment increased by Ps. 32.7 million in the year ended December 31, 2006, as compared to 2005, mainly due to increased midstream services sales for Ps. 11.0 million, construction services sales of Ps 7.8 million and telecommunications services sales for Ps. 5.2 million.

Costs of sales

Cost of sales for the year ended December 31, 2006 increased by approximately Ps. 96.8 million, or approximately 18.4%, as compared to the year 2005. This increase resulted principally from: (i) Ps. 53.5 million of higher NGL production costs due to increases in the prices of raw materials; (ii) Ps. 12.0 million due to higher labor costs and (iii) Ps. 14.4 million of higher accruals for easement expenses. The remainder of the increase includes increased construction costs in the other services businesses, higher costs of third party services rendered and a higher management fee attributable to higher net income.

Administrative and selling expenses

Administrative and selling expenses for the year ended December 31, 2006, increased by approximately Ps. 20.7 million, or approximately 21.9%, as compared to the year 2005. This Ps. 20.7 million increase was primarily the result of: (i) higher labor costs of Ps. 7.6 million and (ii) Ps. 6.5 million in export taxes associated with the increase in our export sales.

Other expenses, net

In the year ended December 31, 2006, other expenses, net decreased by Ps. 5.4 million compared to 2005. This decrease was principally the result of a recorded gain of Ps. 24.7 million consisting of insurance proceeds in respect of damage that occurred in 2005 to a facility located at the Cerri Complex. This positive variation was partially offset by higher allowances recorded of Ps. 22.6 million, as more fully described in Note 9 to our Financial Statements.

Gain / (Loss) on related companies

(Loss) / gain on related companies decreased by Ps. 3.0 million for the year ended December 31, 2006, as compared to the year ended December 31, 2005 due to decreased earnings on our investment in Link.  

Net financial expense

Net financial expense for the years ended December 31, 2006, and 2005 is as follows:

		Years ended December 31,
		2006		2005
Generated by assets		(In millions of pesos)
Interest income		30.6	15.4
Foreign exchange gain		13.4	15.8
Other financial results, net		1.7	(0.3)
Total		45.6	30.9
	Generated by liabilities
	Interest expense	(193.7)	(185.5)
	Foreign exchange loss	(26.5)	(40.3)
	Other expenses and financial charges	(14.5)	(14.3)
	Total	(234.7)	(240.0)
	Total net financial expense	(189.0)	(209.1)

Net financial results for the year ended December 31, 2006 showed a reduction in expense of Ps. 20.1 million as compared to 2005. The variation is mostly attributable to the Ps. 15.2 million increase in interest income as a result of a greater investment in financial assets. In addition, as a consequence of a lower devaluation of the Argentine peso against the US dollar in the year ended December 31, 2006, the foreign exchange loss was lower by Ps. 11.3 million compared to 2005. Both effects were partially offset by a higher cost of debt associated with the increase in the effective interest rate on our indebtedness and an increased U.S. dollar to peso exchange rate, partially reduced by a more than 20% decrease in the outstanding amount of our indebtedness through early amortization payments.

Income Tax

Income tax expense increased by Ps. 9.1 million in 2006 compared to 2005 primarily as a result of an increased accrual of income tax of Ps. 53.6 million in 2006, which was in turn a result of increased income in 2006, partially offset by a reversal of a tax loss carry-forward allowance of Ps. 144.5 million (compared with a reversal in 2005 of Ps. 101.4 million) relating to operating losses.

B. Liquidity and capital resources

As a result of the severe financial crisis in Argentina that occurred in 2002 and the Argentine government’s resulting default on its financial indebtedness, we have had limited access to non-Argentine sources of financing or the public capital markets generally since 2002. Prior to the 2002 economic crisis, we financed our operations with internally generated funds but supplemented such funds with third-party financings and funds raised through our several global medium-term note programs. Since the crisis, we have had to rely entirely on internally generated funds to satisfy our payment obligations. In addition, our ability to generate funds suffered severely from the pesification of our tariffs in 2002, resulting in lower revenues from our gas transportation segment in U.S. dollar terms. By 2003, these events and conditions had caused us to default on substantially all of our then-outstanding de bt obligations.  

In December 2004, we restructured substantially all of our debt obligations by means of an exchange offer (the “Restructuring”), which was accepted by creditors holding 99.76% of the principal amount of the debt that we sought to restructure.  In connection with the Restructuring, we also settled Ps. 27.0 million of peso denominated debt, and since the Restructuring, we have settled an additional US$2.2 million in principal amount of unrestructured debt.

Beginning in April 2007, we began a series of steps to refinance our outstanding obligations under the notes issued in connection with the Restructuring (the “Restructured Notes”) and the amended and restated loan agreements with Inter-American Development Bank (the “Amended Loans”).  These steps included a tender offer and proxy solicitation with respect to all of the Restructured Notes (the “Tender Offer”), a new notes offering and an optional prepayment of amounts outstanding under the Amended Loans and redemption of the Restructured Notes remaining after the completion of the tender offer. On April 9, 2007, we launched the Tender Offer, and received a sufficient number of proxies by the early tender deadline to amend the terms of the Restructured Notes as necessary to allow the consummation of the Tender Offer, which was otherwise not permitted under the terms of the Restr uctured Notes.  The Tender Offer expired on May 7, 2007 and was accepted by 78.4% of noteholders.  

Concurrent with the Tender Offer, we commenced an offering of new notes in an aggregate principal amount of US$500,000,000 (the “New Notes”) pursuant to our Medium Term Note Program (the “Program”), which provides for the issuance of up to a maximum principal amount of US$650 million in notes. On May 14, 2007, we simultaneously closed the offering of New Notes and used a portion of the proceeds and cash to settle the Tender Offer. The interest rate for the New Notes is fixed at 7.875%, and the maturity date is May 14, 2017. As of May 14, 2007, our total U.S. dollar-denominated principal debt for accounting purposes consisted of US$500,000,000 in New Notes and US$97,318,912 in Restructured Notes not tendered in the Tender Offer and US$206,823,727 under the Amended Loans. On June 15, 2007, using the remainder of the proceeds from the New Notes and cash, we made an optional prepaym ent of all amounts owing under the Amended Loans and redeemed the outstanding Restructured Notes. As a result, the aggregate principal amount of our total U.S. dollar-denominated debt as of the date of this Annual Report is US$500,000,000.

Currently, we believe that our working capital is sufficient for our present requirements. A potential future devaluation of the peso, additional capital expenditures required by the Argentine government or a significant decrease of NGL prices could harm our cash-generating ability and materially adversely affect our liquidity and our ability to service our debt.

The statements of cash flows presented in the primary financial statements are prepared based on Argentine GAAP amounts. Under Argentine GAAP, we consider all short-term, highly liquid investments that are readily convertible to known amounts of cash and with original maturities of three months or less to be cash equivalents. Under Argentine GAAP, mutual funds are considered to be cash equivalents since original maturity is determined by reference to the frequency with which liquidity is available according to current Argentine GAAP guidance and practice. However, under SFAS No. 95 “Statement of Cash Flows,” the original maturity is determined by reference to the stated term of the security or the timeframe for exercising any put features to the issuer, not by reference to the frequency with which liquidity may be available through an auction, a put feature to a third party, or otherwise. As a result, differences exist be tween the total amount of the increase or decrease in cash and cash equivalents reported in the primary financial statements and the same totals that would be reported in a statement of cash flows prepared based on US GAAP amounts. In addition, differences exist between cash flows from operating, investing and financing activities reported in the primary financial statements and the cash flows from operating, investing and financing activities that would be reported under SFAS No. 95. For a description of the total amounts of cash and cash equivalents and other differences under US GAAP see Note 12 to our Financial Statements.

Our primary sources and uses of cash during the years ended December 31, 2007, 2006 and 2005 are shown in the table below:

	For the years ended December 31,
	2007	2006	2005
	(in millions of pesos)
Cash and cash equivalents at the beginning of the year	478.3	512.9	335.8
Cash flows provided by operating activities	518.4	606.2	584.7
Cash flows used in investing activities	(232.0)	(127.4)	(166.1)
Cash flows used in financing activities	(373.4)	(513.6)	(241.4)
Net (decrease) / increase in cash and cash equivalents	(87.0)	(34.7)	177.1
Cash and cash equivalents at the end of the year	391.3	478.3	512.9

Cash flows provided by operating activities

Cash flows provided by operating activities for the year ended December 31, 2007, decreased by approximately 14% compared to the year ended December 31, 2006, principally due to the fall in revenues generated by the NGL production and commercialization segment.

Cash flows provided by operating activities for the year ended December 31, 2006 increased slightly compared to 2005, mainly due to higher sales, although costs have increased as well, partially offsetting this positive variation. Cash flows provided by operating activities for 2005 included the refund from a pipeline supplier of an advance payment of US$22 million made in 2004 to secure pipe that ultimately was purchased by the Gas Trust in connection with the 2005 expansion of the San Martín pipeline. Increased cash flows were also partially offset by the cash payment that ended a lawsuit brought by GdE for which reserves had previously been established.

Cash flows used in investing activities

Cash flows used in investing activities in 2007 were higher by more than Ps. 100 million in comparison with the year 2006, principally due to Ps. 32.4 million investments for the expansion of a plant in Cerri Complex in order to increase its annual production capacity by 33,069 short tons of propane, butane and natural gas, and a fixed term deposit of Ps. 28.4 million with a maturity of more than 90 days.

Cash flows used in investing activities in 2006 were lower by 23.3%, or approximately Ps. 38.7 million, in comparison with 2005. In 2005 we invested approximately Ps. 100 million in the San Martín pipeline expansion, while in 2006 other incremental capital expenditures increased over 2005.

Cash flows used in financing activities

Although cash flows used in financing activities in 2007 were lower by Ps. 140.1 million in comparison to year 2006, they were significant because the cash was used primarily to reduce our financial indebtedness by more than 20%.

Cash flows used in financing activities more than doubled compared with 2005 as a result of our efforts, during 2006, to reduce our restructured debt.  In December 2006, we redeemed and prepaid US$130 million of this indebtedness. Such efforts were intended to strengthen our financial condition and support the future growth of our business.  In May and June 2007, we refinanced the remainder of our outstanding restructured debt.  See “—Description of indebtedness.”

Description of indebtedness

As described above, in June 2007 we issued new notes pursuant to our Medium Term Note Program. We are subject to several restrictive covenants under the New Notes that limit our ability to obtain additional financing, including limitations on our ability to incur additional indebtedness to create liens on our property, assets or revenues. Since our New Notes amortize, beginning on May 14, 2014, we will have annual obligations to repay principal on such debt. We are also subject to other restrictive covenants that impact our use of cash on hand, such as limitations on our ability to pay dividends to our shareholders, and limitations on our ability to sell our assets. See “Item 10. Additional Information—C. Material Contracts—New Notes” for a detailed discussion of the terms of our New Notes, including the interest rates and material covenants applicable to such indebtedness.

Future Capital Requirements

Details of our currently projected capital expenditures for the 2008-2010 period, in millions of U.S. dollars, are set forth in the following table:

	2008	2009	2010	Total
Gas transportation
Reliability and others	24.1	18.6	21.2	63.9
Expansions	41.8	54.3	-	96.1
Operational efficiencies	0.1	-	-	0.1
Total	66.0	72.9	21.2	160.1
NGL production and commercialization
Expansions	-	-	-	-
Reliability and others	8.7	14.4	14.2	37.3
Total	8.7	14.4	14.2	37.3
Other services	5.6	1.3	1.3	8.2
Total Capital Expenditures	80.3	88.6	36.7	205.6

We currently expect that our capital investment requirements will be financed primarily by cash from operations. Alternatively, expansion investments in the gas transportation segment are expected to be financed by the customers who will require additional services, such as the expansion made to accommodate the needs of Aluar mentioned in “Item 4. Our information—A. Our history and development—General”. Such customer-financed expansions will be repaid through the rendering of services.

Currency and exchange rates

Our primary market risk exposure is associated with changes in the foreign currency exchange rates because substantially all of our debt obligations are denominated in U.S. dollars and a significant portion of our revenue is denominated in pesos. Contributing to this exposure are the measures taken by the Argentine government since the repeal of the Convertibility Law and the pesification of our regulated tariffs. This risk is mitigated in part by our NGL production and commercialization segment, more than 90% of the revenues from which are denominated in U.S. dollars.

Our financial debt obligations denominated in foreign currency as of December 31, 2007, amounted to US$505.2 million (Ps. 1,590.6 million). As of December 31, 2007, we also had the equivalent of US$13.1 million (Ps. 41.3 million) of trade and other payables denominated in U.S dollars. Finally, US$150.7 million (Ps. 468.6 million) of our assets are denominated in U.S. dollars. Therefore, our net liability position in U.S. dollars amounted to US$367.6 million as of December 31, 2007.

We estimate, based on composition of our balance sheet as of December 31, 2007, that every exchange rate variation of Ps. 0.10 against the U.S. dollar, plus or minus, would result in a variation of Ps. 36.8 million of our consolidated net position in U.S. dollars. This sensitivity analysis provides only a limited view of the market risk sensitivity of certain of our financial instruments. The actual impact of market foreign exchange rate changes on our financial instruments may differ significantly from the impact shown in the sensitivity analysis.

Derivative financial instruments

Our Board of Directors has approved the terms for acquiring derivative financial instruments in order to hedge risks associated with the fluctuation of interest and exchange rates of our debt.

In November 2007, the Company entered into a currency forward agreement with a major financial institution, which expired on May 12, 2008. By means of this hedge agreement, the Company fixed an exchange rate of Ps. 3.227 per U.S. Dollar on the purchase of US$ 9 million in order to provide for the interest payment on the New Notes due on May 14, 2008. As of December 31, 2007, the fair value of this currency forward agreement was approximately (Ps. 90) and was recorded in “Current Loans” with credit to “Other Comprehensive Loss” account.

We do not believe that we are exposed to significant interest rate risk because the interest rates on our debt obligations do not change with the market.

C. Research and development, patents and licenses, etc.

Not applicable.

D. Trend information

See “—Discussion of Results of Operations for the Three Years ended December 31, 2007, 2006 and 2005” and “Item 8—Financial Information—A. Consolidated Statements and Other Financial Information—Legal and regulatory Proceedings.”

E. Off-balance sheet arrangements

We currently do not have any off-balance sheet arrangements or significant transactions with unconsolidated entities not reflected in our consolidated financial statements. All of our interests in and/or relationships with our subsidiaries or jointly-controlled entities are recorded in our consolidated financial statements. See “—Liquidity and Capital Resources—Derivative Financial Instruments”.

F. Tabular disclosure of contractual obligations

The following table represents a summary of our contractual obligations as of December 31, 2007:

	Payment due by period (in millions of pesos)
	Total	Less than 1 year	1-3 years	4-5 years	More than 5 years
Long-Term Debt Obligations	1,590.1	15.6	-	-	1,574.5
Capital Lease Obligations	0.7	0.7	-	-	-
Purchase Obligations(1)	67.7	29.6	38.1	-	-
Other Long-Term Liabilities(2)	229.2	34.9	91.7	102.6	-
Total	1,887.7	80.8	129.8	102.6	1,574.5

(1)

Corresponds to contracts for the purchase of natural gas used in our NGL production and commercialization activities.

(2)

Corresponds to the fee to be paid under the Technical Assistance Agreement.

All of the debt obligation amounts set forth above are U.S. dollar-denominated and, therefore, principal and accrued interest included in the amounts presented have been converted to peso amounts using the selling exchange rate of US$1=Ps. 3.149 as of December 31, 2007. Actual foreign currency debt payments may significantly differ from these estimates due to exchange rate fluctuations.

Item 6.

Directors, Senior Management and Employees

A.

Directors and Senior Management

General.Management of our business is vested in the Board of Directors. Our By-laws provide for a Board of Directors consisting of nine Directors and nine Alternate Directors. In the absence of one or more Directors, Alternate Directors will attend meetings of the Board of Directors. Directors and Alternate Directors are elected at an ordinary meeting of shareholders and serve one- to three-year renewable terms, as decided by the shareholders.

Under our By-laws and Argentine law, the Board of Directors is required to meet at least once every three months. A majority of the members of the Board constitutes a quorum, and resolutions must be adopted by a majority of the Directors present. In the case of a tie, the Chairman or the person replacing him at a particular meeting is entitled to cast the deciding vote.

At the Annual Shareholders’ Meeting held on April 2, 2004, the number of Directors on our Board was increased by two members to nine from seven. Additionally, the shareholders decided at that meeting that upon motion by the Chairman, our Board of Directors’ meetings may now be held by video or telephone conference.

The current Board of Directors was elected by our shareholders at the Annual Shareholders’ Meeting held on April 10, 2008, for a one-year term.

The Shareholders Agreements contain provisions governing the voting of our shares held by CIESA, the election of the members of our Board of Directors and certain other matters. For more information see “Item 7. Major Shareholders and Related Party Transactions—A. Major Shareholders—Shareholders Agreements.”

Duties and Liabilities of Directors.Under Argentine law, Directors have the obligation to perform their duties with the loyalty and diligence of a prudent business person. Directors are jointly and severally liable to us, shareholders and third parties for the improper performance of their duties, for violating the law, our By-laws or regulations, if any, and for any damage caused by fraud, abuse of authority or gross negligence. Under Argentine law, specific duties may be assigned to a Director by our By-laws or regulations or by a resolution of a shareholders’ meeting. In such cases, a Director’s liability will be determined with reference to the performance of such duties, provided that certain recording requirements are met. Moreover, under Argentine law, Directors are prohibited from engaging in activities in competition with us without express shareholder authorization. Certain transactions between us and Directors are subject to ratification procedures established by Argentine law.

A Director will not be liable if, notwithstanding his presence at the meeting at which a resolution was adopted or his knowledge of such resolution, a written record exists of his opposition thereto and he reports his opposition to the Supervisory Committee before any complaint against him or her is brought before the Board, the Supervisory Committee, a Shareholder Meeting, competent governmental agency or the courts. Shareholder approval of a Director’s performance terminates any liability of a Director vis-à-vis us, provided that shareholders representing at least 5% of our capital stock do not object and that such liability does not result from a violation of the law or our By-laws or regulations.

Causes of action against Directors may be initiated by us upon a majority vote of shareholders. If a cause of action has not been initiated within three months of a shareholders’ resolution approving its initiation, any shareholder may initiate the action on behalf of and for our account.

At the Annual Shareholders’ Meeting held on March 6, 1996, our shareholders approved the acquisition of civil liability insurance coverage for directors, members of our Supervisory Committee (“Syndics”) and officers. Such coverage is common practice among public companies who seek protection against shareholders’ and other parties’ claims.

Three of the members of our Board of Directors qualify as independent as defined in Section 301 of the Sarbanes Oxley Act and Resolution No. 368 of the CNV. All three are also members of our Audit Committee. The remainder of the members of the Board of Directors are not independent. Under the independence requirements a director is not independent if any of the following apply:

§

is also member of the administrative body or dependent on shareholders who hold “significant shareholding” of the issuer, or any corporation in which those shareholders hold direct or indirectly “significant shareholding”,

§

is engaged or was engaged during the last three (3) years to the issuer under a contract of employment,

§

provides, or belongs to a professional corporation or association which renders professional services to, or receives any form of remuneration or fees (other than the corresponding remuneration for its position in the administration body) from the issuer or those shareholders that have any direct or indirect “significant shareholding” in the Company or from corporations in which shareholders also have any direct or indirect “significant shareholding”,

§

direct or indirectly holds “significant shareholding” in the issuer or any corporation which holds “significant shareholding” in the latter,

§

direct or indirectly sells or provides goods or services to the issuer or its shareholders, who hold direct or indirect “significant shareholding”, for an amount substantially higher than the compensation received for their position as members of the administration body,

§

is husband or wife, close relative up to fourth degree of kinship or second degree of relationship that, in case of being member of the administration body, would not be independent as set forth in the CNV regulations.

In all cases “significant shareholding” refers to those shareholders holding at least thirty-five per cent (35%) of the Company’s common stock, or less in cases when they are entitled to appoint one or more directors per class of share, or have agreements with other shareholders relating to management and administration of any such companies, or its controlling entity.

The following table sets out the membership of our Board of Directors as approved in our Annual Shareholders’ Meeting held on April 10, 2008, their respective positions on the Board and the year they were appointed to such position.

Name	Year of Appointment	Term Expires	Position	Position in other Company
Claudio Fontes Nunes	2008	2009	Chairman	Gas and Energy Vice president at Petrobras Energía
Mariano Pablo González	2007	2009	Vice Chairman	Member of the law firm González & Ferraro Mila
Carlos Alberto Seijo	2006	2009	Director	Marketing manager of the natural gas division at Petrobras Energía
Gustavo Sebastián Viramonte	2006	2009	Director	Member of the law firm Viramonte & Acuña
Diego Alberto Guerri	2006	2009	Director	Member of the law firm Zarantonello & Guerri
Rigoberto Mejía	2006	2009	Director	Manager of the Division Integration and Participations at Petrobras Energía.
Luis Blaquier	2007	2009	Independent Director	Independent consultant
Carolina Sigwald	2004	2009	Independent Director	Member of the law firm Díaz Bobillo Richard & Sigwald
Oscar Marano	2005	2009	Independent Director	Independent consultant
Héctor Daniel Casal	2008	2009	Alternate Director	Legal Director at Petrobras Energía
Gabriel Marchione	2007	2009	Alternate Director	Financial Manager of Petrobras Energía
Pablo Alejandro Melhem Marcote	2007	2009	Alternate Director	Member of the law firm González & Ferraro Mila
Esteban Diez Peña	2004	2009	Alternate Director	Management Control Manager for the Oil, Gas and Energy Upstream Areas at Petrobras Energía
Joaquín Acuña	2006	2009	Alternate Director	Member of the law firm Viramonte & Acuña
Andrea Patricia Gribov	2006	2009	Alternate Director	Member of the law firm Zarantonello & Guerri
Gabriela Domínguez Segado	2007	2009	Independent Alternate Director	Member of the law firm González & Ferraro Mila
Oscar Miguel Castro	2006	2009	Independent Alternate Director	Independent consultant
Diego Petrecolla	2007	2009	Independent Alternate Director	Independent consultant

Additional information regarding the occupation and employment background of each of our regular Directors is set forth below:

Claudio Fontes Nunesholds a degree in Civil Engineering with a concentration in Hydraulic Works from Universidade Federal do Rio de Janeiro. He is also a graduate of the Advanced Management Program from Harvard University. He joined Petrobras Energía in 1980, where he has specialized in petroleum engineering, and at various times during this tenure with Petrobras, he has been in charge of Well Evaluation Operations, Projects Analysis, Contracts, Production Engineering, Engineering and Health, Safety and Environment. He currently serves as Vice President of Gas and Energy of Petrobras Energía and a member of the Board of Directors of Petrobras Energía Participaciones S.A., Petrobras Energía, Edesur S.A., CIESA, Distrilec Inversora S.A. and MEGA. He was born on April 6, 1956.

Mariano Pablo González received a Law degree from the University of Belgrano. In 1996, he obtained a Master’s degree in Corporate Law from the Columbia University School of Law. Before holding his current position, he worked for the CNV; Milbank, Tweed, Hadley & McCloy; Linklaters; Marval, O´Farrell & Mairal and Beccar Varela. Mr. González is currently a partner at the law firm of González & Ferraro Mila. He currently is a member of the board of directores of Fondomonte el Descanso S.A., Fondomonte Sandoval S.A., EPCA, Manos del Plata S.A., Boring S.A., FTI Consulting S.A., CIESA and Fondomonte Inversiones de Argentina S.A.  He was born on May 24, 1969.

Carlos Alberto Seijo received a Chemical Engineering degree from the University of Buenos Aires. He has worked for Central Puerto S.A. He joined Petrobras Energía in 1999 as New Business Planning Manager for the Gas and Energy Division. He currently holds the position of Gas Natural Marketing Manager. He is also member of the Board of Directors of CIESA and MEGA. He was born on November 27, 1959.

Gustavo Sebastián Viramonte received a Law degree from the Universidad Nacional de Córdoba. He obtained a Master’s Degree in Business Law from Universidad Austral. He has worked for Viramonte & Asociados S.C. and since 2001 and is a partner of the law firm Viramonte & Acuña. He is also a member of the Board of Directors of Nortel Inversora S.A. and CIESA. He was born on May 30, 1970.

Diego Alberto Guerri received a Law degree from the University of Buenos Aires. He has been chairman of Cirqui S.A., Dispel S.A. and Faique S.A. He is currently a partner of the law firm Zarantonello & Guerri, Chairman of several companies, including Quilseg S.A., Quiel Investment S.A. and Quilburs S.A., and liquidator of Scotia Holding Argentina S.A. He is also a member of the Board of Directors of CIESA. He was born on January 8, 1969.

Rigoberto Mejía has a Master’s Degree in Engineering Sciences and an Electrical Civil Engineering degree, both obtained at the University of Chile. He also obtained a Master’s Degree in Business Administration from the Instituto de Altos Estudios Empresariales of the Universidad Austral. Before joining Petrobras Energía, he worked for Central Puerto S.A. and Gener Argentina S.A. He currently works as Manager of the Division Integration and Participations at Petrobras Energía. He is also member of the boards of directors of the following companies: Distrilec Inversora S.A., EDESUR S.A., MEGA, CIESA, Telcosur, EGS, TGU, Enecor S.A., Petrobras Electricidad de Argentina S.A. and Petrobras Finance Bermuda Ltd.. He was born on November 7, 1963.

Luis Blaquierreceived a degree in Economics from the Universidad Católica Argentina. He also obtained a Master in Business Administration - Finance at Dartmouth College in 1993. He was Executive Director at Goldman Sachs & Co. (Investing Banking Division) in the United States. He also worked at Alliance Capital Management LP and previously worked as an Associate at Ledesma. He currently acts as Director of Texas Emerging Energy S.A. and Grupo Clarín S.A. He was born on October 26, 1965.

Carolina Sigwald received a Law degree from the University of Buenos Aires. She worked at Chadbourne and Parke LLP in New York between 1996 and 1997 and at the Inter-American Investment Corporation in Washington D.C. between 1997 and 1998. She is currently a partner at the law firm Díaz Bobillo, Richard & Sigwald in Buenos Aires. She is a member of the Board of Directors of Supertap S.A., Gener Argentina S.A., Energen S.A., Termoandes S.A., Interandes S.A., Taurus de Argentina S.A., GMF Latinoamericana S.A., Procesix Argentina S.R.L., Minera Andacollo Gold S.A., Latin Luz S.A. and Heirdrick & Struggles S.A. She was born on November 15, 1967.

Oscar Marano received a degree in Public Accounting and a Master’s Degree in Administration from the University of Buenos Aires. He has worked for Edenor S.A., Astra S.A., Compañía Financiera Eugenio Diez S.A., Eugenio Diez S.A. and EDF Branch Americas. He currently acts as an independent consultant. He was born on October 20, 1943.

Executive Officers. The following is a list of our executive officers as of the date of issuance of this Annual Report, their respective positions with us and the year they were appointed to such position:

Name	Year of Appointment	Position
Jorge Casagrande	2006	CEO
Jorge García	1998	Marketing Vice President
Gonzalo Castro Olivera	2007	Chief Financial Officer (“CFO”)
Jorge Bonetto	2000	Operations Vice President
Daniel Perrone	1999	Regulatory and Institutional Affairs Vice President
Carlos Ariosa	2006	Legal Affairs Vice President
Juan Martín Encina	2004	Human Resources Vice President
Alejandro Basso	1998	Control and Corporate Governance Vice President
Oscar Sardi	2005	Services Vice President
Javier Sato	2008	Planning and Business Development Vice President

There is no expiration term defined for the Executive Officers.

Below is a description of the main activities currently carried out by each of our executive officer, together with the biographical information thereof:

Jorge Casagrande received a degree in Public Accounting from theUniversidad Católica Argentina. He has worked for Massalin Particulares and Pricewaterhouse Coopers. He joined Petrobras Energía in 1992, where he served, among other things, as Planning and Corporate Management Control Manager for the Electricity and Gas Business. Since October 2006, he has acted as our CEO. He is also a member of the Board of Directors of Telcosur, EGS and TGU. He was born on February 18, 1968.

Jorge García received a degree in Public Accounting from theUniversidad de Buenos Aires. He has been with the Petrobras Energía group since 1980. He has worked for several companies within the group, including Petrobras Energía from 1980 to 1986, PASA from 1987 to 1991 and Central Costanera S.A. during 1992. From 1992 until September 1, 1998, he served as CFO of TGS. He is currently our Marketing Vice President. He is Vice Chairman of the Board of Directors of Link, EGS and TGU. He was born on March 1, 1952.

Gonzalo Castro Oliverareceived a degree in Business Administration from theUniversidad de Belgrano and a Master’s Degree in Finance from theUniversidad Torcuato Di Tella. Between 1997 and 1998, he worked for the ABN AMRO Bank and, between 1991 and 1997, he worked at BankBoston. In both banks he worked in corporate banking. He joined us as Head of Capital Markets in 1998, and from 2005 to 2007, he was our Finance and Corporate Information Manager. He became CFO in 2007. He was born on October 23, 1968.

Jorge Bonetto received an Electromechanical Engineering degree from theUniversidad Nacional de Córdoba and obtained a Master’s Degree in Business Administration from theUniversidad Austral. Before joining TGS, he worked for PASA, Petroquímica Cuyo S.A. and Corcemar S.A. He joined us in May 2000 as Operations Vice President. He was born on August 2, 1952.

Daniel Perrone received a Mechanical Engineering degree from theUniversidad Tecnológica Nacional. He has previously worked for Cometarsa S.A., Matoil S.A., Servoil S.A., Bridas S.A.P.I.C. and TransCanada International. Since the end of 1999, he has served as our Regulatory Matters and Rates Vice President and, since August 2001, has also been responsible for Institutional Affairs. He was born on August 29, 1948.

Carlos Ariosa received a Law degree from theUniversidad Católica Argentina, and has taken several post-graduate specialization courses in Law and Administration of the Electric Market. He has held positions in the public and private sector. Between 1998 and 2006, he worked for Petrobras Energía, forming part of the Legal Affairs Direction. He has been a member of the Supervisory Committee of several utilities, including Edesur S.A., Transener S.A., Transba S.A., Yacylec S.A., Enecor S.A. and MEGA. He was born on February 2, 1966.

Juan Martín Encina received a Law degree from theUniversidad de Buenos Aires and obtained a Master’s Degree in Human Resources from theUniversidad de Ciencias Empresariales y Sociales. Since 2000, he has served as Human Resources Department Vice President of Petrobras Energía for the Gas and Energy business and Centralized Functions. Prior to that, he headed Human Resources actions for different projects in Ecuador and Brazil, and in Argentina he has been responsible for Labor Relations Areas at utilities of the electric and railway sectors. He was born on March 2, 1967.

Alejandro Basso received a Public Accounting degree from theUniversidad de Buenos Aires. He worked for Petrobras Energía from 1987 to 1992 and for Quitral-Co S.A. from 1992 to 1994. From 1994 to 1998, he acted as our Planning and Corporate Control Manager and between September 1998 and March 2008 he was our Planning and Control Vice President. Since March 2008, he has been our Control and Corporate Governance Vice President. He also acts as Vice Chairman of TGU and member of the Board of Directors of EGS. He was born on October 13, 1961.

Oscar Sardi received a Mechanical Engineering degree from theUniversidad Tecnológica Nacional. He also participated in a General Administration Program at theUniversidad Austral. He worked for Gas del Estado between 1983 and 1992 and during that year he held different positions in our services area. In April 2005 he was designated Services Department Vice President. He also acts as member of the Board of Directors of Link. He was born on September 1, 1955.

Javier Sato received a Chemical Engineering degree from theUniversidad de Buenos Aires. Before joining us in April 2008 as Planning and Business Development Vice President, he worked for Petrobras Energía in several positions. Between October 2005 and March 2008 he acted as CEO of Conecta (a gas distribution company in Uruguay). Up to March 2005 he served as Planning and Business Development Manager of the refining, petrochemical and fertilizing business unit of Petrobras Energía and between April 2005 and September 2005 he worked for Petrobras Brazil. He was born on June 28, 1956.

Indemnification of Officers and Directors. Under the Shareholders Agreement, the shareholders of CIESA require us to: (i) limit the liability of each of our officers, syndics and directors for all consequences of their acts or omissions, excluding acts or omissions where there is evidence of fraud or gross negligence and (ii) enter into agreements obligating us to defend, indemnify and hold harmless each of our officers, syndics and directors from and against all liabilities, losses, and other expenses incurred by each such officer, syndics or director in connection with a pending, threatened or completed civil, criminal, administrative or other proceeding, or any investigation that could lead to such a proceeding, by reason of the fact that such officer, syndics or director is or was one of our officers, syndics or directors, including claims alleged to be due to the negligence of such person, but excluding acts or omissions that involve fraud or gross negligence towards us.

B.

Compensation

The remuneration paid or accrued by us during the year 2007 in favor of our members of the Board of Directors and executive officers amounted to Ps. 0.7 million and Ps. 4.6 million, respectively.

We do not grant pension or retirement plans or other benefits to members of our Board of Directors or to our executive officers.

Executive officers are subject to a goal-directed management system and a variable remuneration program. Consensual objectives, whether individual or by sector, are in line with our global objectives, as the variable remuneration program links a portion of its compensation to the performance thereof and our performance.

C.

Board Practices

For information on the term of office of our directors and executive officers, see“—Directors and Senior Management” above. The information in that section is incorporated herein by reference.

None of the members of our Board of Directors are party to any service contract with us or any of our subsidiaries providing for benefits upon termination of employment.  

Audit Committee

According to the “Public Offering Transparency Regime” regulated under Decree No. 677/01, as supplemented by Resolutions No. 400 and 402 issued by the CNV, publicly listed companies must have an Audit Committee “that will function on a collegiate basis with three or more members of the Board of Directors, the majority of whom must be independent under CNV regulations.”  On May 26, 2003, our Board of Directors approved the form of Rules of Procedure of the Audit Committee in order to comply with the provisions mentioned above.

Also in compliance with the above resolutions, at the Ordinary and Extraordinary Shareholders’ Meeting of April 2, 2004 the shareholders approved the amendment of the by-laws in order to incorporate a section relating to the structure and operation of the Audit Committee.

The Audit Committee operates under its Rules of Procedure, which require that the three members that form it must be independent according to the standards of the SEC and the CNV. Committee members are designated by a simple majority of the Board of Directors, at the first meeting following designation of the members of the Board of Directors, and they hold office until their successors are designated. The Audit Committee adopts its own regulations and must prepare a working plan for each fiscal year. At the Shareholders’ Meeting held on April 10, 2008, Oscar Marano, Luis Blaquier and Carolina Sigwald were designated as independent members of the Board of Directors.

The Committee’s mandatory periodic duties are to:

·

supervise the internal control and accounting systems as well as the reliability of the latter and all the financial information and other significant issues that are to be submitted to the SEC, CNV and BASE in compliance with the applicable disclosure policies;

·

supervise the application of information policies regarding our risk management;

·

ensure that the market is informed about those operations where there may be a conflict of interest with one or more of the members of the Board of Directors, controlling shareholders or other parties as defined by the applicable regulations;

·

express its view on the reasonableness of fees, compensation proposals and stock option plans for directors and officers submitted by the Board of Directors;

·

express its view as to compliance with laws and regulations and the reasonableness of the conditions of an issuance of shares (or convertible securities), in the case of a capital increase excluding or limiting preferential rights;

·

verify compliance with the Code of Conduct;

·

issue a well-founded opinion on whether the terms and conditions of relevant transactions with related parties are according to market practice, within five calendar days from the receipt of a petition issued by the Board of Directors, and at any other time at which a conflict of interests exists or might exist;

·

prepare an annual performance plan for the fiscal year and notify the Board of Directors and the Supervisory Committee within 60 days from the beginning of the period;

·

fulfill all the obligations stated in our By-laws and applicable laws and regulations;

·

express its view on the Board of Directors’ proposals appointing (or rejecting) the external auditors to be hired and monitor the auditors’ independence;

·

establish procedures for: 1) the receipt, treatment, investigation and administration of the complaints received by us regarding accounting, internal accounting. Controls or internal auditing matters, and 2) the confidential, anonymous submission by our employees of concerns regarding questionable accounting or internal auditing matters.

Also, regarding the internal and external auditors, the Committee shall:

·

review their plans; and

·

evaluate their performance, and give an opinion on their performance when issuing the annual financial statements.

In evaluating the external auditors’ performance, the Committee shall:

·

analyze the different services rendered by the external auditors as well as their independence, according to TR No. 7 of the Argentine Federation, any other related regulations issued by professional councils and those regulations set by Resolution No. 400/02, section 4 and Chapter 18, section 18 of the CNV rules;

·

report separately the fees payable as follows: (i) fees for external audit and other related services meant to provide reliability to third parties (e.g., special reports about internal controls, shareholding prospectuses, certifications and special reports requested by regulators, etc.); and (ii) fees related to other special services different from those mentioned above, such as those associated with design and implementation of systems, laws and regulations, financial issues, etc.; and

·

verify the independence of the external auditors in accordance with internal policies.

Additionally, the Committee must perform the following mandatory duties contained in the regulatory framework:

·

give a prior assessment, within five days of notification, that shall be used by the CNV to require us to designate an external auditor as requested by minority shareholders, as long as such shareholders represent at least 5% of our common stock (in those cases in which the minority shareholders’ rights might be affected), in order to carry out one or more specific revisions. The charges of such revisions shall be paid by the petitioning shareholders (Decree No. 677/01, section 14, article e; Regulation No. 400/02, section 4; and Chapter 3, section 23, of the CNV rules);

·

provide a well-founded assessment about an acquiring tender offer if by withdrawing the public offering if we would cease to be a public company or our stock cease to be traded (Decree No. 677, section 32; Resolution No. 401/02, sections 25 and 27); and

·

issue a report supporting a Board of Directors’ resolution to buy back our shares (Decree No. 677/01, section 68, article b; Resolution No. 400/02, section 4 and Chapter 3, article 11 of the CNV rules).

Once a year, the Audit Committee shall prepare a plan for the fiscal year to be presented to the Board of Directors and to the Supervisory Committee. The Directors, members of the Supervisory Committee, managers and external auditors shall, when requested by the Audit Committee, attend its meetings, provide the Audit Committee with information and otherwise assist the Audit Committee in the performance of its functions. In order to better perform its functions, the Audit Committee may seek the advice of legal counsel and other independent professionals at our expense, pursuant to a budget approved by shareholders. The Audit Committee shall have access to the information and documents it may deem necessary to perform its duties.

According to CNV rules, at least once a year and upon the filing of the annual financial statements, the Audit Committee shall issue a report to the shareholders, addressing how the Committee performed its duties and the results of its work.

The aggregate remuneration paid by us during the year 2007 to the members of the Audit Committee was approximately Ps. 0.2 million. We do not provide pension, retirement or similar benefits to any member of the Audit Committee.

Supervisory Committee

The Supervisory Committee is our monitoring body as stipulated in Section No. 284 of the Commercial Companies Law. Our By-laws provide for a Supervisory Committee consisting of three Syndics and three alternate members (“Alternate Syndics”). In accordance with our By-laws, two Syndics and the corresponding Alternate Syndics are elected by a majority vote of the holders of our Class A Shares. The remaining Syndic and corresponding Alternate Syndic are elected by the majority vote of the remaining holders of our common stock. Each member of the Supervisory Committee is elected at the Annual Ordinary Shareholders’ Meeting and serves for a one-year renewable term. Members of the Supervisory Committee must be lawyers or accountants qualified under Argentine law and, for the accountants, Technical Resolution No. 15. Our directors, officers and employees may not be members of the Supervisory Committee. Our By-laws re quire the Supervisory Committee to hold meetings at least once per month.

The primary responsibilities of the Supervisory Committee consist of monitoring our management’s compliance with the Commercial Companies Law, our By-laws and the shareholders’ resolutions, and without prejudice to the role of external auditors, reporting to the shareholders at the Annual Ordinary Shareholders’ Meeting regarding the reasonableness of our financial information. Furthermore, the members of the Supervisory Committee are entitled to: (i) attend Board of Directors and Shareholder Meetings, (ii) call Extraordinary Shareholders’ Meetings when deemed necessary and Ordinary Shareholders’ Meetings when the Board of Directors fails to do so, and (iii) investigate written inquires initiated by shareholders. The Supervisory Committee does not control our operations or evaluate management’s decisions, which are the exclusive responsibility of the Board of Directors.

The aggregate remuneration paid or accrued by us during 2007 to the members of the Supervisory Committee was approximately Ps. 0.2 million. We do not provide pension, retirement or similar benefits for Syndics and Alternate Syndics.

The current members of the Supervisory Committee, each of whom was appointed at the Annual Shareholders’ Meeting held on April 10, 2008, the year each member was initially appointed to the Supervisory Committee and the year each members’ term expires are as follows:

Name	Member since	Term Expires	Position
José María Zuliani	2005	2009	Syndic
Nicolás Martín Mordeglia	2004	2009	Syndic
Pablo Ferraro Mila	2007	2009	Syndic
Enrique Prini Estebecorena	2005	2009	Alternate Syndic
Bárbara Vons	2006	2009	Alternate Syndic
Ignacio Acedo	2008	2009	Alternate Syndic

The present principal occupations and employment history of our Syndics are set forth below:

Mr. José María Zulianireceived Law degree from the National University of Rosario. He has held several managing positions at Petrobras Energía and currently is the Gas and Energy Legal Affairs Manager. He is also a member of the statutory committee of CIESA, Telcosur, MEGA, Distrilec Inversora S.A., Edesur S.A., Enecor S.A. and Urugua-i S.A.. He was born on December 13, 1961.

Mr. Nicolás Mordeglia received a Law degree from the University of Buenos Aires and a Master’s degree in Business Law from Austral University. He worked for Cerro Vanguardia S.A. from 1995 to 1999. Since 1999, he has worked for the Legal Affairs Department of Petrobras Energía. He serves as a member of the Supervisory Committee of CIESA, Enecor S.A., Urugua-i S.A., Distrilec Inversora S.A., Edesur S.A., Telcosur, and MEGA and he acts as alternate director of Petrobras Energía Internacional S.A.. He was born on August 17, 1965.

Pablo Ferraro Milareceived a Law degree from the Universidad de Belgrano. In 1996, he received a Master’s Degree in Comparative Jurisprudence from the New York University School of Law, as well as Master’s Degree in Business Law from Universidad Austral. At present he is a partner of the law firm González & Ferraro Mila. Before joining Gonzalez & Ferraro Mila, he was a Junior Partner at the law firm Beccar Varela (since 1999) and an associate at the law firms of Cravath, Swaine & Moore in New York, Allen & Overy in London, and Allende y Brea in Buenos Aires and New York. He also serves as a syndic of CIESA and EPCA and he is a member of the boards of directors of FTI Consulting S.A. and Agro Terra S.A.. He was born on February 7, 1970.

Remuneration Committee

We do not have a remuneration committee. Compensation decisions are made by our senior management.

Corporate Governance Practices; New York Stock Exchange Requirements

Our corporate governance practices are governed by applicable Argentine law (particularly, the Commercial Companies Law), Decree No. 677/01, the standards of the CNV and our By-laws. We have securities that are registered with the SEC and listed on the New York Stock Exchange (the “NYSE”) and, consequently, we are subject to the rules and regulations of the NYSE.  

On November 4, 2003, the NYSE established new corporate governance standards (“NYSE Standards”) that are applicable to NYSE-listed companies, including non-U.S. companies. Under these standards, non-U.S. companies are permitted, in general, to follow their home country corporate governance practices in lieu of most of the new NYSE corporate governance requirements codified in Section 303A of the NYSE’s Listed Company Manual (the “NYSE Sections”).However, non-U.S. companies must comply with NYSE Sections 303A.06, 303A.11 and 303A.12(b) and (c). Non-U.S. companies must have been in compliance with Section 303A.06 prior to July 31, 2005. Section 303A.11 requires that non-U.S. companies disclose any significant ways in which their corporate governance practices differ from those followed by U.S. companies under NYSE listing standards. Specifically, a non-U.S. company is required to provide a brief, general summary of the significant differences by means of (i) the company’s website (in English) and/or (ii) the company’s annual report distributed to its investors in the United States.  

Pursuant to the requirements of Section 303A.11, the following table summarizes the significant differences between Argentine corporate governance standards and those required of U.S. companies in accordance with the NYSE Sections:

NYSE Section	Requirement of NYSE Section	Argentine Requirements and Our Practice as provided by Argentine law (including Commercial Companies Law and Decree No. 677/01 issued by Executive Branch), CNV regulation requirements and our By-laws
Director Independence
303A.01	Listed companies must have a majority of independent directors on their Board of Directors.	Companies are not required to have a majority of independent directors on their boards of directors. At our Annual Shareholders’ Meeting, held on April 10, 2008 our shareholders appointed three independent directors (together with one alternate independent director) out of nine directors of whom the Board of Directors is composed.
303A.02	Establishes general standards to evaluate directors’ independence (no director qualifies as “independent” unless the Board of Directors affirmatively determines that the director has no material relationship with the listed company (either directly or as a partner, shareholder or officer of an organization that has a relationship with the company), and emphasizes that the director is independent from management. The Board of Directors is also required to express an opinion with regard to the independence or lack of independence, of each individual director.	To qualify as an “independent” or “non-independent” director, CNV standards (General Resolution No. 400/02) are substantially similar to the NYSE standards. CNV standards provide that independence is required with respect to a company and to its controlling shareholders or to shareholders with material holdings (35% or more) and that, for any person to be appointed as an independent director, such person must not perform executive functions within the company. Close relatives of any persons who would not qualify as “independent directors” would also not be considered “independent.” When directors are appointed, each shareholder that nominates a director is required to report at the meeting whether or not such director is independent.
303A.03	The non-management directors of each listed company must meet at regularly scheduled executive sessions without management.	None of Argentine law, the CNV rules or our By-laws requires that any such meetings be held. Under Argentine law, a Board of Directors must meet at least once every three months. Under our By-laws, our Board of Directors must meet at least every three months.
Nominating/Corporate Governance Committee
303A.04	Listed companies must have a nominating/corporate governance committee composed entirely of independent directors, with a written charter that addresses the committee’s purpose and responsibilities and an annual performance evaluation of the committee.	None of Argentine law, the CNV rules or our By-laws requires the establishment of a nominating/corporate governance committee. The right to nominate directors is vested in the shareholders and nominations are made at our annual shareholders’ meeting. Pursuant to CNV standards, the person who nominates a director is required to report at the shareholders’ meeting whether or not the nominee is an “independent person” based on criteria established by the CNV (which are substantially similar to NYSE standards).
Management Resources and Compensation Committee
303A.05	Listed companies must have a compensation committee composed entirely of independent directors, with a written charter that addresses the committee’s purpose and responsibilities and an annual performance evaluation of the committee.	None of Argentine law, the CNV regulations or our By-laws requires the establishment of a compensation committee. However, our Audit Committee is required to give an opinion about the reasonableness of directors’ and executive officers compensation and stock option plans (if applicable), as proposed our Board of Directors. The compensation of members of our Board of Directors is approved by our Shareholders at their Annual Meeting.
Audit Committee
303A.06	Listed companies must have an “Audit Committee” that satisfies the requirements of Rule 10A-3 under the Exchange Act.	According to Decree No. 677/01 audit committees must have a majority of independent members. Our Audit Committee is composed of three members of the Board of Directors who qualifies as independent as defined in Section 301 of the Sarbanes Oxley Act and CNV Resolution No. 368/02. Our Audit Committee satisfies the requirements of Rule 10A-3 under the Exchange Act of 1934.
303A.07 (a)	An Audit Committee shall consist of at least three members. All of its members shall be financially literate or must acquire such financial knowledge within a reasonable period and at least one of its members shall have expertise in accounting or financial management.	Argentine law requires an Audit Committee to be comprised of at least three members. Pursuant to CNV standards, Audit Committee members are required to be conversant in business, financial or accounting matters and issues.  In addition, CNV standards require the training of an Audit Committee’s members in the practice areas that would permit them to carry out their duties on the Audit Committee.   One of our Audit Committee members qualifies as a “financial expert” within the meaning of Item 16A of the Form 20-F. See “Item 16A. Audit Committee Financial Expert.”
303A.07 (a)	If a member of the Audit Committee is simultaneously a member of the Audit Committee of more than three public companies, and the listed company does not limit the number of Audit Committees on which its members may serve, then, in each case the Board of Directors shall determine whether the simultaneous service would prevent such members from effectively serving on the listed company’s Audit Committee, and shall disclose its decision in the annual proxy statement of the company or in the company’s annual report on Form 10-K, which is filed with the SEC.	No comparable provision, relating to an Audit Committee member’s simultaneous membership on the Audit Committee of other public companies, exists under Argentine law, CNV standards or our By-laws.
303A.07 (c)	An Audit Committee shall have a written charter addressing (i) the committee’s purpose; (ii) an annual performance evaluation of the committee, and (iii) the duties and responsibilities of the committee, including, at a minimum, those required by Section 10A-3(b)(2-5) of the Exchange Act.	Local regulations do not require an annual performance evaluation of the audit committee. We have established a written charter governing our Audit Committee, which charter complies with the standards set by the CNV. The functions and responsibilities of our Audit Committee are described in “Item 6. Directors, Senior Management and Employees—C. Board Practices—Audit Committee.”
303A.07(d)	Provides that each company must have an internal audit function to provide management and the Audit Committee with ongoing assessments of the company’s risk management processes and system of internal control.	Under local regulations, an internal audit function is not required, nonetheless we have outsourced that function. Internal audit reports are addressed to the Audit Committee and the Board of Directors.
Equity Compensation Plans
303A.08	Shareholders must be given the opportunity to vote on equity-compensation plans and material revisions thereto, with limited exemptions set forth in the NYSE standards.	We do not have any stock option programs for our executive officers or senior management.  See “Item 6. Directors, Senior Management and Employees—B. Compensation.” Our audit committee has to give an opinion about the reasonableness of compensation and stock option plans, as approved by the Board of Directors.   As noted above, the determination of whether to compensate a director is made at a shareholders’ meeting.
Corporate Governance Guidelines
303A.09	Listed companies must adopt and disclose corporate governance guidelines.	Decree No. 677/01 lists additional information that issuers must include in their annual reports, such as  information relating to the company’s decision-making organizational structure (corporate governance), internal control system, directors’ and officers’ compensation, stock-options, and any other compensation system applicable to the members of a company’s Board of Directors and managers. Decree No. 677/01 does not address the remaining issues included in NYSE Section 303A.09.
Code of Ethics for Directors, Officers and Employees
303A.10	Listed companies must adopt and disclose a code of business conduct and ethics for directors, officers and employees, and promptly disclose any waivers of the code for directors or executive officers.	We have not adopted a code of ethics because Argentine public companies are not required to do so. However, in October 2005, our Board of Directors approved a “Code of Conduct” (replacing the previous Code of Conduct approved in March 2004, with the purpose of introducing SEC rules applicable to foreign registrants that apply to all Board of Directors’ members, Audit Committee members, Senior Management, and employees, with no exceptions. Our Code of Conduct is available to the public on our website and as an Exhibit to this Annual Report.
303A.12 (b)	The CEO shall notify the NYSE in writing whenever any executive officer of the company becomes aware of any material non-compliance with any applicable provision under NYSE Section 303A.	No comparable provision exists under Argentine law, the CNV standards or our By-laws.

12

D.

Employees

The following table sets out the number of employees according to department as of December 31, 2007, 2006 and 2005:

	Number of Employees as of December 31,
Department	2007	2006	2005
General	3	3	3
Administration and Finance	48	50	48
Human Resources	15	15	11
Planning and Management Control	7	7	7
Legal Affairs	11	10	9
Regulatory and Public Affairs	6	6	6
Services	61	60	54
Safety and Environmental	15	15	11
Marketing	66	60	59
Operations	638	580	561
Total	870	806	769

The following table sets out the number of employees according to geographical location as of December 31, 2007, 2006 and 2005:

	Number of Employees as of December 31,
Location	2007	2006	2005
City of Buenos Aires	235	196	175
Province of Buenos Aires	335	325	324
Province of Chubut	59	54	50
Province of La Pampa	16	15	15
Province of Neuquén	57	51	48
Province of Río Negro	60	61	60
Province of Salta	6	6	5
Province of Santa Cruz	95	91	89
Province of Tierra del Fuego	7	7	3
Total	870	806	769

As of December 31, 2007, 2006 and 2005 the number of temporary employees working for us was 17, 36 and 40, respectively.

Under Argentine law, in the event of an unfair dismissal of an employee, the employer is required to pay the terminated employee severance, the amount of which is regulated by the Argentine Labor Law (Section 245). The severance consists of payment of one month’s wages for each year of employment. The Argentine Labor Law stipulates limits to the severance payment; these limits affect only employees who earn high wages. However, the Supreme Court has ruled this severance payment limitation unconstitutional when it results in a loss of more than 33% for a terminated employee as compared to the non-limited amount.

The Supreme Court recently held the Law of Occupational Hazard Prevention unconstitutional as applied to contractors whose employees are injured in the course of employment, extending liability to the company that contracted with the contractor for the services.

Some courts have held that a company that contracts with a contractor for services is jointly liable for a contractor's obligations to provide its workers and third-party service providers with social security benefits, wages, insurance, etc., even if the service for which the company contracts is not part of the company's usual business.

Due to higher inflation rates in Argentina, conflicts between employers and unionized workers have increased recently. Even though these kind of conflicts have involved us only to a limited extent, other companies in our industry have suffered strikes and conflicts with labor unions. Despite this hostile atmosphere and the demands of the unions, in April 2008, we signed a one-year agreement with the labor unions which includes a salary increase. This agreement has to be officially approved by the Labor Ministry before becoming effective.

Currently, approximately 19% of our workforce is affiliated with one of three national unions, each of which has representation in each of the jurisdictions in which we operate.

E.

Share Ownership

The total amount of our Class B Shares held by our directors, members of our supervisory committee and executive officers as of March 31, 2008 is 67,691 shares.

Our directors and executive officers, individually and together, hold less than 1% of our Class B Shares.

Item 7. Major Shareholders and Related Party Transactions

A.

Major Shareholders

Our controlling shareholder is CIESA, which holds approximately 55.3% of our common stock. Local and foreign investors hold the remaining ownership in our common stock. CIESA is owned 50% by Petrobras, 40% by the Trust, and the remainder 10% by EPCA.

On April 16, 2004, Petrobras and Enron signed the Settlement Agreement, which contemplates a two-stage reorganization of CIESA’s ownership. The first stage of the reorganization was carried out on August 29, 2005. In this first stage, EPCA and EACH transferred 40% of the outstanding share capital of CIESA to the Trust, and Petrobras transferred Class “B” common shares (representing 7.35% of our outstanding share capital), which it held directly and not through CIESA, to EPCA and EACH.

On January 27, 2006, EPCA, EACH and other Enron’s subsidiary sold their shareholding in our common stock to D.E. Shaw.

The following table sets forth certain information, with respect to each shareholder known to us to own more than five percent of our common stock as of April 30, 2008:

Name of Beneficial Owner	Number of Shares	% TotalCommon Shares	Class
CIESA	405,192,594	51.0000	A
CIESA	34,133,200	4.2962	B
D.E. Shaw	60,803,041	7.653	B

Pursuant to the Pliego and our debt agreement, CIESA may not reduce its shareholding below 51% of our share capital.

As of April 30, 2008 a total of 19,012,058 ADRs, representing 95,060,290 Class B shares, were held by approximately 60 institutional investors and mutual funds. Because certain of these ADRs are held by nominees, the number of record holders may not be representative of the number of beneficial owners.

Shareholders Agreement

As a result of changes in the shareholding of our controlling company, a new Shareholders Agreement was signed on August 29, 2005. This agreement governs certain matters relating to shareholder participation in CIESA and in us. This agreement divides the CIESA shares into five classes that grant the shareholders different rights and places obligations with respect to us and CIESA, mainly regarding the designation of the members of our Board of Directors and our Supervisory Committee.

Under this agreement, Class A1 and B1 shares are owned by Petrobras Energía Group, Class A2 and B2 shares belong to the Trust and Class B3 shares are owned by EPCA.

Transfers of CIESA and Our Shares. The Shareholders Agreement provides certain rights of first refusal and “tag-along” or co-sale rights in favor of EPCA, in the event of a proposed transfer of CIESA shares. In particular, before any sale of shares to outside parties, the selling shareholder must offer to sell such shares to EPCA at the price agreed upon in a written purchase proposal from the outside party seeking to purchase such shares. In the event that EPCA does not choose to purchase the shares, it can opt to have a portion of its own shares (the allotted portion is dependent on the number of shares being sold) additionally included in the shares to be sold by the selling shareholder to the third party.

Under the Shareholders Agreement, the sale or transfer of any of our shares held by CIESA requires an affirmative vote of at least 60% of CIESA’s issued and outstanding common voting shares.

Election of Our Directors and Officers; Voting. The Shareholders Agreement also contains provisions governing the voting of shares held by CIESA, the election of the members of the Board of Directors and our Supervisory Committee, the appointment of certain officers and certain other matters.

Our Board of Directors consists of nine Directors (see “Item 6. Directors, Senior Management and Employees—A. Directors and Senior Management”). Under the Shareholders Agreement, the CIESA directors designated by each of the Class A1, Class A2, Class B1 and Class B3 shareholders shall cause CIESA to nominate directors, alternate directors and syndics pursuant to the instructions given by each of such class of shareholders. Thus, indirectly, the Class A1 shareholders (controlled by Petrobras Energía Group) nominate two regular directors, two alternate directors, one regular syndic and one alternate syndic, the Class A2 shareholders (controlled by the Trust) nominate two regular directors and two alternate directors, the Class B1 shareholders (controlled by Petrobras Energía Group) nominate one regular director, one alternate director, one regular syndic and one alternate syndic and the Class B3 shareholders (controlled by EPCA) nom inate one regular director, one alternate director, one regular syndic and one alternate syndic. The three remaining Independent Directors must be unanimously approved by all the shareholders of CIESA.

Under the terms of the Shareholders Agreement, but subject to their overriding duty to protect our corporate interest and the common interest of all of our shareholders, it is contemplated that the CIESA- nominated Directors shall vote unanimously in favor of the candidates nominated by the Class A1 shareholders for Chairman of the Board of Directors and CEO. The Vice-Chairman of our Board of Directors is nominated by the Class B3 shareholders.

Regarding the designation of our Supervisory Committee members, Petrobras Energía Group appoints two Syndics and the same number of Alternate Syndics. The position of Chairman of our Supervisory Committee is held by one of the two Syndics appointed by the Class A1 shareholders. The remaining Syndic and Alternate Syndic are appointed by the Class B3 shareholders.

Actions Requiring Special Shareholder Approval.The Shareholders Agreement states that a full majority vote of our Board of Directors (such majority must include the affirmative vote of the Class B3 shareholders) is required to approve the following decisions, among others: (i) the sale of our assets above a certain amount, outside of the day-to-day course of business; (ii) approval of our annual budget and material amendments thereto and certain related matters; (iii) commitments to incur, loans or operating expenses for an amount that exceeds by more than 10% the amount approved in our annual budget; (iv) capital expenditures which are individually in excess of US$500,000; (v) the setting of compensation of senior management; (vi) approval to make any claims of and any transactions related to, or negotiations of claims against us in excess of US$50,000; and (vii) the termination or extension of the Technical Assistance Agreement.

Future Changes in CIESA Shareholding.Once the approvals from ENARGAS and the Argentine Antitrust Authority (Comisión Nacional de Defensa de la Competencia) of the Restructuring Agreement (signed on September 7, 2005, among CIESA, its current shareholders and its creditors), are obtained, CIESA will cancel most of its defaulted debt through the transfer to its creditors of our Class “B” common shares representing approximately 4.3% of our common stock (which will be simultaneously exchanged for the 10% of CIESA’s outstanding shares currently held by EPCA), and the issuance of new CIESA’s shares in such a manner that the creditors of CIESA will hold 50% of the common stock, while the remaining 50% will be held by Petrobras.

The CIESA’s Shareholders Agreement will be terminated and replaced by a new Shareholders Agreement addressing the ownership change following consummation of the restructuring agreement. At no time will the Petrobras parties hold, directly or indirectly, more than their current 50% shareholding in CIESA or hold a controlling interest in CIESA.

The Settlement Agreement also provides that the Petrobras parties and their respective affiliates and the Enron parties and their respective affiliates will each grant the other releases from any and all claims under or arising from or in connection with certain agreements entered into by such parties in connection with their investment in CIESA and in us and certain other related documents. Such releases will not be given by, but will extend to, Transwestern Pipeline Company, a member of the Enron Economic Group (as defined in the Settlement Agreement).

In May 2004, the bankruptcy court having jurisdiction over the bankruptcy of Enron approved the Settlement Agreement. In addition, the transfers referred to above are subject to several conditions, one of which is the approval from ENARGAS.

Tender Offer Regime.According to Decree No. 677/01, issued by the Executive Branch, public companies will be included in the Tender Offer Regime, starting from the date of the shareholders’ meeting approving the company’s inclusion in the regime or automatically upon the first shareholders’ meeting held twelve months after the enforcement of the CNV resolution regulating the matter, issued in March 2003. The Decree also provides that if a public company is not willing to be included in such regime, it must incorporate an article to its By-laws stating the following: “Company not Subject to the Tender Offer Regime.” Such resolution must be adopted no later than in the shareholders’ meeting mentioned above. As our shareholders decided not to adhere to this regime, our shareholders approved an amendment to our By-laws to incorporate the exclusion expressly at the shareholder’s meeting held on April 2, 2004.

B.

Related Party Transactions

Our principal transaction with a related party is our export sales of LPG and natural gasoline to PIFCo made under the terms of two agreements described in Item 4—Our Information—B. Business Overview—NGL Production and Commercialization.

Under the Technical Assistance Agreement, Petrobras Energía renders services to us in its role of technical operator. The term of the Technical Assistance Agreement originally entered into with EPCA was for eight years from December 28, 1992, renewable automatically upon expiration for additional eight-year periods. The Settlement Agreement mentioned in “Item 4. Our Information—A. Our History and Development–General” includes a term which provided for the assignment of the Technical Assistance Agreement to Petrobras Energía. This transfer, which was approved by ENARGAS in June 2004, was carried out on July 15, 2004. As from that date, Petrobras Energía has been in charge of providing services related to, among others, the operation and maintenance of the gas transportation system and related facilities and equipment, to ensure that the performance of the system is in conformity with internation al standards and in compliance with certain environmental standards. For these services, we pay a monthly fee based on the higher of: (i) a percentage of certain of our defined income or (ii) a specified fixed annual amount.

Additionally, under each of our business segments, we render to Petrobras Energía the following services:

§

gas transportation service for a capacity of 106 MMcf/d under long term firm transportation capacity contracts which expire in 2013 and 2014,

§

midstream services (in Río Neuquén oilfield) through which we compress, dehydrate, store and dispatch natural gas. This contract was signed in 1999 and it finalizes in 2017;

§

under a long term agreement which expires in January 2011, we process natural gas and market NGL products on behalf of Petrobras Energía in our Cerri Complex. For this service, we collect a commission on the average monthly sale price obtained from our sales of its products in the domestic or international markets.

The details of significant outstanding balances for transactions with related parties as of December 31, 2007, 2006 and 2005 are as follows:

Year ended December 31, 2007

		Revenues
Company		Gas transportation	NGL production and commercialization	Other services	Gas purchases and other related costs	Petrol purchases	Compensation for technical assistance	Revenues for administrative services
Controlling shareholders:
EPCA		-	-	-	-	-	-	13
Petrobras Energía		28,500	25,562	16,741	7,130	1,561	34,747	-
CIESA		-	-	-	-	-	-	122
Affiliates with significant influence:
Link		-	-	995	-	-	-	-
TGU		-	-	207	-	-	-	-
Other related companies:
PIFCo(1)		-	476,551	-	-	-	-	-
Refinor S.A.		-	-	1,614	-	-	-	-
WEB S.A.		2,793	-	-	-	-	-	-
Área Santa Cruz II U.T.E.		-	-	3,079	-	-	-	-
Total		31,293	502,113	22,636	7,130	1,561	34,747	135
	(1) Includes NGL sales made on behalf of third parties, from which we withhold fees for production and commercialization.

Year ended December 31, 2006:

	Revenues
	Gas transportation	NGL production and commercialization	Other services	Gas purchases and other related costs	Petrol purchases	Compensation for  technical assistance	Revenues for administrative services
Controlling shareholders:
EPCA	-	-	-		-	-	80
CIESA	-	-	-		-	-	122
Petrobras Energía	26,635	28,411	27,273	7,849	1,279	42,631	-
Main affiliates-significant influence:
Link	-	-	947		-	-	-
TGU	-	-	307		-	-	-
EGS	-	-	49		-	-	-
Other related companies:
PIFCo(1)	-	530,312	-		-	-	-
Refinor S.A..	-	-	2,356		-	-	-
Quintana y Otros U.T.E.	1,820	-	-		-	-	-
WEB S.A.	3,044	-	-		-	-	-
Área Santa Cruz II U.T.E.	-	-	2,069		-	-	-
Total	31,499	558,723	33,001	7,849	1,279	42,631	202
(1) Includes NGL sales made on behalf of third parties, from which we withhold fees for production and commercialization.

Year ended December 31, 2005:

	Revenues
	Gas transportation	NGL production and commercialization	Other services	Gas purchases and other related costs	Salaries and wages	Compensation for technical assistance	Revenues for administrative services
Controlling shareholders:
EPCA	-	-	-	-	-	-	84
CIESA	-	-	-	-	-	-	122
Petrobras Energía	25,173	21,189	16,019	3,643	210	32,880	-
Main affiliates-significant influence:
Link	-	-	876	-	-	-	-
TGU	-	-	614	-	-	-	-
EGS	-	-	323	-	-	-	-
Other related companies:
PIFCo(1)	-	383,871	-	-	-	-	-
Petrolera Santa Fe S.A.	-	-	-	2,879	-	-	-
Refinor S.A..	-	-	2,157	-	-	-	-
Quintana y Otros U.T.E.	3,107	-	-	-	-	-	-
WEB S.A.	3,003	-	-	-	-	-	-
Área Santa Cruz II U.T.E.	-	-	1,472	-	-	-	-
Total	31,283	405,060	21,461	6,522	210	32,880	206
(1) Includes NGL sales made on behalf of third parties, from which we withhold fees for production and commercialization.

We do not have any outstanding loans to related parties.

C.

Interests of Experts and Counsel

Not applicable.

Item 8. Financial Information

A.

Consolidated Statements and Other Financial Information

Our Financial Statements, which are set forth in the Index to financial statements in Item 18, are filed as part of this Annual Report.

Exports

In 2007, our export revenues from NGL production and commercialization segment were Ps. 345.3 million and represented 27% of our total net revenues. Additionally, the total volume of sales from NGL was 899,148 short tons, and the volume of sales from NGL exports was 311,673 short tons. These volumes also include sales made on account of third parties.

In May 2004, the effective tax rate for LPG exports was increased from 4.76% to 16.67%. On May 24, 2007, it was increased to 20%.

Currently, a variable export tax regime is in force, with a minimum effective tax rate of 31.03% when LPG and natural gasoline international prices are lower than US$ 663 and US$ 920 per metric ton, respectively. See “Item 5. A. Operating results—Discussion of results of operations for the three years ended December 31, 2007, 2006 and 2005” for more information.

Legal and Regulatory Proceedings

a)

In February 2005, we were served notice by the CNV that certain notes that we issued in December 2004 in the amount of US$178 million did not fulfill the requirements of Article 56 of Chapter VI of the CNV Standards and CNV Resolution No. 470. If the CNV’s interpretation is upheld, those notes would not be entitled to the benefits of the exemption from income tax withholding provided by Law No. 23,576, and we, therefore, would be exposed to a contingency for the payment of withholding amounts associated with the income tax payable on interest paid in respect of those notes from their issue date in December 2004.  See “Item 5. Operating and Financial Revenue and Prospects — A. Operating Results — Factors affecting our consolidated results of operations — Net financial expense.”

On February 18, 2005, we filed an appeal with the CNV, alleging sufficient grounds to support the applicability of Article 56, Chapter VI of CNV Standards and Resolution No. 470/04. However, the CNV denied our appeal and on July 8, 2005, we filed an appeal with the Ministry of Economy and Production, which was rejected in November 2006. On December 6, 2006, we filed a second appeal with that Ministry seeking reconsideration of the rejection, which was rejected in June 2007. In November 2007, TGS challenged said resolution before the Federal Administrative Court.

The amount of such contingency is an uncertain amount of between US$6 million and US$17 million as of December 31, 2007 (including interests as of this date), depending on the applicable withholding tax rates determined on payments of interest by Argentine obligors, by the country of residence of the note holders at the date of each interest payment. We do not have available information that permits the identification of the country of residence of each note holder on each interest payment date.

We believe that we have sufficient legal grounds to defend our position that no withholding was required, and accordingly, we have not recorded any provision in respect of this proceeding.

b)

On November 30, 2007, we were served notice of the summary proceedings initiated against us by the BCRA. BCRA charged us with the late settlement of foreign currencies for an approximate amount of US$ 14.7 million. The transactions at issue were conducted between January 2002 and February 2003, a period in which the applicable exchange regulations were subject to frequent changes and the terms for the settlement of foreign currencies were shorter than the current ones.

On February 25, 2008, we filed a motion to dismiss before the BCRA requesting the dismissal of the summary proceedings on the grounds of lack of foreign exchange violation. We believe that we have several levels of appeal through which we may defend our position, and accordingly, we have not recorded any provision in respect of this proceeding. Based on the opinion of our legal advisors, the amount of the fine that may result from an eventual adverse sentence will not be greater than US$ 7.3 million.

c)

On February 1, 2008, we filed an arbitration claim against Bank of America in order to obtain the refund of US$ 9 million corresponding to the annulment made by Bank of America of the transfer of funds to our account that we had instructed the bank to execute on December 6, 2007, to redeem securities of the Columbia Strategic Cash Fund (Cash Fund arranged by the Bank of America). On such date, the Cash Fund entered into a liquidation process, and pledged to refund to the subscribers the proceeds of the settlement of its investments in the following months. From December 6, 2007 to the date of the issuance of this Annual Report the Cash Fund has reimbursed to TGS US$ 3.8 million, on account of the US$ 9 million. The arbitration is conducted under the provisions of the Federal Arbitration Act and the rules of the Judicial Arbitration and Mediation Services, Inc. in the United States of America.

Tax Claims

a)

Under the 1993 Tax Agreement between the Argentine national government and the Provinces and provincial Law No. 11,490, NGL sales were exempted from the turnover tax in the Province of Buenos Aires. In September 2003, the Tax Bureau of the Province of Buenos Aires, through Resolution No. 4,560/03, denied the exemption and claimed unpaid taxes on accrued NGL sales since 2002.

In October 2003, we filed an administrative appeal with the Tax Court of the Province of Buenos Aires. In February 2007, the Tax Court partially upheld our complaint. In its pronouncement, the Tax Court stated that ethane sales were within the scope of the turnover tax exemption but that LPG sales did not qualify for the exemption because they are not raw materials for an industrial process.

In May 2007, we appealed the unfavorable portion of this ruling in the Province of Buenos Aires Court alleging that LPG sales might be utilized for other uses different from petrochemical industry.  

In a separate proceeding related to the turnover tax in the Province of Buenos Aires, we received notice fromthe Tax Bureau of the Province of Buenos Aires in November 2004 that a tax assessment process had been initiated in connection with the turnover tax on NGL. On September 26, 2005, we were notified of the results of the tax assessment process for the period from January 2002 to July 2003, which amounted to Ps. 4.4 million plus interest. On October 18, 2005, we filed a motion to dismiss on our belief that the NGL sales activity was conducted under the tax exemption regime discussed above. On April 12, 2006 the motion to dismiss was rejected and therefore, we filed an appeal with the Tax Bureau of this province. In February 2008, the Tax Bureau of the Province of Buenos Aires notified TGS of another tax assessment process for the period from August 2003 to December 2004, whi ch amounted to Ps. 3.6 million plus interest. On March 11, 2008, we filed a motion to dismiss the new tax assessment before the Tax Bureau of the Province of Buenos Aires.

As of December 31, 2007, we recorded a provision of Ps. 15.9 million to cover potential losses relating to the claims of the Tax Bureau of the Province of Buenos Aires.

b)

In November 2002, the Tax Bureau of the Province of Santa Cruz sent us a formal assessment notice for the payment of a turnover tax calculated on the value of the natural gas used by us as fuel to render our transportation services. This assessment corresponds to the period from January 1998 to October 2002. In August 2005, we paid the amount claimed of Ps. 1.6 million (including interest to December 4, 2002) and started a tax recovery process, first exhausting all other procedural steps, with the Tax Bureau of the province and then initiating a proceeding in the provincial Tax Court.

In November 2005, we received a notice from the Tax Bureau of the Province of Río Negro, claiming payment of Ps. 0.2 million, on the same grounds as those of the Province of Santa Cruz, for the period from January 1999 to May 2005. On February 1, 2008, TGS initiated a tax recovery process with the Tax Court of the province of Río Negro to obtain the refund of Ps. 0.5 million paid in November 2007, after exhausting the same procedural steps followed in the case in the province of Santa Cruz.

Both the proceeding in the Province of Santa Cruz and the proceeding in the Province of Río Negro remain pending.

As of December 31, 2007, we have recorded a provision of Ps. 20.1 million in respect of this contingency under the line item “Provisions for contingencies” of our Financial Statements, which amount was determined in accordance with the estimations of tax and interest that would be payable as of such date.

Our management believes that, in case our position fails and the turnover tax has to be paid, we have a right to recover it by a transportation tariff increase as set forth in our License.

Other Litigation

As discussed above under “Item 4. Our Information—B. Business Overview—Gas Transportation—Regulatory Framework”, we are involved in the process of renegotiating our public service contracts with UNIREN.

In addition to the matters discussed above, we are a party to certain lawsuits and administrative proceedings arising in the ordinary course of business. Although no assurances can be given, we believe we have meritorious defenses, which we will assert vigorously to challenge all claims, and that possible liabilities from these claims will not have a material adverse effect on our consolidated financial position or results of operations.

Dividend Distribution Policy

Our dividend distribution policy consists of maintaining a dividend level that assures our credit quality and allows the partial reinvestment of earnings, considering growth projects that we may develop. See “Item 3. Key Information—A. Selected Financial Data—Dividends.”

B.

Significant Changes.

No undisclosed significant change has occurred since the date of our Financial Statements.

Item 9. The Offer and Listing

A.

Offer and Listing Details

The table below shows the high and low market prices of the Class B Shares on the BASE,stated in historical Argentine pesos and of the ADRs on the NYSE, stated in U.S. dollars, for each of the last five fiscal years.

	NYSE (in  US$)		BASE (in Ps.)
Years	High	Low	High	Low
2003	4.72	1.47	2.84	1.06
2004	5.72	3.61	3.34	2.13
2005	6.83	4.98	3.99	2.86
2006	7.99	4.44	4.20	2.74
2007	8.47	5.40	5.18	3.43

The table below shows the high and low market prices of the Class B Shares on the BASE, stated in historical Argentine pesos and of the ADRs in the NYSE, stated in U.S. dollars, for each full quarterly period within the two most recent fiscal years.

	2007				2006
	NYSE (in US$)		BASE (in Ps.)		NYSE (in US$)			BASE (in Ps.)
Quarters	High	Low	High	Low	High	Low	High		Low
First Quarter	7.40	6.18	4.57	3.80	5.99	4.81	3.60		2.97
Second Quarter	8.40	6.71	5.01	4.12	5.67	4.44	3.39		2.74
Third Quarter	8.47	5.74	5.18	3.57	5.50	4.91	3.40		2.97
Fourth Quarter	7.37	5.40	4.67	3.43	7.99	5.56	4.20		3.41

The table below shows the high and low market prices of the Class B Shares on the BASE, stated in historical Argentine pesos and of the ADRs in the NYSE, stated in U.S. dollars, for each full monthly period within the six most recent months.

	NYSE (in  US$)		BASE (in Ps.)
Months	High	Low	High	Low
December 2007	6.02	5.40	3.80	3.43
January 2008	5.98	4.95	3.65	3.17
February 2008	5.38	4.56	3.40	3.08
March 2008	4.76	4.05	3.08	2.80
April 2008	4.75	3.96	2.98	2.85
May 2008	4.80	3.90	3.08	2.56

B.

Plan of Distribution

Not Applicable.

C.

Markets

The Argentine Securities Market. In Argentina, the oldest and largest exchange is the BASE, founded in 1854. The BASE is the exchange on which the majority of equity trades in Argentina are executed. As of December 31, 2007, the market capitalization of shares of the 102 companies (excluding mutual funds) listed on the BASE was approximately Ps. 1,773,043 million. At the end of December 2007, the top 10 listed securities represented 95% of the total. Trading in securities listed on an exchange is conducted through the Mercado de Valores (“Stock Market”) affiliated with such exchange.

Securities may also be listed and traded through over-the-counter market brokers who are linked to an electronic reporting system. The activities of such brokers are controlled and regulated by the Mercado Abierto Electrónico S.A. (the “MAE”), an electronic over-the-counter market reporting system that functions independently from the Mercado de Valores de Buenos Aires S.A. (the “Buenos Aires Stock Market”) and the BASE. Under an agreement between the BASE and the MAE, trading in equity and equity-related securities is conducted exclusively on the BASE and trading in corporate debt securities is conducted on both the BASE and the MAE. Trading in Argentine government securities, which are not covered by the agreement, may be conducted on either or both of the BASE and the MAE. The agreement does not extend to other Argentine exchanges.

Changes to the legal framework of securities trading have been introduced, permitting issuance and trading of new, non-bank financial products in the Argentine capital markets, including commercial paper, new types of corporate bonds, futures and options. The Argentine government deregulated brokerage fees and eliminated transfer and stamp taxes on securities transactions in November 1991.

The Buenos Aires Stock Market. The Buenos Aires Stock Market, which is affiliated with the BASE, is the largest stock market in Argentina. The Buenos Aires Stock Market is a corporation whose 250 shares are owned by a number of members who are the only individuals and entities authorized to trade in the securities listed on the BASE. Trading on the BASE is conducted by open outcry and a computer-based negotiation system called SINAC from 11:00 A.M. to 5:00 P.M. each business day. The BASE also operates an electronic continuous market system from 11:00 A.M. to 5:00 P.M. each business day, on which privately-arranged trades are registered and made public. To control price volatility, the Buenos Aires Stock Market operates a system that restricts dealing in shares of any issuer when changes in the price of such issuer’s shares varies 15% from the previous closing price, unless trading at the top price.

Investors in the Argentine securities market are primarily individuals, companies and institutional investors consisting of a limited number of mutual funds. Certain information regarding the Argentine equities market is set forth in the table below.

	2003	2004	2005	2006	2007
Market capitalization (US$ in billions)	185.4	231.6	254.4	401.5	563.0
Average daily trading volume (US$ in millions)	11.6	17.9	25.5	20.0	28.5
Number of listed companies	108	107	106	107	109

Source: Data published by the Buenos Aires Stock Market.

D.

Selling Shareholders

Not applicable.

E.

Dilution

Not applicable.

F.

Expenses of the Issue

Not applicable.

Item 10. Additional Information

A.

Share Capital

Not applicable.

B.

Memorandum and Articles of Association

Information contained in Item 14 of our Registration Statement on Form F-1 (Registration No. 33-85178) is hereby incorporated by reference.

C.

Material Contracts

New Debt Obligations

On May 15, 2007, in connection with the refinancing of all of our debt incurred as part of the Restructuring, we issued a series of new notes in aggregate principal amount of US$500,000,000 (the “New Notes”). The issuance of the New Notes under our Medium Term Note Program, which provides for the issuance of up to a maximum principal amount of US$650 million in notes, was authorized by resolutions of an extraordinary meeting of shareholders dated December 21, 2006, and by resolutions of our Board of Directors adopted on January 4, 2007, March 30, 2007 and April 20, 2007.  

The scheduled maturity date of the New Notes is May 14, 2017.  The New Notes accrue interest at an annual fixed rate of 7.875%, payable semi-annually. Principal amortization payments are required commencing on May 14, 2014 with the following schedule: 25% on May 14, 2014, 25% on May 14, 2015, 25% on May 14, 2016 and 25% on May 14, 2017.  

The New Notes are redeemable, in whole but not in part, prior to maturity at our option any time after May 14, 2012 at a redemption price as set forth in the table below, together with accrued interest thereon and any additional amounts to the redemption date.

During the 12 Months Beginning	Applicable Percentage
On the 5th anniversary of the Issue Date	103.938%
On the 6th anniversary of the Issue Date	101.969%
On the 7th anniversary of the Issue Date	100.984%
On the 8th anniversary of the Issue Date and thereafter	100%

We are also permitted to redeem the New Notes in whole, but not in part, at a price equal to 100% of the principal amount outstanding if, as result of any change in, or amendment to, the laws or regulations of Argentina or any governmental authority thereof or therein having power to tax or as a result of any change in the application or official interpretation of such laws or regulations, we become obligated to pay additional amounts in respect of the New Notes and we cannot avoid such obligation by taking reasonable measures available to us.

In the event that the Republic of Argentina, directly or indirectly through any one or more controlled entities, comes to own shares representing more than 50% of the voting power of all of our shares, holders of New Notes are entitled to require us to purchase all or a portion the New Notes at price in cash equal to 101% of the principal amount of the New Notes so purchased. The New Notes are general, direct, unsecured and unsubordinated obligations and rank at all timespari passuin all respects, without any preference among themselves, with all of our other present and future unsecured and unsubordinated obligations, other than obligations preferred by statute or by operation of law.

Covenants

We are subject to several restrictive covenants under the terms of the New Notes, which include, among others, the following:

·

limitations on our ability to terminate our License or take any action that, in our reasonable opinion, would result in the termination of the License. We may not agree to amend or waive any terms of the License unless such amendment or waiver would not, in our reasonable opinion, adversely affect (i) our ability to meet our obligations under the New Notes on a timely basis or (ii) any material rights or interest of the trustee or the holders under the indenture or the New Notes;

·

a requirement that we not enter into or consent to any amendment, restatement or modification of the Technical Assistance Agreement or any successor agreement thereto, other than an amendment, restatement or modification that is not materially adverse to us and our subsidiaries, taken as a whole;

·

a limitation on our and our subsidiaries’ ability to create liens on our property, assets or revenues, other than certain permitted liens;

·

a limitation on our and our subsidiaries’ ability to incur additional indebtedness unless we meet certain financial ratios and no event of default exists, other than certain permitted indebtedness;

·

a limitation on our and our subsidiaries’ ability to pay dividends and make certain other restricted payments and investments with respect to any fiscal year or fiscal semester unless: (i) no event of default or potential event of default shall have occurred and be continuing and (ii) immediately after giving effect to such restricted payment, we would be able to incur at least US$1.00 of additional indebtedness pursuant to the limitation on indebtedness covenant;

·

limitations on our and our subsidiaries’ ability to enter into sale-leaseback transactions;

·

limitations on our and our subsidiaries’ ability to enter into a transaction with an affiliate, unless such transaction is on terms that are not materially less favorable to us or our subsidiary than we or such subsidiary would obtain in a comparable arm’s-length transaction with a non-affiliate;

·

a limitation on our and our subsidiaries’ ability to sell our assets; and

·

a limitation on our and our subsidiaries’ ability to enter into a merger, consolidation or similar transaction;

Events of Default

The New Notes contain the following events of default, among others:

·

default in the payment of principal, interest or any other amount due under the terms of the New Notes after a specified grace period;

·

breach of obligations contained in the New Notes after a specified cure period;

·

the occurrence of an event of default under our other debt obligations;

·

the occurrence of certain bankruptcy events or enforcement proceedings;

·

enforcement by any creditor of any mortgage, charge, pledge, lien or other encumbrance created or assumed by us or one of our subsidiaries exceeding US$10 million;

·

failure to obtain certain required governmental authorizations when required or if any such authorizations are rescinded, terminated, lapse or cease to be in full force and effect; and

·

the occurrence of certain material adverse events with respect to our License, such as the revocation, suspension for a period of greater than 120 days or termination of the License.

D.

Exchange Controls

Since the end of 2001 the Argentine government has imposed controls on the foreign exchange market and the movement of capital. During 2002, these controls were extensive, but since 2003 they have been progressively and considerably eased.

The most important provisions currently in force, that affect us, are mentioned below:

1.

there is an obligation to enter at least 30% of the funds received as payment for the export of NGL into the exchange market and to convert it into local currency within a time limit established by the Ministry of Economy and Production;

2.

Argentine individuals and companies are authorized to buy up to US$ 2,000,000 per month;

3.

principal and interest payments of financial obligations may be freely made, provided that the debt has been previously reported to the BCRA, negotiated in the local foreign exchange market and taken for a minimum term;

4.

companies may freely transfer dividends corresponding to audited financial statements without prior BCRA approval.

E.

Taxation

General

The following is a general summary of certain Argentine and United States federal income tax matters that may be relevant to the ownership and disposition of ADSs or Class B Shares. The summary describes the principal tax consequences of the ownership and disposition of ADSs or Class B Shares, but it does not purport to be a comprehensive description of all of the tax considerations that may be relevant to a holder of ADSs or Class B Shares.

The summary is based upon tax laws of Argentina and the United States and regulations thereunder as in effect on the date of this Annual Report, which are subject to change, possibly on a retroactive basis. In addition, the summary is based in part on representations of the Depositary and assumes that each obligation provided for in or otherwise contemplated by the Deposit Agreement or any other related document will be performed in accordance with its terms. Holders of ADSs or Class B Shares should consult their own tax advisors as to the United States, Argentine or other tax consequences of the acquisition, ownership and disposition of the ADSs or Class B Shares in their particular circumstances.

Argentine Taxes

Taxation of Dividends. Dividends of our cash, property or capital stock paid or distributed to holders of Class B Shares or ADSs are currently exempt from Argentine withholding or other taxes. However, according to Law No. 25,063, published on December 30, 1998, cash or other type of dividend distribution, exceeding accumulated net income at year end determined as stipulated by tax regulations, will be subject to a 35% withholding tax as a sole and definite payment.

Taxation of Capital Gains. Capital gains derived by non-Argentine residents from the sale, exchange or other disposition of ADSs or Class B Shares are not subject to income tax.

Tax on Personal Property (Individuals).The Argentine Tax authority has introduced some amendments to the Personal Property Tax. In accordance with the Law No. 25,585, the personal tax corresponding to the ownership of securities issued by entities domiciled in Argentina, whose direct owners are individuals domiciled in Argentina or abroad and entities domiciled abroad, will be liquidated and deposited by the entity that has issued such securities. The applicable rate is 0.50% on the equity value according to the last financial statements as of each respective fiscal year. The Law presumes that securities whose holders are entities domiciled or located abroad indirectly belong to individuals domiciled abroad.

We are responsible for depositing such tax and have the right to recover such amount from holders, even withholding and/or liquidating the securities which caused such tax payment. This Amendment was effective starting fiscal year 2002.

VAT. The sale, exchange or other disposition of ADSs or Class B Shares is not subject to VAT.

Transfer Taxes.The sale, exchange or other disposition of ADSs or Class B Shares is not subject to transfer taxes.

Purchase or Sale of Foreign Currency. There is no tax on the purchase or sale of foreign currency.

Deposit and Withdrawal of Class B Shares in Exchange of ADSs. No Argentine tax is imposed on the deposit or withdrawal of Class B Shares in exchange for ADSs.

Other Taxes. There are no Argentine inheritance or succession taxes applicable to the ownership, transfer or disposition of ADSs or Class B Shares. There are no Argentine stamp, issue, registration or similar taxes or duties payable by holders of ADSs or Class B shares.

Tax Treaties. Argentina has entered into tax treaties with several countries. A tax treaty between Argentina and the United States has been signed but has not yet been ratified and therefore is not currently in effect. It is not clear when, if ever, the treaty will be ratified or will enter into effect.

United States Taxes

General. This discussion relating to certain US federal income tax consequences applies only to an investor who holds our ADSs or Class B Shares as capital assets for tax purposes and is not a member of a special class of holders subject to special rules, including: a dealer in securities; a trader in securities that elects to use a mark-to-market method of accounting for his or her securities holdings; a tax-exempt organization; an insurance company, a person liable for alternative minimum tax; a person that actually or constructively owns 10% or more of our voting stock; a person that holds shares or ADSs as part of a hedging or straddle or conversion transaction; or a US holder whose functional currency is not the U.S. dollar. A holder is a US holder if such holder is a beneficial owner of shares or ADSs and such holder is: a citizen or resident of the United States; a domestic corporation; an estate whose incom e is subject to US federal income tax regardless of its source; or a trust, if a US court can exercise primary supervision over the trust’s administration and one or more US persons are authorized to control all substantial decisions of the trust.

Moreover, the effect of any applicable US state or local tax laws is not discussed in this Annual Report.

In general, and taking into account the earlier assumptions, for US federal income tax purposes, a holder of ADRs evidencing ADSs will be treated as the owner of the underlying shares represented by those ADSs, and exchanges of Class B Shares for ADRs, and ADRs for Class B shares, will not be subject to US federal income tax.

Taxation of Dividends. Subject to the passive foreign investment company (“PFIC”) rules discussed below, if a holder is a US holder such holder must include in his or her gross income the gross amount of any dividend (or other distribution, other than certain distributions in redemption of ADSs or Class B shares or distributions of our capital stock or rights to subscribe for our capital stock) paid by us out of our current or accumulated earnings and profits (as determined for US federal income tax purposes). If the holder is a non-corporate US holder, dividends paid to him or her in taxable years beginning before January 1, 2011 that constitute qualified dividend income will be taxable at a maximum tax rate of 15% provided that the shares or ADSs are held for more than 60 days during the 121-day period beginning 60 days before the ex-dividend date and certain other holding period requirements are met. Dividends with respect to the shares or ADSs generally will be qualified dividend income, provided that in the year that the holder receives the dividend, the shares or ADSs are readily tradable on an established securities market in the US. The holder must include the gross amount of dividends in income when he or she receives them, either actually or constructively, in the case of Class B Shares, or when the depositary receives such dividend, in the case of ADSs. The dividend will not be eligible for the dividends-received deduction generally allowed to US corporations in respect of dividends received from other US corporations.  Distributions in excess of current and accumulated earnings and profits, as determined for US federal income tax purposes, will be treated as a non-taxable return of capital to the extent of a holder’s basis in the ADSs or Class B Shares and thereafter as capital gain.

The amount of the dividend distribution that a holder must include in his or her income will be the U.S. dollar value of the Argentine peso payments made, determined at the spot Argentine peso/U.S. dollar rate on the date such dividend distribution is includible in such holder’s income, regardless of whether the payment is in fact converted into U.S. dollars. Generally, any gain or loss resulting from currency exchange fluctuations during the period from the date a holder includes the dividend payment in income to the date such payment is converted into U.S. dollars will be treated as ordinary income or loss and will not be eligible for the special tax rate applicable to qualified dividend income. Such gain or loss will generally be income or loss from sources within the United States for foreign tax credit limitation purposes.

For foreign tax credit purposes, the dividend will be income from sources outside the United States. Dividends paid in taxable years beginning before January 1, 2007 generally will be “passive income” or “financial services income” and dividends paid in taxable years beginning after December 31, 2006 will, depending on your circumstances, be “passive” or “general” income, which, in either case, is treated separately from other types of income for purposes of computing the foreign tax credit allowable to a holder. No US foreign tax credit will be allowed to US holders of Class B Shares or ADSs in respect of any personal property or similar tax imposed by Argentina (or any taxing authority thereof or therein). Special rules apply in determining the foreign tax credit limitation with respect to dividends that are subject to the maximum 15% tax rate.

Distributions of additional shares to US holders with respect to their Class B Shares or ADSs that are made as part of a pro rata distribution to all shareholders generally will not be subject to US federal income tax.

Taxation of Capital Gains. Subject to the PFIC rules discussed below, a US holder that sells or otherwise disposes of Class B Shares or ADSs will recognize gain or loss for US federal income tax purposes in an amount equal to the difference between the U.S. dollar value of the amount realized and his or her tax basis (determined in U.S. dollars) in such shares or ADSs. Capital gain of a non-corporate US holder that is recognized in taxable years beginning before January 1, 2011 is generally taxed at a maximum rate of 15% where the holder has a holding period greater than one year. The gain or loss will generally be income or loss from sources within the US for foreign tax credit limitation purposes.

PFIC Rules. We believe the Class B Shares or ADSs should not be treated as stock of a PFIC for United States federal income tax purposes, but this conclusion is a factual determination that is made annually and thus may be subject to change. The application of the PFIC rules to a corporation such as ours, a substantial portion of whose business is the processing and selling of NGL, is not entirely clear. If we were to be treated as a PFIC, unless a US holder elects to be taxed annually on a mark-to-market basis with respect to the Class B Shares or ADSs, gain realized on the sale or other disposition of the shares or ADSs would in general not be treated as capital gain.  Instead, the US holder would be treated as if he had realized such gain and certain “excess distributions” ratably over the holding period for the shares or ADSs and would be taxed at the highest tax rate in effect for each such year to which the gain was allocated, together with an interest charge in respect of the tax attributable to each such year. In addition, dividends received from us will not be eligible for the special tax rates applicable to qualified dividend income if we are a PFIC either in the taxable year of the distribution or the preceding taxable year, but instead will be taxable at rates applicable to ordinary income.

F.

Dividends and Paying Agents.

Not applicable.

G.

Statement by Experts.

Not applicable.

H.

Documents on Display

We are subject to the informational requirements of the CNV and the BASE and file reports and other information relating to our business, financial condition and other matters with the CNV and the BASE. You may read such reports, statements and other information, including our publicly-filed financial statements, at the public reference facilities of the CNV and BASE maintained in Buenos Aires. We are also required to file annual and special reports and other information with the SEC. You may read and copy any documents filed by us at the SEC’s public reference room at 100 F Street, N.E., Room 1580, Washington, D.C. 20549. Please call the SEC at 1-800-SEC-0330 for further information on the public reference room. Our filings with the SEC will also be available to the public at the offices of the NYSE, 11 Wall Street, New York, New York 10005.

We have appointed The Bank of New York to act as depositary for our ADRs. For so long as our ADRs are deposited with the depositary, we will furnish the depositary with our annual reports;andsummaries of all notices of general meetings of shareholders and other reports and communications that are made generally available to our shareholders.

The depositary will, as provided in the deposit agreement, arrange for the mailing of summaries in English of such reports and communications to all record holders of our ADRs. Any record holder of ADRs may read such reports, notices, or summaries thereof, and communications at the depositary’s office. The depositary’s office is located at 111 Wall Street, New York, NY 10043.

Whenever a reference is made in this Annual Report to a contract or other document of ours, please be aware that such reference is not necessarily complete and that you should refer to the exhibits that are a part of the Annual Report for a copy of the contract or other document. You may review a copy of the Annual Report at the SEC’s public reference room in Washington, D.C.

I.

Subsidiary Information

Not applicable.

Item 11.

 Quantitative and Qualitative Disclosures About Market Risk

Market risk represents the risk of loss that may impact our consolidated financial position, results of operations or cash flows due to adverse changes in financial market prices and interest rates. We are exposed to market risk in the areas of interest rates and foreign currency exchange. This discussion contains forward-looking statements that are subject to risks and uncertainties. Actual results could vary materially as a result of a number of factors. Uncertainties that are either non-financial and non-quantifiable, such as political, economic, tax, other regulatory or credit risks, are not included in the following assessment of our market risks.

Interest Rate Risk

Our exposure to market risk associated with changes in interest rates is limited to our current investments.

We place our cash and current investments in high quality financial institutions in Argentina, the United States and Europe. Our policy is to limit exposure with any one institution. Our temporary investments primarily consist of money market mutual funds, fixed-term deposits and commercial papers in foreign currency. As of December 31, 2007, current investments amounted to Ps. 421.1 million.

With regard to our debt obligations, as a general matter, we are not exposed to interest rate risk because all of our debt bears interest at a fixed rate.

Foreign exchange exposure

Our primary market risk exposure is associated with changes in the foreign currency exchange rates since our debt is denominated in U.S. dollars. As of December 31, 2007, our net monetary liability position that is subject to exchange rate fluctuations amounted to US$ 367.6 million.

As discussed herein, the Argentine government has adopted various economic measures, including the repeal of the Convertibility Law and the pesification of our gas transportation revenues. Therefore, our results of operations are very susceptible to changes in the peso/U.S. dollar exchange rate because approximately half of our revenues are denominated in pesos while substantially all our liabilities are denominated in U.S. dollars.

Sensitivity analysis disclosure to interest rates and exchange rates

In view of the nature of our current investments, an immediate 100 basis points parallel shift change in the interest rate curve would not have a significant impact on the total value of our current investments.

The potential loss in our net monetary liability position held as of December 31, 2007, that would have resulted from a hypothetical, instantaneous and unfavorable 10% change in the current peso/U.S. dollar exchange rates would have been approximately Ps. 115.7 million.

Our New Debt Obligations accrue interest at a fixed rate. Therefore, we do not currently have an exposure to changes in interest rates. The following table provides information presented in our reporting currency, Argentine pesos, with respect to our foreign exchange exposure. For debt obligations, the table presents principal cash flows and interest rate by expected maturity dates.

	Expected maturity dates(4)
	2008	2009	2010		2011	2012	Thereafter		Total	Fair value(2)
	(in millions of pesos)(1)
U.S. dollars
Fixed rate	127.1	125.7		125.7	125.7	126.1		1,951.3	2,581.6	1,369.8
Interest rate(3)	7.875%	7.875%		7.875%	7.875%	7.875%		7.875%	-	-

⁽¹⁾  Converted at theexchange rate as of December 31, 2007: Ps. 3.149 = US$1.00.

⁽²⁾ Based on the quoted market prices of our new notes.

⁽³⁾  Interest rate based on the prices settled in the contract as of December 31, 2007.

⁽⁴⁾ For a more detailed description, see “Item 10. Additional Information – C. Material contracts – New Debt Obligations” included elsewhere herein.

See “Item 5. Operating and Financial Review and Prospects—B. Liquidity and Capital Resources—Currency and Exchange Rates” and “Item 5. Operating and Financial Review and Prospects—B. Liquidity and Capital Resources—Derivative Financial Instruments” for more information.

Commodity price risk

In the NGL production and commercialization segment we are exposed to market risk in relation to price volatility of the LPG and natural gasoline since they are subject to international prices (Mont Belvieu for the LPG and NWE Ara for the natural gasoline). Their prices have fluctuated in response to changing market forces. Based on our volume sales of 2007, a US$ 50 per ton change in the weighted-average sale prices of LPG and natural gasoline would have approximately a Ps. 16 million annual net income effect, if international reference prices of LPG and natural gasoline are lower than US$ 666 and US$ 954, respectively. If they are higher, there would be no effect as the variable export tax regime neutralize any change in the prices of such products. See “Item 8. Financial Information—A. Consolidated Statements and Other Financial Information—Exports” for more information.

For any given period, the NGL sales will be dependent on the international price of LPG and natural gasoline, taxes and other government take impacts and production volumes. Accordingly, changes in international prices for the mentioned products only provide a broad indicator of changes in the net income of any fiscal year.

For more information see “Item 3. Key Information—D. Risk Factors—Risks Relating to Our Business—Increases in export taxes on, a decrease in international prices or other regulation of NGL may materially adversely affect our results of operations and financial condition.”

Item 12.

Description of Securities Other Than Equity Securities

Not applicable.

13

Part II

Item 13.

Defaults, Dividend Arrearages and Delinquencies

No events required to be reported have occurred.

Item 14.

Material Modifications to the Rights of Security Holders and Use of Proceeds

None.

Item 15.

Controls and Procedures.

A. Disclosure controls and procedures

Our CEO and CFO, after evaluating the effectiveness of our disclosure controls and procedures (as defined in the Exchange Act under Rule 13a-15(e)) as of December 31, 2007, have concluded that, as of December 31, 2007, our disclosure controls and procedures were effective to ensure that information required to be disclosed in the reports we submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC.

B. Management’s annual report on internal control over financial reporting

Our management, including our CEO and CFO, is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act. Our internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with applicable generally accepted accounting principles.

Management assessed the effectiveness of its internal control over financial reporting as of December 31, 2007.  In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”). Based on this assessment, management concluded that, as of the end of fiscal year 2007, its internal control over the financial reporting was effective.

C. Attestation Report of the Registered Public Accounting Firm

The effectiveness of our internal control over financial reporting as of December 31, 2007 has been audited by KPMG, an independent registered public accounting firm, as stated in their report which appears on page F-1 herein.

D. Changes in Internal Control Over Financial Reporting

There have not been any changes in our internal control over financial reporting during 2007 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Item 16A.

Audit Committee Financial Expert

We have at least one audit committee financial expert serving on our audit committee. Our Board of Directors has identified Mr. Oscar Marano as an audit committee financial expert. Mr. Marano is an independent director.

Item 16B.

Code of Ethics

We have adopted a Code of Conduct, applicable to all employees including our principal executive and financial officers. Our code of conduct is available both on our web site at http://www.tgs.com.ar and as an Exhibit to this Annual Report. For more information see, “Item 6. Directors, Senior Management and Employees-C. Board Practices- Corporate Governance Practices; New York Stock Exchange Requirements”.

Item 16C.

Principal Accountant Fees and Services

Audit and Non-Audit Fees

Fees billed for professional services provided to us by Price (our former independent registered public accounting firm) and KPMG during the years ended December 31, 2007 and 2006 in each of the following categories are:

	Year ended December 31,
	2007	2006
	(in thousands of pesos)
Audit fees	1,095.0	966.3
Audit-related fees	611.3	21.6
Tax fees	-	15.0
All other fees	-	-
Total fees	1,706.3	1,002.9

Audit fees. Audit fees in the above table are mainly for the audit of our annual financial statements and the review of our quarterly reports, syndics of subsidiaries and Form 20-F.

Audit-related fees. Audit-related fees in the above table are mainly for services related to the review of the information memorandum for the restructuring proposal finalized in June 2007.

Tax fees. Tax fees in the above table are fees mainly for tax compliance and tax advice.

Audit Committee Pre-Approval Policies and Procedures

Consistent with SEC requirements regarding auditor independence, the Audit Committee has adopted a policy of pre-approving services prior to commencement of the specified service. Under the policy, the Audit Committee must pre-approve the provision of services by our principal auditor prior to commencement of the specified service. The requests for pre-approval are submitted to the Audit Committee by our CFO, or a designate, and the Audit Committee Chairman executes engagement letters from the principal auditor following approval by committee members.

All audit-related fees, other fees and tax fees are submitted to our audit committee for prior approval. The Audit Committee has delivered its policy to the Board of Directors that sets forth its procedures for evaluating, in each case, the scope of the work to be performed by our accountants and the fees for such work prior to their engagement.

Consequently, 100% of the fees rendered by our principal accountants in 2007 were approved by the Audit Committee prior to their engagement to perform such work.

Item 16D. Exemptions from the Listing Standards for Audit Committees

Not applicable.

Item 16E. Purchases of Registered Equity Securities of the Issuer by the Issuer and Affiliated Purchasers

Not applicable.

14

Part III

Item 17.

Financial Statements

The registrant has responded to Item 18 in lieu of responding to this Item.

Item 18.

Financial Statements

The following financial statements are filed as part of this Form 20-F:

Transportadora de Gas del Sur S.A.--

	Page
Report of independent registered public accounting firm	F-1
Consolidated Statements of Income for the years ended December 31, 2007, 2006 and 2005	F-2
Consolidated Balance Sheets as of December 31, 2007 and 2006	F-3
Consolidated Statements of Cash Flows for the years ended December 31, 2007, 2006 and 2005	F-4
Statements of Changes in Shareholders’ Equity for the years ended December 31, 2007, 2006 and 2005	F-5
Notes to Consolidated Financial Statements for the years ended December 31, 2007, 2006 and 2005	F-6

Reference is made to pages F-1 through F-53.

Item 19. Exhibits

See Exhibit Index

15

SIGNATURE

Pursuant to the requirements of Section 12 of the Securities Exchange Act of 1934, the Registrant hereby certifies that it meets all of the requirements for filing this Annual Report on Form 20-F and that it has duly caused and authorized the undersigned to sign this Annual Report on its behalf.

TRANSPORTADORA DE GAS DEL SUR S.A. (Registrant) By:
		/s/ Jorge Casagrande
	Name:		Jorge Casagrande
	Title:		Chief Executive Officer

	/s/ Gonzalo Castro Olivera
Name:		Gonzalo Castro Olivera
Title:		Chief Financial Officer

Dated: June 12, 2008

16

EXHIBIT INDEX

ExhibitNo.

1.1

Corporate Charter and By-laws.*

1.2

By-laws Amendments. **

2.1

Indenture dated as of May 14, 2007, among TGS, Law Debenture Trust Company of New York, as trustee, co-registrar, principal paying agent and transfer agent, and Banco Santander Río S.A., as registrar, paying agent and transfer agent, in respect of TGS’s 7.875% Notes Due 2017. *******

2.2

Officers’ Certificate establishing the terms of TGS’ 7.875% Notes Due 2017. *******

3.1

CIESA Shareholders’ Agreement. ******

4.1

Technical Assistance Agreement between TGS and EPCA dated December 28, 1992****

4.2

Ethane supply agreement between TGS and PBB Polisur S.A. ******

4.3

LPG supply agreement between TGS and PIFCo. *******

4.4

Natural gasoline supply agreement between TGS and PIFCo. *******

8.1

List of TGS’s Subsidiaries

11.1

Code of Conduct ******

12.1

Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

12.2

Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

13.1

Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

13.2

Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

15.1

Audit Committee Charter. *****

1

* Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year-ended December 31, 2001 (Commission File No. 1-13396).

** Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year-ended December 31, 2004 (Commission File No. 1-13396).

**** Incorporated by reference to our Registration Statement on Form F-1 filed with the Securities and Exchange Commission on October 14, 1994 (Registration No. 33-85178).

***** Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year-ended December 31, 2003 (Commission File No. 1-13396).

****** Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year-ended December 31, 2005 (Commission File No. 1-13396).

******* Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year-ended December 31, 2006 (Commission File No. 1-13396).

EXHIBIT 8.1

SUBSIDIARIES

The following are our subsidiaries:

Company Name	Country of incorporation	Proportion of Ownership Interest
Telcosur	Argentina	99.98 %

1

EXHIBIT 12.1

CERTIFICATION

I, Jorge Casagrande, certify that:

1.

I have reviewed this annual report on Form 20-F of Transportadora de Gas del Sur S.A.;

2.

Based on my knowledge, this annual 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 annual report;

3.

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

4.

The Company’s other certifying officers 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 Company and have:

a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the Company, 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 company’s internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the company’s internal control over financial reporting; and

5.

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

a)

All significant deficiencies and material weaknesses in the design or operation of internal controls over financial reporting which are reasonably likely to adversely affect the Company’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 Company’s internal control over financial reporting.

Date: June 12, 2008

/s/ Jorge Casagrande

Jorge Casagrande

Chief Executive Officer

1

EXHIBIT 12.2

CERTIFICATION

I, Gonzalo Castro Olivera, certify that:

1.

I have reviewed this annual report on Form 20-F of Transportadora de Gas del Sur S.A.;

2.

Based on my knowledge, this annual 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 annual report;

3.

Based on my knowledge, the financial statements, and other financial information included in this annual 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 annual report;

4.

The registrant’s other certifying officers 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 Company and have:

a)

Designed such disclosure controls and procedures 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 company’s internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the company’s internal control over financial reporting; and

5.

The registrant’s other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of registrant’s Board of Directors (or persons performing the equivalent function):

a)

All significant deficiencies and material weaknesses in the design or operation of internal controls 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.

Date: June 12, 2008

/s/ Gonzalo Castro Olivera

Gonzalo Castro Olivera

Chief Financial Officer

1

EXHIBIT 13.1

CERTIFICATION

Pursuant to section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of section 1350, chapter 63 of title 18, United States Code), the undersigned officer of Transportadora de Gas del Sur S.A. (“the Company”), herby certifies, to such officer’s knowledge, that:

The Annual Report on Form 20-F for the year ended December 31, 2007 (the “Report”) of the Company fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 and all information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: June 12, 2008

/s/ Jorge Casagrande

Jorge Casagrande

Chief Executive Officer

1

EXHIBIT 13.2

CERTIFICATION

Pursuant to section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of section 1350, chapter 63 of title 18, United States Code), the undersigned officer of Transportadora de Gas del Sur S.A. (“the Company”), herby certifies, to such officer’s knowledge, that:

The Annual Report on Form 20-F for the year ended December 31, 2007 (the “Report”) of the Company fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 and all information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: June 12, 2008

/s/ Gonzalo Castro Olivera

Gonzalo Castro Olivera

Chief Financial Officer

1

Report of Independent Registered Public Accounting Firm

The Board of Directors and Shareholders

Transportadora de Gas del Sur S.A.:

1

We have audited Transportadora de Gas del Sur S.A.’s internal control over financial reporting as of December 31, 2007, based on the criteria established in “Internal Control – Integrated Framework” issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The management of Transportadora de Gas del Sur S.A. is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting. Our responsibility is to express an opinion on the effectiveness of the Company’s internal control over financial reporting based on our audit.

2

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

3

A company’s internal control over financial reporting is a process designed 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. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) prov ide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

4

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

5

In our opinion, Transportadora de Gas del Sur S.A. maintained, in all material respects, effective internal control over financial reporting as of December 31, 2007, based on  the criteria established in “Internal Control – Integrated Framework” issued by the COSO.

F-1

6

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of Transportadora de Gas del Sur S.A. and its subsidiary as of December 31, 2007, and the related consolidated statements of operations, changes in shareholders’ equity and and cash flows for the year ended December 31, 2007, and our report dated June 12, 2008 expressed an unqualified opinion on those consolidated financial statements.

Buenos Aires, Argentina

June 12, 2008

SIBILLE

(Member firm of KPMG International)

Jorge E. Dietl

Partner

F-2

Report of Independent Registered Public Accounting Firm

The Board of Directors and Shareholders

Transportadora de Gas del Sur S.A.:

1

We have audited the accompanying consolidated balance sheet of Transportadora de Gas del Sur S.A. and its subsidiary as of December 31, 2007 and the related consolidated statements of income, changes in shareholders’ equity and cash flows for the year then ended.  These consolidated financial statements are the responsibility of the Company’s management.  Our responsibility is to express an opinion on these consolidated financial statements based on our audit.

2

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States).  Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement.  An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements.  An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation.  We believe that our audit provides a reasonable basis for our opinion.

3

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Transportadora de Gas del Sur S.A. and its subsidiary as of December 31, 2007, and the results of their operations and their cash flows for the year then ended, in conformity with accounting principles generally accepted in Argentina, as approved by the Professional Council of Economic Sciences of the City of Buenos Aires.

4

Accounting principles generally accepted in Argentina, as approved by the Professional Council of Economic Sciences of the City of Buenos Aires vary in certain significant respects from accounting principles generally accepted in the United States. Information relating to the nature and effect of such differences is presented in Note 12 to the consolidated financial statements.

5

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the effectiveness of Transportadora de Gas del Sur S.A.’s internal control over financial reporting as of December 31, 2007, based on the criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated June 12, 2008 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.

Buenos Aires, Argentina

June 12, 2008

SIBILLE

(Member firm of KPMG International)

Jorge E. Dietl

Partner

F-3

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of  

Transportadora de Gas del Sur S.A.

We have audited the accompanying consolidated balance sheets of Transportadora de Gas del Sur S.A. and its subsidiary as of December 31, 2006 and 2005, and the related consolidated statements of income, of changes in shareholders’ equity and of cash flows  for each of the three years in the period ended December 31, 2006. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits of these financial statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Transportadora de Gas del Sur S.A. and its subsidiary at December 31, 2006 and 2005, and the results of their operations and their  cash flows for each of the three years in the period ended December 31, 2006 in  conformity with accounting principles generally accepted in Argentina.

Accounting principles generally accepted in Argentina vary in certain significant respects from the accounting principles generally accepted in the United States of America and as allowed by Item 18 to Form 20-F, information relating to the nature and effect of such differences is presented in Note 12 to the consolidated financial statements.

PRICE WATERHOUSE & CO. S.R.L.

Rubén O. Vega (Partner)

City of Buenos Aires, Argentina

February 5, 2007 (except with respect to the matters discussed in

Note 12 to the consolidated financial statements, which is as of April 17, 2007)

F-4

F-5

F-6

F-8

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

1.

BUSINESS DESCRIPTION

Transportadora de Gas del Sur S.A. (“the Company” or “TGS”) is one of the companies created as a result of the privatization of Gas del Estado S.E. (“GdE”). The Company commenced operations on December 29, 1992 and it is engaged in the transportation of natural gas and production and commercialization of natural gas liquids (“NGL”). TGS’s pipeline system connects major gas fields in southern and western Argentina with gas distributors and industries in those areas and in the greater Buenos Aires area. The gas transportation license to operate this system for a period of thirty-five years (“the License”) was exclusively granted to the Company. TGS is entitled to a one-time extension of ten years provided that it has essentially met the obligations imposed by the License and by the Ente Nacional Regulador del Gas (National Gas Regulatory Agency or “ENARGAS”). The General Cerri Gas Processi ng Complex (the “Cerri Complex”), where the Company processes natural gas by extracting NGL, was transferred from GdE along with the gas transmission assets. The Company also renders midstream services, which mainly consist of gas treatment, removal of impurities from the natural gas stream, gas compression, wellhead gas gathering and pipeline construction, operation, and maintenance services.

2.

BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

The Company’s consolidated financial statements have been prepared in accordance with generally accepted accounting principles in Argentina (“Argentine GAAP”) as approved by Professional Council in Economic Sciences of the Autonomous City of Buenos Aires (“CPCECABA”), and the regulations of theComisión Nacional de Valores (the Argentine National Securities Commission or “CNV”) and ENARGAS. Argentine GAAP differs in certain significant respects from generally accepted accounting principles in the United States of America ("US GAAP"). Such differences involve methods of measuring the amounts shown in the financial statements, as well as additional disclosures required by US GAAP and Regulation S-X of the Securities and Exchange Commission (“SEC”). A description of the significant differences between Argentine GAAP and US GAAP as they relate to the Company is set forth in Note 12 to these consolidated financial statements.

In accordance with Argentine GAAP, the presentation of the parent company’s individual financial statements is mandatory. Consolidated financial statements are to be included as supplementary information to the individual financial statements. For the purpose of these financial statements, individual financial statements have been omitted since they are not required for SEC reporting purposes.

The consolidated financial statements include the accounts of TGS and its subsidiary Telcosur S.A. (“Telcosur”) over which it has effective control. Investments in companies, in which the Company exercises significant influence, but not control, are accounted for under the equity method. The Company followed the methodology established in Technical Resolution (“TR”) No. 21 “Equity Method of Accounting, Consolidation of Financial Statements and Related Party Transactions” of the Argentine Federation of Professional Councils in Economic Sciences (“Argentine Federation”) and approved by the CPCECABA. The accounting policies followed by Telcosur in the preparation of its financial information are consistent with those applied by TGS. All significant intercompany transactions have been eliminated in consolidation.

Detailed data reflecting subsidiary direct control as of December 31, 2007, 2006 and 2005 is as follows:

Company	% of shareholding and votes			Closing date		Legal address
	2007	2006	2005
TELCOSUR S.A.	99.98%	99.98%	99.98%	December 31,	Don Bosco 3672, 6th Floor Autonomous City of Buenos Aires

Certain reclassifications of prior year information have been made to conform to the current year presentation.

F-9

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

a)

Use of estimates

The preparation of the consolidated financial statements in conformity with generally accepted accounting principles requires management to make accounting estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements, as well as the reported amounts of revenues and expenses during the reporting fiscal year. Estimates are used when accounting for the allowance for doubtful accounts, depreciation, amortization, income taxes, allowance for contingencies, impairment of long-lived assets, and present value of long term receivables and liabilities. Actual results could be significantly different from such estimates.

b)

Presentation of consolidated financial statements in constant Argentine pesos

The consolidated financial statements have been prepared in constant Argentine pesos, recognizing the overall effects of inflation up to August 31, 1995. As from that date, in line with professional accounting standards and the requirements of the control authorities, the Company discontinued the restatement of its consolidated financial statements until December 31, 2001.

As established by Resolution No. 3/2002 of the CPCECABA and Resolution No. 415 of the CNV, as from January 1, 2002, the Company resumed the recognition of the effects of inflation in these consolidated financial statements, following the provisions of TR No. 6, as amended by TR No. 19, both issued by the Argentine Federation.  Accounting measurements restated due to the change in the purchasing power of the currency up to August 31, 1995, as well as those which have been originated between that date and December 31, 2001, are stated in the currency value as of the later date.

On March 25, 2003, the Executive Branch issued Decree No. 664, which provides that financial statements for periods ending after such date shall be stated in historical Argentine pesos. As a consequence and in accordance with Resolution No. 441, issued by the CNV, the Company suspended inflation accounting effective March 1, 2003. This criterion is not in line with Argentine GAAP, which stipulate that financial statements should be restated as of September 30, 2003. If the Company had applied inflation accounting for the period from March 1 to September 30, 2003, the non-recognized inflation effect on net income and shareholders´equity for the fiscal years ended December 31, 2007, 2006 and 2005 would not be significant.

The restatement methodology is computed at each balance sheet date, using the Argentine Wholesale Price Index (“WPI”) published by theInstituto Nacional de Estadística y Censos (“INDEC”), as follows:

-

Non-monetary items and consolidated statement of income amounts are adjusted to reflect the then-current general purchasing power;

-

Monetary items are not adjusted as such items are, by their nature, stated in terms of current general purchasing power in the financial statements; and

-

Monetary gains or losses are recognized in the consolidated statement of income, reflecting the effect of holding monetary items. This gain or loss on exposure to inflation (monetary gain or loss) is included in the consolidated statement of income within “Net financial expense”.

Information presented for comparative purposes has been restated in constant currency as of February 28, 2003.

c)

Adoption by CNV of accounting standards

The CNV issued General Resolutions No. 485 and No. 487 on December 29, 2005 and January 26, 2006, respectively, which adopted, with certain modifications, the new accounting standards previously issued by the CPCECABA through its Resolution CD 93/2005. These standards were mandatory for fiscal years or interim periods corresponding to fiscal years beginning as from January 1, 2006.

The most significant changes included in the accounting standards adopted by the CNV relate to (i) changes in the impairment test of long-lived assets and (ii) changes to deferred income tax accounting.

Under the new standards, the carrying value of a long-lived asset is considered impaired by the Company when the expected cash flows from such asset are separately identifiable and are less than the carrying value of the asset. Expected cash flows are determined using the anticipated cash flows discounted at a rate commensurate with the risk involved.

The new standards provide for the accounting treatment of differences between the tax basis and book basis of non-monetary items for deferred income tax calculation purposes when companies prepare price-level restated financial statements. The new accounting mandates companies to treat these differences as temporary differences. However, the standard allows a one-time accommodation to continue treating the differences between the tax basis and indexed book basis of non-monetary items as permanent at the time of adoption of the standard. As such, the Company elected to continue treating differences as permanent.

d)

Short-term receivables and liabilities

Short-term receivables and liabilities, including accrued interest if applicable at the end of each year, have been valued at their respective nominal amount, which does not materially differ from the present value of the future cash flow that the receivables and liabilities will generate, using the internal rate of return estimated at inception.

e)

Foreign currency assets and liabilities

Assets and liabilities denominated in foreign currencies, including accrued interest, if applicable, have been translated at the prevailing exchange rates at the end of each year. Detailed information is disclosed in Note 14.g).

Generally, foreign currency transaction gains and losses are included in the determination of net income.

However, CNV Resolution No. 398 provides, under certain circumstances, for the application of CPCECABA Resolution MD No. 3/02, issued in March 2002, which provides that foreign currency transaction gains or losses on or after January 6, 2002, related to liabilities in foreign currency as of such date may be allocated to the cost of assets acquired or constructed with such financing as long as a series of conditions and requirements established in such standard are complied with. However, in July 2003, the CPCECABA issued Resolution CD No. 87/03, which suspended such accounting treatment and therefore required foreign currency transaction gains and losses to be included in the determination of net income for the period as from July 29, 2003.

f)

Inventories

Inventories consist of natural gas of TGS (in excess of line pack, which is classified as property, plant and equipment) and third parties in the pipeline system, and NGL obtained from natural gas processing at the Cerri Complex. Inventories have been valued at replacement or reproduction cost, as applicable, at the end of each year. The carrying value of inventories does not exceed its net realizable value.

g)

Current investments

Bank accounts and time deposits in local and foreign currency have been valued at their face values plus accrued interest. Private bonds have been valued at their face values plus accrued interest ("amortized cost"), which do not materially differ from their discounted value using the internal rate of return effective at inception.

Mutual funds in foreign currency have been valued at market value at year-end.

Unrealized gains and losses on time deposits and mutual funds are included in financial results, net, in the consolidated statement of income.

h)

Long-term receivables and liabilities in currency

Long-term receivables and liabilities (except for deferred tax assets and liabilities and asset tax credit as described below) have been valued based on the best estimate of the discounted value of the amounts expected to be collected or paid, as applicable, using the interest rate effective at the time of the initial measurement.

F-10

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

 Loans have been valued based on the present value of the amounts expected to be paid, using the internal rate of return estimated at the inception of the transaction. This rate does not significantly differ from the market interest rate at that moment.

Assets and liabilities generated as a result of the application of the deferred tax method and the asset tax credit have been calculated at their nominal value.

i)

Non-current investments

Equity investments in companies in which the Company’s ownership interest ranges between 20% and 50% are Gas Link S.A. (“Link”), Transporte y Servicios de Gas en Uruguay S.A. (“TGU”) and Emprendimientos de Gas del Sur S.A. (“EGS”), have been accounted for under the equity method. These investments have been valued based on the financial statements at the dates specified in Note 14.c), which have been prepared applying the same accounting policies as those used by the Company to prepare its consolidated financial statements. As of December 31, 2007 and 2006, the investment in Link has been adjusted by Ps. 4,350 and Ps. 4,368, respectively, due to the elimination of intercompany profits. The book value of the investment in EGS and TGU as of December 31, 2007 includes Ps. 64 and Ps. 29, respectively, corresponding to the transactions between EGS and the Company in the three-month period ended on December 31, 2007.

The Company considers its foreign subsidiary TGU to be a “non-integrated subsidiary”. Consequently, TGU’s assets and liabilities have been translated into Argentine pesos using the exchange rate in effect at year-end, while its common stock and retained earnings accounts have been translated using historical exchange rates.

The Company’s management is not aware of any significant subsequent events which affected the financial statements of EGS, Link and TGU as from September 30, 2007 to December 31, 2007.

j)

Property, plant and equipment, net

-

Assets transferred from the privatization of GdE: The value of these assets was determined based on the price paid for the acquisition of 70% of the Company’s common stock, which amounted to US$ 561.2 million. This price was the basis to determine a total value of common stock of US$ 801.7 million, which, when added to the debt assumed under the Company’s privatization agreement (the “Transfer Agreement”) of US$ 395.0 million, resulted in a total value for property, plant and equipment of US$ 1,196.7 million.  Such value, converted at the exchange rate in effect as of the date of the Transfer Contract, has been restated for the effects of inflation as described in Note 2.b).

-

Line pack: It represents the natural gas in the transportation system that is necessary to keep the system at operating capacity, and is valued at acquisition cost and restated for the effects of inflation as described in Note 2.b).

-

Capitalization of foreign exchange loss: Resolutions No. 3/2002 and 87/03 issued by the CPCECABA and Resolution No. 398 of the CNV established that exchange losses arising from the devaluation of the peso from January 6, 2002 to July 28, 2003, to the extent that they were related to foreign currency liabilities existing at the first date, may be added to the cost basis of assets acquired or constructed with direct financing by such foreign currency liabilities. Similar accounting treatment is permitted, but not required, for foreign exchange losses arising from indirect financing. It was assumed that the proceeds from such financings were used, firstly, to cover working capital requirements and, secondly, to finance the acquisition or construction of assets that do not qualify for capitalization. The remainder was assumed to relate to assets for which capitalization is permitted.

-

Additions: They have been valued at acquisition cost restated for the effects of inflation as described in Note 2.b). The Company has capitalized all the investments stipulated as mandatory in the License during the first five-year period, in order to achieve system integrity and public safety equal to those required by international standards. Such investments included, among others, the costs of survey programs related to internal and external pipeline inspection, cathodic protection and pipeline replacement and recoating. Additionally, Resolutions No. 1,660 and No. 1,903 issued by ENARGAS include definitions prescribing which costs should be considered improvements and which costs should be considered maintenance expenses. Repair and maintenance costs have been expensed as incurred.

- Depreciation: Accumulated depreciation related to natural gas transportation assets is computed under the straight-line method over the estimated useful lives of the specific assets, provided they are lower than the maximum useful lives established by the ENARGAS through Resolutions No. 1,660 and No. 1,903.

For depreciation of all other property, plant and equipment, the Company uses the straight-line method of depreciation and applies the annual depreciation rates disclosed in Note 14.a).

When assets are retired or otherwise disposed of, the cost and related accumulated depreciation are removed from the accounts, and any resulting gain or loss is reflected in the income statement.

Capitalized foreign exchange loss is depreciated over the remaining useful lives of the assets that led to such capitalization.

- Financial charges capitalization: The Company capitalizes financial expense on long term construction projects. Financial expense capitalized was Ps. 5,053 and Ps. 2,622 for the years ended December 31, 2007 and 2006, respectively.

The Company periodically evaluates the carrying value of these assets for impairment, by comparing the carrying value with its fair value which is calculated based on the projected cash flow discounted at a rate commensurate with the risk involved. In case that its carrying value is higher than its fair value, a loss would be recognized based on the amount by which the carrying value exceeds its fair value.

Based on the projections made as discussed in Note 2.a) and c), the Company’s management believes that the recorded value of property, plant and equipment does not exceed its fair value.

k)

Intangible assets

Intangible assets have been valued at their historical cost, restated to account for the effects of inflation as described in Note 2.b), less accumulated amortization.

Debt issuance costs are being amortized over the term of the notes issued on May 14, 2007 (Note 6).

The intangible assets balance includes costs generated by the acquisition of turbine maintenance and repair licenses and the expenses related to the creation of the Global Program 2007. Both of these items are being amortized in a 5-year period.

l)

Income tax

The Company did not either calculate or pay income taxes on a consolidated basis for any of the periods presented.

The Company and its subsidiary record income taxes using the deferred tax method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Argentine GAAP requires companies to record a valuation allowance for that component of net deferred tax assets which are not recoverable. The statutory income tax rate was 35% for all the periods presented.

The reconciliation between the income tax computed for tax purposes and the income tax expense charged to the statement of income is as follows:

	2007	2006	2005
Estimated current income tax expense	16,205	1,714	611
Deferred income tax expense	130,807	164,726	113,566
Change in valuation allowance	-	(144,549)	(101,362)
Income tax expense	147,012	21,891	12,815

The components of the net deferred tax (liability) / asset as of December 31, 2007 and 2006, are the following:

	2007		2006
Deferred tax assets
Allowance for doubtful accounts	27		98
Present value other receivables	38		5,769
Present value advanced payments from clients	-		451
Other provisions	869		835
Provision for contingencies	16,838		17,547
Accrued interest from loans	-		18,221
Labor provisions	3,120		1,532
Tax loss carryforwards	-		110,750
Foreign exchange loss generated by current investments	177		651
	21,069		155,854
Deferred tax liabilities
Deferred revenues	683		744
Property, plant and equipment, net	77,695		81,612
	78,378		82,356
Net deferred tax (liability) / asset (Note 4.i and 4.d)	(57,309)	(1)	73,498

⁽¹⁾ Net of deferred tax asset of Ps. 95 recorded under “Other non-current receivables”.

Income tax expense computed at the statutory tax rate on pre-tax income differs from the income tax expense for the years ended December 31, 2007, 2006 and 2005 as follows:

	2007	2006	2005
Pre-tax income	294,520	379,914	230,322
Statutory income tax rate	35%	35%	35%
Income tax expense at statutory income tax rate	103,082	132,970	80,613
Permanent differences at statutory income tax rate
- Inflation adjustment	36,524	32,781	35,908
- Non-taxable income and non-deductible expenses	(533)	(447)	(979)
- Variation in deferred tax assets allowance	-	(144,549)	(101,362)
- Others	7,939	1,136	(1,365)
Income tax expense	147,012	21,891	12,815

In assessing the recoverability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become recoverable. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning in making these assessments. The Company is required to continuously evaluate the recoverability of deferred tax assets. This evaluation is based on internal projections made as discussed in Note 2.a), which are routinely updated to reflect more recent trends in the Company’s results of operations.

As mentioned in Note 2.c), TGS has elected to disclose in the note to the consolidated financial statements the deferred tax liability generated by the net book value of the inflation adjustment included in the accounting value of the property, plant and equipment. This deferred tax liability does not constitute an account payable, but it is a liability that will be reversed over the remaining period over which these assets are depreciated. In compliance with Resolution No. 487 of the CNV, TGS advises that, if that liability had been recognized, the deferred tax liability as of December 31, 2007, would have increased in Ps. 687,826 (generating a net liability position of Ps. 745,230) and a positive effect of Ps. 36,395, Ps. 32,714 and Ps. 33,817 on the Company’s net income for the years ended December 31, 2007, 2006 and 2005, respectively, would have been recognized. Additionally, in 2007 and subsequent years, TGS would have r ecorded a lower income tax expense as follows:

F-11

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

	Amount
Year 2008	30,421
Year 2009	30,817
Year 2010	30,359
Year 2011	30,305
Year 2012 onwards	565,924
Total	687,826

m)

Asset tax

The Company and its subsidiary are subject to the Asset Tax Law(“Impuesto a la Ganancia Mínima Presunta”). The asset tax is calculated on an individual entity basis at the statutory tax rate of 1%, and is based upon the taxable assets of each Argentine entity as of the end of the year. This tax is complementary to income tax and the Company is required to pay the greater of the income tax or the asset tax. Any excess of the asset tax over the income tax may be carried forward and recognized as a payment on account of any excess of income tax over asset tax occurring within the subsequent ten years.

In the opinion of management, it is probable that the Company will utilize such asset against future taxable income charges within the next ten years and, as a result, the Company has recognized the accumulated asset tax charge within “Other non-current receivables” in the accompanying consolidated balance sheet.

This tax credit has been recorded at its nominal value according to what it is mentioned in Note 2.h).

The breakdown of the asset tax credit as of December 31, 2007 is as follows:

Fiscal year	Amount	Year of expiration
2002	10,395	2012
2003	26,214	2013
2004	23,861	2014
2005	22,680	2015
2006	22,807	2016
2007	7,960	2017
Balance at the end of the year (Note 4.d.)	113,917

n)

Advances from customers in kind

The advances from customers in kind have been valued at their respective nominal amount considering that this value is higher than the cost of rendering the gas transportation services that will cancel said advances.

o)

Allowances and provisions for contingencies

The Company provides for losses relating to its accounts receivable. The allowance for losses is based on management’s evaluation of various factors, including the credit risk of customers, historical trends and other information. While management uses the information available to make evaluations, future adjustments to the allowance may be necessary if future economic conditions differ substantially from the assumptions used in making the evaluations. Management has considered all events and/or transactions that are subject to reasonable and normal methods of estimation, and the consolidated financial statements reflect that consideration.

The Company has certain contingent liabilities with respect to existing claims, lawsuits and other proceedings, including those involving legal and regulatory matters. The Company records liabilities when it is probable that future costs will be incurred and such costs can be reasonably estimated. Such accruals are based on developments known by TGS at the date of the issuance of these consolidated financial statements, estimates of the outcome of these matters and the experience of its legal counsel in contesting, litigating and settling other matters. As the scope of the contingent liabilities become better defined, there will be changes in the estimates of future costs, which could have a material effect on the Company's future results of operations and financial condition or liquidity.

Contingencies and allowances are disclosed in Note 9 and Note 14.e).

p)

Shareholders’ equity accounts

These accounts have been restated to account for the effects of inflation as described in Note 2.b), except for “Common stock nominal value” which is stated at original cost. The adjustment derived from the restatement of such account has been disclosed under the line item “Inflation adjustment to common stock”, in the Statement of Changes in Shareholders´ Equity.

q)

Revenue recognition

Firm transportation revenues are recognized based on the accrued contracted capacity reserved regardless of actual usage. For interruptible transportation services and certain NGL production and commercialization contracts, revenues are recognized upon the delivery of natural gas or gas liquids to customers, respectively. For other NGL production and other services contracts, revenues are recognized when services are rendered.

r)

Statement of income accounts

Accounts relating to the statement of income have been registered as follows:

-Accounts that accumulate monetary transactions, at their nominal value.

-Expenses related to consumption of non-monetary assets have been charged to the statement of income taking into account the restated cost of such assets as described in Note 2.b).

- Gain / (loss) on related companies were determined on the basis of TGS’ affiliates’ results and were disclosed under “Gain / (loss) on related companies”.

Other expenses, net for the years ended December 31, 2007, 2006 and 2005, include the following items:

	2007	2006	2005
Insurance liquidation associated with the damage of a facility located at the Cerri Complex	-	24,722	-
Provision for contingencies (Note 14.e.)	2,025	(26,129)	(3,490)
Others	(4,619)	676	(2,620)
Total other expense, net	(2,594)	(731)	(6,110)

The breakdown of “Net financial results” line item for the years ended December 31, 2007, 2006 and 2005 is as follows:

	2007	2006	2005
Generated by assets
Interest income	34,103	30,603	15,363
Foreign exchange gain	8,421	13,390	15,822
Impairment of property, plant and equipment	(19,600)	-	-
Other financial results, net	-	1,654	(254)
Total	22,924	45,647	30,931
Generated by liabilities
Interest expense	(156,661)	(193,674)	(185,458)
Foreign exchange loss	(42,643)	(26,536)	(40,256)
Gain on debt prepayment	10,576	-	-
Other expenses and financial charges	(27,691)	(14,480)	(14,289)
Total	(216,419)	(234,690)	(240,003)
Total net financial results	(193,495)	(189,043)	(209,072)

s)

Earnings and dividends per share and per American Depositary Shares (“ADS”)

Earnings and dividends per share and per ADS for the years ended December 31, 2007, 2006 and 2005 have been calculated based on 794,495,283 outstanding shares during each year. One ADS represents five Class B shares. As the Company does not have preferred stock or convertible debt, the amount of basic earnings per share is the same as the amount of diluted earnings per share.

t)

Derivative financial instruments

The Company has outstanding derivative financial instruments with major financial institutions with the aim to reduce the risk of the financial market, at a competitive cost in accordance with the market conditions, to manage the impact of the floating interest rate changes and the US dollar exchange rate changes. TGS does not use financial instruments with speculative aims.

The derivative financial instrument described in Note 6 consists of a currency forward and has been valued at its net realizable value.

3.

CONSOLIDATED BUSINESS SEGMENT INFORMATION

Operating segments are defined under Argentine GAAP as components of an enterprise about which separate financial information is available that is evaluated regularly by the chief operating decision maker, or the decision-making group, in deciding how to allocate resources and in assessing performance. The Company’s decision-making group is the Executive Officer Committee.

For the years ended December 31, 2007, 2006 and 2005, the Company classifies its businesses into three segments: Natural Gas Transportation Services, NGL Production and Commercialization and Other Services. The operating segments are reviewed separately because each operating segment represents a strategic business unit that generally offers different products, although interrelated, and/or serves different markets.

The Company manages its segments to the operating income (loss) level of reporting.

The accounting policies of the operating segments are the same as those described in Note 2.

Assets and liabilities were allocated to each segment based on the specific identification of the assets and liabilities related to the specific business. Assets and liabilities that cannot be allocated to a specific segment were grouped under "Corporate" and include current investments and loans, among others.

As of and for the year ended December 31, 2007	Gas Transportation	NGL Production and commercialization	Other services	Corporate	Total
Net revenues	509,501	667,395	80,377	-	1,257,273
Operating income (loss)	218,406	297,187	25,570	(51,144)	490,019
Depreciation of property, plant and equipment	149,130	32,795	14,226	1,655	197,806
Additions to property, plant and equipment	114,593	56,964	7,929	9,575	189,061
Identifiable assets	3,737,490	474,601	174,224	615,369	5,001,684
Identifiable liabilities	249,528	59,510	9,345	1,753,753	2,072,136

As of and for the year ended December 31, 2006	Gas Transportation	NGL Production and commercialization	Other services	Corporate	Total
Net revenues	491,996	726,393	91,113	-	1,309,502
Operating income (loss)	211,379	370,836	33,864	(45,949)	570,130
Depreciation of property, plant and equipment	144,401	31,050	13,294	3,908	192,653
Additions to property, plant and equipment	119,882	17,719	15,429	3,381	156,411
Identifiable assets	3,836,424	449,891	166,475	686,452	5,139,242
Identifiable liabilities	121,982	61,709	9,734	2,163,686	2,357,111

As of and for the year ended December 31, 2005	Gas Transportation	NGL Production and commercialization	Other services	Corporate	Total
Net revenues	460,008	546,302	58,428	-	1,064,738
Operating income (loss)	202,787	258,470	15,952	(34,312)	442,897
Depreciation of property, plant and equipment	141,211	29,251	13,664	2,867	186,993
Additions to property, plant and equipment	140,388	23,015	4,034	4,093	171,530
Identifiable assets	3,882,854	473,787	183,561	657,028	5,197,230
Identifiable liabilities	68,145	61,074	8,067	2,635,837	2,773,123

The Company renders services of gas transportation business principally to gas distribution companies, to Petrobras Energía, to Profertil S.A. (“Profertil”) and to Repsol-YPF S.A. (“Repsol-YPF”). Significant customers in terms of net revenues from gas transportation for the years ended December 31, 2007, 2006 and 2005 are as follows:

	2007	2006	2005
MetroGAS S.A.	169,590	176,474	173,518
Camuzzi Gas Pampeana S.A.	92,474	89,501	83,696
Gas Natural BAN S.A.	71,519	70,042	64,477
Petrobras Energía (Note 10)	28,500	26,635	25,173
Camuzzi Gas del Sur S.A.	24,857	23,915	22,542
Profertil	11,445	11,459	11,577
Repsol-YPF	17,524	27,346	16,853

Significant customers in the NGL production and commercialization segment are Petrobras International Finance Company (“PIFC”), a subsidiary of Petrobras Petróleo Brasileiro S.A., and PBB-Polisur S.A. (“Polisur”). Net revenues from these customers (include NGL sales made on behalf of third parties, from which TGS withholds charges for the production and commercialization of NGL) for the fiscal years ended December 31, 2007, 2006 and 2005 are as follows:

	2007	2006	2005
PIFC (Note 10)	476,551	530,212	383,871
Polisur	203,888	238,188	141,547

4.

SUMMARY OF SIGNIFICANT BALANCE SHEET ITEMS AS OF DECEMBER 31, 2007 AND 2006

		2007	2006
a)	Current accounts receivable
	Gas transportation
	MetroGAS S.A.	8,773	16,649
	Camuzzi Gas Pampeana S.A.	8,803	8,473
	Gas Natural BAN S.A.	7,479	7,358
	Camuzzi Gas del Sur S.A.	2,128	2,189
	Profertil	1,261	1,158
	Repsol-YPF	3,045	6,997
	Total Austral S.A. (“Total Austral”)	3,345	2,969
	Pan American Sur S.R.L. (“PAS”)	2,948	1,906
	Related companies	4,125	3,469
	Others	12,866	7,753
	Subtotal	54,773	58,921

F-12

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

	2007	2006
NGL production and commercialization
Polisur	22,032	25,089
Pan American Energy LLC (Argentine Branch)	1,165	7,979
Total Austral	3,788	5,790
Related companies	47,848	50,681
Others	6,827	6,456
Subtotal	81,660	95,995

	Other services
	Pan American Energy LLC (Argentine Branch)	939	2,085
	Profertil	3,437	3,340
	Sipetrol Argentina S.A.	-	538
	Gas trust fund (Note 7.c.)	9,230	-
	Related companies	2,604	9,246
	Others	13,173	9,109
	Subtotal	29,383	24,318
	Allowance for doubtful accounts (Note 14.e)	(716)	(920)
	Total	165,100	178,314
b)	Other current receivables
	Tax credits	13,357	23,592
	Prepaid insurance expense	4,311	4,589
	Advances to suppliers	26,127	9,737
	Claims to third parties(1)	25,493	-
	Others	8,342	7,717
	Total	77,630	45,635

c)	Non-current accounts receivable
	Other services
	Profertil	13,443	14,710
	Total	13,443	14,710
d)	Other non-current receivables
	Deferred income tax  (Note 2.l.)	95	73,498
	Asset tax credit (Note 2.m.)	113,917	111,641
	Easement expense to be recovered	4,233	4,233
	Others	4,909	4,338
	Total	123,154	193,710
e)	Current accounts payable
	Suppliers	147,954	152,285
	Customers (Credit balances)	13,594	19,880
	Related companies (Note 10)	2,042	2,451
	Total	163,590	174,616
f)	Taxes payable
	Asset tax, net	-	13,733
	Turnover tax	568	884
	Income tax (net of advances and others)	6,371	-
	Value added tax (“VAT”)	106	1,917
	Tax on exports	23,021	803
	Others	4,203	3,468
	Total	34,269	20,805

F-13

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

		2007	2006
g)	Current advances from customers(2)
	Aluar Aluminio Argentino S.A.C.I. (“Aluar”)	2,411	1,765
	Total Austral	6,426	1,743
	Wintershall Energía S.A. (“Wintershall”)	1,656	1,743
	PAS	4,284	1,162
	Other	585	761
	Total	15,362	7,174

h)	Other liabilities
	Negative equity value (Note 14.c)	-	120
	Provisions forGdElawsuit (Note 9.d)	12,035	11,517
	Other provisions	119	556
	Total	12,154	12,193

i)	Non-current taxes payable
	Deferred income tax	57,404	-
	Total	57,404	-
j)	Non-current advances from customers(2)
	Aluar	55,539	47,488
	Total Austral	41,582	4,611
	Wintershall	2,628	4,611
	PAS	27,721	3,073
	Others	21	56
	Total	127,491	59,839

⁽¹⁾ It corresponds to an arbitration claim initiated by TGS against the Bank of America for the amount of US$ 9 million, net of a related payment received late in December 2007. The claim is based on the annulment made by the bank, of the transfer of funds to TGS account that had been instructed by the Company on December 6, 2007 to redeem securities of the Columbia Strategic Cash Fund (Cash Fund arranged by the Bank of America). On such date, the Cash Fund entered into a liquidation process, and pledged to refund to the subscribers the proceeds of the settlement of its investments in the following months. From December 6, 2007 to the date of the issuance of these consolidated financial statements the Cash Fund has reimbursed to TGS US$ 2.8 million, on account of the US$ 9 million (Note 9.e.).

⁽²⁾ They are mainly related to the financing of TGS pipeline system expansion works for the rendering of firm transportation services contracted by such clients. The advance payments will be settled with the effective rendering of firm transportation service.

5.

SUPPLEMENTAL CASH FLOW INFORMATION

For purposes of the consolidated statement of cash flows, the Company considers all highly liquid temporary investments with an original maturity of three months or less at the time of purchase to be cash equivalents. The cash flow statement has been prepared using the indirect method, which requires a series of adjustments to reconcile net income for the year to net cash flows from operating activities.

The following table reconciles the balances included as cash and banks and current investments in the balance sheet to the total amounts of cash and cash equivalents at the beginning and end of the period shown in the statements of cash flows:

	As of December 31,
	2007	2006	2005
Cash and banks	2,816	6,583	2,418
Current investments	421,102	471,673	510,526
Current investments other than cash and cash equivalents	(32,600)	-	-
Total cash and cash equivalent	391,318	478,256	512,944

F-14

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

Non-cash transactions are as follows:

	As of December 31,
	2007	2006	2005
Acquisition of property, plant & equipment through an increase in accounts payable	20,312	36,079	7,337
Financial charges capitalization	(1,264)	(286)	(1,647)

Cash flows resulting from operations include net financial expense generated by cash and cash equivalents as of December 31, 2007, 2006 and 2005 for Ps. 27,295, Ps. 33,405 and Ps. 24,808, respectively.

6.

LOANS

Short-term and long-term debt as of December 31, 2007 and 2006 comprise the following:

	2007	2006
Current Loans:
Tranche A:
2004 Euro medium – term notes (“EMTN”) Program:  Series 1 notes	-	54,381
Privately placed notes	-	3,414
Inter-American Development Bank (“IDB”) loans	-	30,197
1999 EMTN Program: Series 2 notes(1)	94	92
Interests payable	15,636	8,003
Financial leases (annual interest rate of 7.65%)	729	2,976
Total current loans	16,459	99,063
Non- current loans:
2007 EMTN Program:  Series 1 notes	1,574,500	-
Tranche A:
2004 EMTN Program:  Series 1 notes	-	331,490
Privately placed notes	-	20,810
IDB loans	-	184,211
Tranches B-A and B-B:
2004 EMTN Program:  Series 1 notes	-	781,720
Privately placed notes	-	121,145
IDB loans	-	426,436
Interests payable	-	52,060
Financial leases (annual interest rate of 7.65%), due through 2008	-	652
Total non-current loans	1,574,500	1,918,524
Total loans	1,590,959	2,017,587

⁽¹⁾ Corresponds to notes that were not tendered in the debt exchange made in December 2004 and bear an annual interest rate of 10.375%.

Issuance of notes under the 2007 Global Program:

The Extraordinary Shareholders' meeting held on December 21, 2006 approved the creation of the Global Program for the issuance of new notes of a maximum aggregate amount of US$ 650,000,000. This Program was authorized by the CNV on January 18, 2007.

With the aim of improving the indebtedness profile of the Company and to soften the restrictions of the previous debt, in May and June 2007, TGS succeeded in the process of refinancing its financial debt by means of the issuance of new notes in an amount of US$ 500,000,000 within the 2007 Global Program, and the prepayment of its prior debt by a tender offer, the redemption of those notes not tendered and the prepayment of the IDB loans.

The early amortization of the restructured debt generated a Ps. 10,576 gain, which is net of a cost of Ps. 25,222 paid for the prepayment of Tranche B-A (equaled to the 2% of the principal amount), and the Ps. 2,291 premium paid for the equivalent of 0.25% of the residual principal amount of the tendered notes.

The issuance of the US$ 500,000,000 notes within the Global Program 2007, due on May 14, 2017, accrues interest at a fix annual rate of 7.875%, payable semi-annually. The principal amount will be amortized in four equal payments of US$ 125,000,000, which mature on May 14, 2014, 2015, 2016 and 2017. Public trading of these notes was authorized by theBolsa de Comercio de Buenos Aires ("BCBA"), theMercado Abierto Electrónico (“MAE”) and the Luxembourg Stock Exchange.

Covenants:

The Company is subject to some restrictive covenants under its outstanding debt obligations which include, among others, some restrictions to incur new debt, dividend payments, the granting of guarantees, assets sales and transactions with related companies.

The Company may incur new debt, under these restrictions, among others:

a.

As long as after incurring the new debt, (i) the consolidated coverage ratio (quotient of the consolidated adjusted EBITDA -earnings before financial results, income tax, depreciation and amortization-) and the consolidated interest expense) is equal or higher than 2.0:1; and (ii) the consolidated debt ratio (quotient of the consolidated debt and the consolidated EBITDA) is equal or lower than 3.75:1.

b.

For the refinancing of the outstanding financial debt.

c.

Provided by advances from customers.

The Company may pay dividends as long as (i) the Company is not in default under the new debt obligations, (ii) immediately after the dividend payment, the Company would be able to incur in additional indebtedness pursuant to a. from the preceding paragraph.

Financial debt restructured in December 2004:

Debt corresponding to Tranches A, B-A and B-B was issued in December 2004 to restructure the terms and conditions of the previous outstanding loans, which payments of principal and interest were suspended in May 2003.

The principal terms of the Company’s outstanding debt obligations were as follows:

Description	Tranche A	Tranches B-A y B-B
Principal	US$ 470,306,281, which represented 52% of the total principal amount.	US$ 409,044,874 and US$ 25,083,940, respectively, representing approximately 48% of the principal amount.
Interest	Ranging from an annual rate of 5.3% for the first year to 7.5% in the last year, payable on a quarterly basis.	Ranging from an annual rate of 7% for the first year to 10% in the ninth year, payable on a quarterly basis, The Tranche B-A debt obligations also accrued additional interest from December 15, 2006 onwards at an incremental annual interest rate ranging from 0.75% to 2%, subject to the level of the Company’s consolidated adjusted EBITDA (as defined in the new debt obligations) for each applicable fiscal year. The Tranche B-B debt obligations also accrued additional interest at an incremental annual rate starting at 0.60% in the third year and increasing by 5 basis points (0.05%) annually until such annual rate reached 0.90% in the last year.
Principal amortization	Amortization quarterly payments commencing on March 15, 2005 until December 15, 2010.	Amortization quarterly payments commencing on March 15, 2011 until December 15, 2013.

The notes and privately placed notes in a principal amount of US$ 531,870,232 and US$ 82,424,863, respectively, were issued pursuant to the Company’s Global Program, which provides for the issuance of notes up to a maximum amount of                    US$ 800,000,000. The creation of the Global Program was approved by the Annual Shareholders’ Meeting held on April 2, 2004 and was authorized by the CNV on October 28, 2004. Public trading of notes was authorized by the BCBA and the MAE.

Derivative financial instruments

In November 2007, the Company entered into a currency forward agreement with a major financial institution, which expiration date was on May 12, 2008. By means of this hedge agreement, the Company ensured the purchase of US$ 9 million at an exchange rate of Ps. 3.227 per U.S. Dollar, in order to afford the interest payment of its financial debt on May 14, 2008. To the purpose of its settlement, the Company took the reference exchange rate informed by the Central Bank of the Argentine Republic (“BCRA”) through the Circular A 3,500. As of December 31, 2007, its fair value amounts to approximately (Ps. 90) and was recorded in “Current Loans” with debit to “Other Comprehensive Loss” account.

7.

REGULATORY FRAMEWORK

a)

General framework and current tariff context:

The Company’s natural gas transportation business is regulated by Law No. 24,076 (“the Natural Gas Act”), its regulatory decree No. 1,738/92 and by regulations issued by ENARGAS, which is entitled, among other things, to set the basis for the calculation, monitoring and approval of tariffs (the “Regulatory Framework”). According to the Regulatory Framework, transportation tariffs were to be calculated in US dollars and converted into Argentine pesos at the time the customer was billed using the exchange rate prevailing at that time. The basic gas transportation tariffs charged by TGS had been established at the time of the privatization of GdE and were to be adjusted, subject to prior authorization, in the following cases: (i) semi-annually to reflect changes in the US producer price index (“PPI”) and (ii) every five years according to efficiency and investment factors determined by ENARGAS. The “efficiency factor” is a reduction to the base tariff resulting from future efficiency programs while the “investment factor” increases the tariffs to compensate the licensees for future investments which are not repaid through tariffs. Also, subject to ENARGAS approval, tariffs were to be adjusted to reflect non-recurrent circumstances or tax changes, other than income tax.

The terms and conditions as described in the precedent paragraph in connection with tariff adjustments contemplated within the Regulatory Framework are no longer effective since the enactment of the Public Emergency Law in early 2002 (the “Emergency Law”), which, among other provisions, eliminated tariff increases based on US dollar exchange rate fluctuations, foreign price indexes or any other indexing procedure and established a conversion rate of one peso to one US dollar for tariffs. The Emergency Law also granted the Executive Branch power to renegotiate contracts entered into with private utility companies, pursuant to the framework included in the said law as long as it is in force, which will expire in December 31, 2008, after several extensions.

In July 2003, the Unit for Renegotiation and Assessment of Utilities Contracts (“UNIREN”) was created under the joint jurisdiction of the Ministry of Economy and Production and the Ministry of Federal Planning, Public Investment and Services. UNIREN conducts the renegotiation process of the contracts related to utilities and public works, and is entitled to enter into total or partial agreements with the licensees and submit projects regulating the transitory adjustment of tariffs and prices, among other things. At the end of 2003, the UNIREN submitted the “Preliminary Renegotiation Guidelines” to TGS including a draft agenda with main issues to be discussed during the renegotiation process such as costs, investment programs and financing, rates of return and tariffs, etc, and a renegotiation schedule which set December 28, 2004 as the deadline for the adjustment of the regulatory framework with the approval o f the National Congress.

In July 2004, UNIREN submitted to TGS a proposal for the adjustment of the contractual terms and conditions of the License, which among other things provided for a tariff increase of 10% effective as from 2005, an overall tariff review to become effective as from 2007 and required TGS’s and its shareholders’ abandonment of any claim or lawsuit resulting from the effects of the Public Emergency Law on the License prior to the effectiveness of a renegotiation of the License, and also demanded TGS to hold the Argentine government harmless from any claim or lawsuit filed by its shareholders. As this proposal differed from discussions TGS previously had with UNIREN, the Company rejected it and sought to reach an overall agreement with UNIREN by the end of 2004 (in line with UNIREN’s original proposal set forth in the “Preliminary Renegotiation Guidelines”) and to carry out the process of obtaining approval fro m the National Congress during the first semester of 2005.

During the Public Hearing held on April 27, 2005, with the aim of discussing the above mentioned proposal, UNIREN reaffirmed its 10% tariff increase proposal and suggested to advance the process of the overall tariff revision, so that the resulting tariff adjustments would come into effect during 2006. UNIREN also outlined a first stage that included the postponement of the potential claims from the Company and its shareholders, prior to a renegotiation of the License, and the subsequent abandonment of any such claims from TGS or its shareholders, and the agreement to hold harmless the Argentine Government. Regarding the original proposal, TGS put forward the need to improve certain items of UNIREN’s original proposal and expressed its willingness to continue the negotiation.

In June and November 2005, TGS received two proposals from UNIREN which were in line with the previous one. Said proposals also established, as an additional condition, the Company’s and its shareholders’ abandonment of any future claim or lawsuit regarding the PPI tariff adjustments which were not applied in 2000 and 2001. TGS responded to the proposals, and declared that the original 10% increase was insufficient and committed not to file any administrative, arbitration or judicial claim or lawsuit in Argentina or abroad, as long as a reasonable renegotiation agreement was reached. Moreover, TGS stated that the Company is determined to make its best efforts to obtain similar commitments from its investors.

In November 2005, in response to the requirement made by the UNIREN, CIESA and Petrobras Energía Holding (as CIESA’s shareholder) confirmed that they had not initiated or intended to initiate in the future any claim against the Argentine Republic. Furthermore, Ponderosa Assets L.P. (“Ponderosa”) as a controlling company of Enron Pipeline Company Argentina S.A. (“EPCA”) and Enron Argentina CIESA Holding S.A. (“EACH”) (both TGS’s shareholders at that time, and in the case of EPCA, currently CIESA’s minority shareholder) informed on the existence of a claim which, jointly with Enron Corp., it had initiated against the Argentine Republic before the International Center for the Settlement of Investment Disputes (“ICSID”) and that it would only consider waiving its claim if Ponderosa has received fair compensation. In May 2007, the ICSID ordered the Argentine Government to pay US$ 106.2 million to Enron Corp.

During 2006, the UNIREN made two new proposals to TGS with the same guidelines established in the previous proposals, reflecting no significant progress in the tariff renegotiation process as of the date of the issuance of these consolidated financial statements.

The NGL production and commercialization segment is not regulated by the ENARGAS, and as it is provided in the Transfer Agreement, is organized as a separate business unit within the Company, keeping accounting information separately. However, the Federal Energy Bureau regulates the propane and butane sales price for the local market. This organism determines annually a minimum volume of propane and butane to be commercialized in the local market in order to guarantee the domestic supply.

The License establishes, among other restrictions, that the Company will not be able to afford CIESA´s obligations, nor granting loans, real guarantees or of any other sort in favor of the creditors of this company.

b)

Gas Electronic Market (“MEG”)

The Executive Branch, through Decree No. 180/04, among other measures, established the creation of the MEG with the purpose of improving the transparency of financial and operating performance, the coordination of daily transactions both of the gas spot and the transportation and distribution secondary markets along with the shaping of efficient prices through offer and demand free interaction. To that purpose, all firm transportation capacity non-allocated for the following day shall be marketed through the MEG and the proceeds from that capacity sale will be used at the Energy Bureau’s criteria. Non-allocated capacity includes remaining capacity not used in any of the transportation systems or pipelines. This implies that TGS is bound to offer daily non-allocated capacity that complies with this condition in the MEG, which might have a material impact on the Company’s interruptible transportation revenues. Notwithstan ding the MEG started its operations in August 2005, it has not started yet with respect to the transactions related to natural gas transportation and distribution.

F-15

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

c)

Expansion of the gas transportation system

Due to the lack of expansions of the natural gas transportation system over the last years (as a consequence of the “pesification” of tariffs and the fact that the renegotiation of the license is still pending) and a growing gas demand in certain segments of the Argentine economy, the Argentine Government established - through Executive Branch Decree No. 180/04 and Resolution No. 185/04 issued by the Ministry of Federal Planning, Public Investment and Utilities - the framework for the creation of a trust fund (“the gas trust fund”) aimed  at  financing the expansion of the national gas transportation system.

Within this framework, the first expansion of the San Martín Pipeline ended in August 2005, which increased the transportation capacity by 102 millions of cubic feet per day (“MMcf/d”). This project involved the construction of approximately 316 miles of pipeline and a 30,000 HP compression capacity increase through the construction of a compressor plant and the revamping of some of TGS’s existing compressor units. The gas trust fund financed US$ 311 million from a total amount of US$ 351 million, while TGS invested approximately US$ 40 million (including VAT for U$S 7 million).

The gas trust fund repays it investment by means of the 20% of the total net revenues generated by the current tariffs from the additional transportation capacity and collects an specific charge, which is finally paid by industries, power plants and compressed natural gas suppliers for whom gas transportation supply is made under firm contracts. This charge represents an 81.6% increase in the current tariffs. The works financed by these means belong to the gas trust fund and, TGS, as well as being in charge of the management of the works, is responsible for the operation and maintenance of the gas trust assets. The cost of TGS's investment is being recovered through collection of the remaining 80% of current tariff rate. This surplus is also bound for the payment of operation and maintenance expense of these new assets.

In April 2006, the Ministry of Federal Planning and Public Investment and Utilities, the Federal Energy Bureau and natural gas transportation companies, among others, signed a Letter of Intent to carry out the second expansion of the gas pipeline system. This new expansion will increase the transportation capacity by 883 MMcf/d, of which approximately 332 MMcf/d correspond to TGS system. In December 2006, the gas trust fund contracts and the works management agreement were signed; the latter is in charge of TGS.

According to this agreement, TGS will bill Ps. 50 million plus VAT as a consideration for the services to be rendered for the 247 MMcf/d expansion (for the year ended December 31, 2007, the Company recorded a provision of Ps. 9.2 million), and the expansion works management fee for the remaining 85 MMcf/d has not yet been determined. The property of the works will be entitled to a gas trust fund and the investment would be financed by other gas trust funds, whose trustors are the shippers who subscribed the additional capacity. The works will be repaid with a new tariff charge that will be finally paid by the industries, power plants and large and medium-size businesses.It is expected that the first stage, which consists of an expansion of 78 MMcf/d, will be in operation in winter of 2008.

d)

Essential assets:

A substantial portion of the assets transferred by GdE has been defined as essential for the performance of the gas transportation service. Therefore, the Company is required to segregate and maintain these assets, together with any future improvements, in accordance with certain standards defined in the License.

The Company may not, for any reason, dispose of, encumber, lease, sublease or loan essential assets nor use such assets for purposes other than providing the licensed service without the prior authorization of ENARGAS. Any expansion and improvement that the Company may make to the gas pipeline system after the takeover may only be encumbered to secure loans that have a term of more than one year to finance new expansions and improvements to the licensed service.

Upon expiration of the License, the Company will be required to transfer to the Argentine Government or its designee, the essential assets listed in an updated inventory as of the expiration date, free of any debt, encumbrances or attachments, receiving compensation equal to the lower of the following two amounts:

i)

the net book value of the essential assets determined on the basis of the price paid by the acquiring joint venture, and the original cost of subsequent investments carried in US dollars and adjusted by the PPI, net of accumulated depreciation according to the calculation rules to be determined by ENARGAS; or

ii)

  the net proceeds of a new competitive bidding.

8.

COMMON STOCK AND DIVIDENDS

a)  Common stock structure and shares’ public offer

As of December 31, 2007, 2006 and 2005 the Company’s common stock was as follows:

Common Shares Class (Face value $ 1, 1 vote)	Amount of common stock, subscribed, issued, paid in, and authorized for public offer
Class “A”	405,192,594
Class “B”	389,302,689
	794,495,283

TGS’s shares are traded on the BCBA and under the form of the American Depositary Shares (“ADS”) (registered in the SEC and representing 5 shares each) on the New York Stock Exchange.

The Company is required to have in force the authorization of the public offer of its common stock and the corresponding authorization to trade in the different official stock markets in Argentina until 2009.

b)

Limitation on the transfer of the Company’s shares

The Company's by-laws provide that prior approval of ENARGAS and the unanimous approval of CIESA’s shareholders, under agreements among them, must be obtained in order to transfer Class “A” shares (representing 51% of common stock). The Bid Package states that approval of ENARGAS will be granted provided that:

-

The sale covers 51% of common stock or, if the proposed transaction is not a sale, the transaction that reduces the shareholding will result in the acquisition of a shareholding of not less than 51% by another investment company; and

-

The applicant provides evidence to the effect that the transaction will not impair the operating quality of the licensed service.

In the case of shareholders of CIESA who have qualified to obtain such condition due to the equity, guarantee and/or technical background of their respective parent companies, the sale of shares representing the capital of such subsidiaries by the respective ultimate, direct or indirect parent companies, and/or the cessation of management running the Company, requires the prior authorization of ENARGAS.

In case the Company wishes to reduce its capital, redeem its shares or distribute any part of its equity, except for the payment of dividends, in accordance with the provisions of the Argentine Business Associations Law, it requires prior authorization from ENARGAS.

c)

Restrictions on distribution of retained earnings

Under current Argentine legal requirements and CNV standards, 5% of each fiscal year net income must be appropriated into a legal reserve, provided that there is no unappropriated retained deficit. In such case, the 5% should be calculated on any excess of the net income over the unappropriated retained deficit. This appropriation is legally binding until such reserve equals 20% of the amount which results from the sum of the “Common stock nominal value” and the balance of “Inflation adjustment to common stock”.

In addition, the by-laws provide for the issuance of Profit Sharing Vouchers, as defined in Article 230 of the Argentine Business Associations Law, which Vouchers entitle all regular employees to share in 0.25% of the Company’s net income for each year.  

According to law No. 25,063, the dividends paid in cash or in kind, in excess of the tax profit, will be subject to a 35% withholding tax of the income tax, as sole and only payment.

Furthermore, the Company is subject to certain restrictions for the payment of dividends, which were contemplated in the outstanding debt agreements (Note 6 - “Covenants”).

9.

LEGAL AND REGULATORY MATTERS

a)

In the framework of the Tax Agreement subscribed by the Argentine Government and the Provinces in 1993, and as from the enactment of provincial Law No. 11,490, NGL sales were exempted from the turnover tax in the province of Buenos Aires. In September 2003, the Tax Bureau of the Province of Buenos Aires, through overruling Resolution No. 4,560/03, denied the exemption and claimed unpaid taxes on accrued NGL sales as from 2002. In October 2003, the Company filed an administrative appeal with the Tax Court of the Province of Buenos Aires.

In February 2007, the Tax Court partially upheld TGS complaint. In its pronouncement, the Tax Court stated that ethane sales were within the scope of the turnover tax exemption but that neither propane nor butane sales qualified for the exemption, because they were not raw materials for an industrial process. 

In May 2007, TGS appealed the unfavorable portion of this ruling in the Province of Buenos Aires Court alleging that propane and butane sales might be utilized for other uses different from petrochemical industry.

Moreover, in November 2004, TGS received a notice from the Tax Bureau of the province of Buenos Aires starting thus a tax assessment process regarding the claim mentioned above. On September 26, 2005, TGS was notified of the results of the tax assessment process for the period from January 2002 to July 2003, which amounted to Ps. 4.4 million plus interest. On October 18, 2005, TGS filed a motion to dismiss on its belief that the NGL sales activity was conducted under the tax exemption regime discussed above. On April 12, 2006 the motion to dismiss was rejected and therefore, the Company filed an appeal with the Tax Bureau of this province.  

As of December 31, 2007, TGS recorded a provision of Ps. 15.9 million, having partially reversed in this year the provision related to ethane sales recorded under the line Other expenses, net, pursuant to the sentence pronounced in February 2007 mentioned before.

b)

In February 2005, the Company was served notice by the CNV that certain notes issued in December 2004 by US$178 million did not fulfil the requirements provided by Article 56 of Chapter VI of the CNV Standards and in Resolution No. 470. Therefore, if CNV´s interpretation prospers, those notes would not be entitled to the benefits of the tax exemption provided by the law No. 23,576, thus the Company would be exposed to a contingency due to the payment of the withholding income tax on interest payments.

On February 18, 2005, TGS filed an appeal with the CNV, alleging sufficient grounds to support the applicability of Article 56, Chapter VI of CNV Standards and Resolution N°470/04. However, the CNV denied the Company’s appeal and on July 8, 2005, TGS filed an appeal with the Ministry of Economy and Production which was subsequently rejected in November 2006. In December 2006, TGS filed a second appeal with said Ministry seeking reconsideration of the rejection, which was rejected in June 2007. In November 2007, TGS challenged said resolution before the Federal Administrative Court.

As of December 31, 2007, the amount of this contingency ranges between US$ 6 million and US$ 17 million (including interests as of this date), depending on the applicable withholding tax rates determined on payments of interest by Argentine obligors, by the country of residence of the note holders at the date of each interest payment. The Company does not have available information that permits the identification of the country of residence of each note holder on each interest payment date.

The Company believes that it has sufficient grounds and other legal instances to defend its position and thus, as of December 31, 2007, TGS has not recorded any provision in connection with this matter.

c)

In November 2002, the Tax Bureau of the Province of Santa Cruz sent TGS a formal assessment notice for the payment of the turnover tax calculated on the value of the natural gas used by TGS as fuel to render its transportation services. This assessment corresponds to the fiscal period from January 1998 to October 2002. In August 2005, the Company paid the amount claimed of Ps. 1.6 million (including interests to December 4, 2002) and started a tax recovery process, first exhausting all other procedural steps, with the Tax Bureau of the province and then initiationg a proceeding in the provincial Tax Court..

In November 2005, TGS received a notice from the Tax Bureau of the province of Río Negro, claiming the payment of Ps. 0.2 million, on the same grounds as those of the Province of Santa Cruz, for the period from January 1999 to May 2005. On February 1, 2008, TGS initiated a tax recovery process with the Tax Court of the province of Río Negro to obtain the refund of Ps. 0.5 million paid in November 2007, after exhausting the same procedural steps followed in the case of province of Santa Cruz.

As of December 31, 2007, the Company recorded a provision of Ps. 20.1 million under the line item "Provisions for contingencies", determined according with the estimations of tax and interests to be paid as of such date, as an estimate of contingency which could be unfavourable to the Company.

The Company’s management believes that, in case the Company’s position fails and the turnover tax has to be paid, TGS has a right to recover it by a transportation tariff increase as set forth in the License.

d)

In 1996, GdE filed a legal action against the Company for the reimbursement for the cost of construction of two compressor plants. After a long litigation process, in 2003, the Supreme Court of Justice sustained GdE's claim and sentenced TGS to pay the market price of the compressor plants at the date of the addition to TGS assets plus interest and litigation expenses. As of December 31, 2007, the remaining balance of the sentence amounted to Ps. 46.4 million.

On January 14, 2004, TGS signed an agreement with the UNIREN, which was subsequently ratified by the Argentine government through the Decree No. 959/04 through which TGS will carry out the expansion of the Cordillerano Pipeline. The cost of the expansion will be taken as a payment on account of the final amount to be paid as a consequence of the outcome of the lawsuit described above. The Argentine Government owns such assets and granted their right of use to TGS, who will have to operate and maintain such assets. Therefore, the cost of the works was recorded under "Other liabilities", offsetting the provision mentioned above. As of December 31, 2007, the net provision amounted to Ps. 12.0 million.

e)

On February 1, 2008, TGS filed an arbitration claim against the Bank of America in order to obtain the refund of US$ 9 million corresponding to the annulment made by the mentioned bank of the transfer of funds to TGS account that the Company had instructed the bank to execute on December 6, 2007. The arbitration is conducted under the provisions of the Federal Arbitration Act and the rules of the Judicial Arbitration and Mediation Services, Inc. in the United States of America (Note 4.b.).

f)

On November 30, 2007, TGS was served notice of the summary proceedings initiated against the Company by the BCRA. This entity charges TGS with the late settlement of foreign currencies for an approximate amount of US$ 14.7 million. The questioned transactions were conducted between January 2002 and February 2003, period in which the applicable exchange regulations were subject to frequent changes and the terms for the settlement of foreign currencies were shorter than the current ones.

The Company believes that it has several legal instances to defend its position, and accordingly, as of December 31, 2007, TGS has not recorded any provision in respect of this proceeding. Based on the opinion of our legal advisors, the amount of the fine that may result from an eventual adverse sentence will not be greater than US$ 7.3 million.

g)

In addition to the matters discussed above, the Company is a party to certain lawsuits and administrative proceedings arising in the ordinary course of business.

10.

BALANCES AND TRANSACTIONS WITH RELATED COMPANIES

TGS sells propane, butane, and natural gasoline to PIFC, at international prices minus a fixed discount per ton, according to common market practices for this type of transactions.

Petrobras Energía is TGS´s technical operator, according to the approval of ENARGAS in June 2004, and subject to the terms and conditions of the Technical Assistance Agreement which provides that Petrobras Energía is in charge of providing services related to the operation and maintenance of the gas transportation system and related facilities and equipment, to ensure that the performance of the system is in conformity with international standards and in compliance with certain environmental standards. For these services, the Company pays a monthly fee based on a percentage of the operating income of the Company.

Additionally, TGS renders natural gas transportation services to Petrobras Energía, for a 106 MMcf/d firm capacity by means of two contracts which expire in 2013 and 2014. Moreover the Company, under certain agreements, processes the natural gas in Cerri Complex and commercializes the NGL for Petrobras Energía’s account and on behalf of it. For consideration, TGS collects a commission which is calculated over the NGL selling price. This service is regulated by a contract which is due in December 2010.

As of December 31, 2007 and 2006, the outstanding balances corresponding to the Board of Directors´ compensations amounted to Ps. 78 and Ps. 97, respectively. The accrued amounts for such compensation for the years ended December 31, 2007, 2006 and 2005 were Ps. 751, Ps. 395 and Ps. 261, respectively.

The detail of significant outstanding balances for transactions entered into by TGS and its related parties as of December 31, 2007 and 2006 is as follows:

	2007		2006
Company	Accounts receivable	Accounts payable	Accounts receivable	Accounts payable
Controlling shareholders:
CIESA	111	-	37	-
Petrobras Energía	4,558	8,761	9,590	2,451
Affiliates with significant influence:
Link	101	-	193	-
TGU	210	-	147	-
EGS	21	-	20	-
Other related companies:
PIFC	47,332	-	50,518	-
Área Santa Cruz II U.T.E.	307	-	311	-
Refinor S.A.	730	-	1,327	-
WEB S.A.	643	-	218	-
Total	54,013	8,761	62,361	2,451

F-16

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

The detail of significant transactions with related parties for the years ended December 31, 2007, 2006 and 2005 is as follows:

For the year ended December 31, 2007

	Revenues
Company	Gas transportation	NGL production and commercialization	Other services	Purchase of gas and others	Compensation for  technical assistance	Revenues for administrative services
Controlling shareholders:
EPCA	-	-	-	-	-	13
Petrobras Energía	28,500	25,562	16,741	8,691	34,747	-
CIESA	-	-	-	-	-	122
Affiliates with significant influence:
Link	-	-	995	-	-	-
TGU	-	-	207	-	-	-
Other related companies:
PIFC	-	476,551	-	-	-	-
Refinor S.A.	-	-	1,614	-	-	-
WEB S.A.	2,793	-	-	-	-	-
Área Santa Cruz II U.T.E.	-	-	3,079	-	-	-
Total	31,293	502,113	22,636	8,691	34,747	135

For the year ended December 31, 2006

	Revenues
Company	Gas transportation	NGL production and commercialization	Other services	Purchase of gas and others	Compensation for technical assistance	Revenues for administrative services
Controlling shareholders:
EPCA	-	-	-	-	-	80
CIESA	-	-	-	-	-	122
Petrobras Energía	26,635	28,411	27,273	9,128	42,631	-
Affiliates with significant influence:
Link	-	-	947	-	-	-
TGU	-	-	307	-	-	-
EGS	-	-	49	-	-	-
Other related companies:
PIFC	-	530,312	-	-	-	-
Refinor S.A.	-	-	2,356	-	-	-
Quintana y Otros U.T.E.	1,820	-	-	-	-	-
WEB S.A.	3,044	-	-	-	-	-
Área Santa Cruz II U.T.E.	-	-	2,069	-	-	-
Total	31,499	558,723	33,001	9,128	42,631	202

F-17

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

For the year ended December 31, 2005

	Revenues
Company	Gas transportation	NGL production and commercialization	Other services	Purchase of gas and others	Salaries and wages	Compensation for  technical assistance	Revenues for administrative services
Controlling shareholders:
EPCA	-	-	-	-	-	-	84
CIESA	-	-	-	-	-	-	122
Petrobras Energía	25,173	21,189	16,019	3,643	210	32,880	-
Affiliates with significant influence:
Link	-	-	876	-	-	-	-
TGU	-	-	614	-	-	-	-
EGS	-	-	323	-	-	-	-
Other related companies:
PIFC	-	383,871	-	-	-	-	-
Petrolera Santa Fe S.A.	-	-	-	2,879	-	-	-
Refinor S.A.	-	-	2,157	-	-	-	-
Quintana y Otros U.T.E.	3,107	-	-	-	-	-	-
WEB S.A.	3,003	-	-	-	-	-	-
Area Santa Cruz II U.T.E.	-	-	1,472	-	-	-	-
Total	31,283	405,060	21,461	6,522	210	32,880	206

11. SUBSIDIARY AND AFFILIATES

Telcosur:

The corporate purpose of Telcosur is to render telecommunication services. Telcosur was created to assure the optimal utilization of TGS’s telecommunication system. TGS’s equity interest in the company is 99.98% and the remaining 0.02% is held by Petrobras Energía Internacional S.A.

Link:

Link was created in February 2001, with the purpose of the operation of a natural gas transportation system, which links TGS’s gas transportation system with Gasoducto Cruz del Sur S.A. pipeline. The connection pipeline extends from Buchanan, located in the high-pressure ring that surrounds the city of Buenos Aires, which is part of TGS’s pipeline system, to Punta Lara. TGS’s ownership interest in such company is 49% and Dinarel S.A. holds the remaining 51%.

TGU:

TGU is a company incorporated in Uruguay. This company renders operation and maintenance services to Gasoducto Cruz del Sur S.A. pipeline in the Uruguayan pipeline tranche. TGS holds the 49% of its common stock.

EGS:

In September 2003, EGS, a company registered in Argentina, was incorporated. The ownership is distributed between TGS (49%) and TGU (51%). EGS operates its own pipeline which connects TGS’s main pipeline system in the Province of Santa Cruz with a delivery point on the border with Chile.

Transportadora de Gás e Serviços do Brasil S.A.:

In January 2007, TGS and TGU entrusted their legal attorneys in Brazil the incorporation of a Brazilian company with the aim to set up new businesses in this country. At the date of the issuance of these financial statements, its shareholders have made no capital contributions to this subsidiary. The corporate name is Transportadora de Gás e Serviços do Brasil S.A.

12. DIFFERENCES BETWEEN ARGENTINE GAAP AND US GAAP

The accompanying consolidated financial statements have been prepared in accordance with Argentine GAAP, which differ in certain significant respects from US GAAP. Such differences involve methods of measuring the amounts shown in the consolidated financial statements, as well as additional disclosures required by US GAAP and Regulation S-X of the SEC.

I. Differences in measurement methods            

The following reconciliation to US GAAP does not include an elimination of the adjustments to the consolidated financial statements to account for the effects of inflation required under Argentine TR No. 6, (as amended by TR No. 19), as permitted by Regulation S-X of the SEC.

The principal differences, other than inflation accounting, between Argentine GAAP and US GAAP as they relate to the Company are described below, together with an explanation, where appropriate, of the method used in the determination of the necessary adjustments.

	Year ended December 31,
		2007	2006	2005
Reconciliation of net income:
Net income under Argentine GAAP		147,508	358,022	217,507
US GAAP adjustments:
Capitalization of interest cost, net (Note 12.a)		(1,774)	(425)	(2,902)
Intangible assets (Note 12.b and g)		(3,661)	(1,309)	9,635
Interest rate lock agreements (Note 12.g)		(5,322)	(1,903)	(1,035)
Deferred income tax under US GAAP (Note 12.c)		15,934	24,828	26,560
Non-current investment in unconsolidated affiliated companies (Note 12.d)		(2,349)	199	35
Capitalized foreign exchange differences (Note 12.e)		7,524	7,522	7,521
Discounted value of certain receivables (Note 12.f)		-	(2,003)	(102)
Troubled debt restructuring (Note 12.g)		61,696	22,060	11,992
Accounting for current investments (Note 12.h)		-	(1,409)	1,409
Net income under US GAAP		219,556	405,582	270,620

Earnings per share:	2007	2006	2005
Amounts under US GAAP	0.28	0.51	0.34
Earnings per ADS:
Amounts under US GAAP	1.38	2.55	1.70

	As of December 31,
	2007	2006
Reconciliation of shareholders’ equity:
Shareholders’ equity under Argentine GAAP	2,929,547	2,782,129
US GAAP adjustments:
Capitalization of interest cost (Note 12.a)	8,094	9,868
Intangible assets (Note 12.b and g)	-	3,661
Deferred income tax under US GAAP (Note 12.c)	(644,751)	(658,822)
Non-current investments in unconsolidated affiliated companies (Note 12.d)	(3,307)	(958)
Capitalized foreign exchange differences (Note 12.e)	(131,160)	(138,684)
Troubled debt restructuring (Note 12.g)	-	(61,696)
Shareholders’ equity under US GAAP	2,158,423	1,935,498

F-18

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

Description of changes in shareholders’ equity under US GAAP:

	For the years ended December 31,
	2007	2006
Shareholders’ equity under US GAAP as of the beginning of the year	1,935,498	1,527,763
Other comprehensive income	3,369	2,153
Net income under US GAAP	219,556	405,582
Shareholders’ equity under US GAAP as of the end of the year	2,158,423	1,935,498

a)

Capitalization of interest cost

Under Argentine GAAP, the Company capitalized financial costs comprising of interest and exchange differences amounting to Ps. 5,053, Ps. 2,622 and Ps. 6,294 for the years ended December 31, 2007, 2006 and 2005, respectively.

Under US GAAP, the Company applied the provisions of Statement of Financial Accounting Standards (“SFAS”) No. 34, “Capitalization of Interest Cost”, which requires interest capitalization on assets which have a period of time to get them ready for their intended use. Capitalization of foreign exchange differences is not allowed under SFAS No. 34.

The US GAAP reconciling item represents the net effect of (i) reversing the total financial costs capitalized under Argentine GAAP net of its corresponding accumulated depreciation (Ps. 12,825 and Ps. 8,320 for the years ended December 31, 2007 and 2006, respectively) and (ii) computing interest capitalization in accordance with SFAS No. 34. net of its corresponding accumulated depreciation (Ps. 20,919 and Ps. 18,188 for the years ended December 31, 2007 and 2006, respectively).

b)

Intangible assets

Under Argentine GAAP, the Company capitalized cancellation costs of assumed commitments, organization and pre-operating costs (including costs associated with voluntary retirement programs) incurred in the start-up of the Company. These costs were being amortized under the straight-line basis over 35 years until December 31, 2000. As from January 1, 2001, the unamortized deferred costs were amortized under the straight-line basis over a 5-year period. Consequently, as of December 31, 2005, these costs were fully amortized. Under US GAAP, these costs were expensed as incurred.

Additionally, under Argentine GAAP and US GAAP, issuance costs of debts which were restructured in December 2004 were capitalized when they were incurred. Under Argentine GAAP, the unamortized issuance costs as of date of the debt restructuring were charged to expense. Under US GAAP, these unamortized costs were amortized during the term of the restructured debt until it was cancelled in June 2007, following the provisions contained in SFAS No. 15. The unamortized costs as of June 2007, were expensed.

c)

Deferred income tax

During the years ended December 31, 2007, 2006 and 2005, under Argentine GAAP, the Company has calculated income taxes using the deferred tax method, which requires the recognition of the tax consequences of temporary differences between the financial statement carrying amounts and the tax basis of existing assets and liabilities. This standard is similar to the principles of US GAAP set forth in SFAS No. 109, “Accounting for Income Taxes”.

However, under Argentine GAAP, the Company has treated the differences between the price-level restated amounts of assets and liabilities and their historical basis as permanent differences for deferred income tax calculation purposes in accordance with Resolution MD No.11/2003 issued by the CPCECABA. Under US GAAP, the Company applies EITF 93-9, “Application of FASB Statement No. 109 in Foreign Financial Statements Restated for General Price-Level Changes”, which requires such differences to be treated as temporary differences in calculating deferred income taxes.

As discussed in note 2.c), effective January 1, 2006 the Company applied the new accounting standards issued by the CPCECABA and adopted by the CNV. The new standards provide for the accounting treatment of differences between the tax basis and book basis of non-monetary items for deferred income tax calculation purposes when companies prepare price-level restated financial statements. The new accounting mandates companies to treat these differences as temporary differences. However, the standard allows a one-time accommodation to continue treating the differences between the tax basis and indexed book basis of non-monetary items as permanent at the time of adoption of the standard. As such, the Company elected to continue treating differences as permanent.

In addition, the US GAAP adjustment includes the effect on deferred income taxes of the reconciling items, as appropriate.

On January 1, 2007, the Company has adopted FASB Interpretation No. 48, “Accounting for Uncertainty in Income Taxes – an Interpretation of FASB Statement No. 109,” (“FIN 48”). FIN 48 prescribes a comprehensive model for how a company should recognize, measure, present, and disclose in its financial statements, uncertain tax positions that it has taken or expects to take on a tax return. This Interpretation requires that a company recognize in its financial statements the impact of tax positions that meet a “more likely than not” threshold, based on the technical merits of the position. The tax benefits recognized in the financial statements from such a position should be measured based on the largest benefit that has a greater than fifty percent likelihood of being realized upon ultimate settlement. As of the date of the adoption of FIN 48, the Company has no material unrecognized tax benefit which would favorably affect the effective income tax rate in future periods and do not believe there will be any significant increases or decreases within the next twelve months. The Company has elected to classify interest and penalties related to unrecognized tax benefits, if and when required, as part of income tax expense in the consolidated statements of operations.  No interest or penalties have been accrued at the date of adoption. 

Additionally, effective January 1, 2007, the Company has adopted FSP No. FIN 48-1, “Definition of Settlement in FASB Interpretation No. 48,” (FSP FIN 48-1), which was issued on May 2, 2007. FSP FIN 48-1 amends FIN 48 to provide guidance on how an entity should determine whether a tax position is effectively settled for the purpose of recognizing previously unrecognized tax benefits. FSP FIN 48-1 clarifies that a tax position can be effectively settled upon the completion of an examination by a taxing authority without being legally extinguished. For tax positions considered effectively settled, an entity would recognize the full amount of tax benefit, even if the tax position is not considered more likely than not to be sustained based solely on the basis of its technical merits and the statute of limitations remains open. The adoption of FSP FIN 48-1 did not have an impact on TGS’s consolidated financial state ments.

The Company and its subsidiary file income tax returns only in Argentina due to the fact that Taxable income was generated from argente companies TGS is no longer subject to income tax examinations by tax authorities for years prior to 2002.

d)

Non-current investments in unconsolidated affiliated companies

The Company has assessed the impact of US GAAP adjustments for its equity investees. As a consequence of this assessment, the Company recognized a net (loss) / gain of (Ps. 2.3 million), Ps. 0.2 million and Ps. nil for the years ended December 31, 2007, 2006 and 2005, respectively. This adjustment relates to the reversal, under US GAAP, of capitalized foreign exchange differences, the discount of certain receivables and the impairment of long-lived assets, as well as the application of SFAS No.109 for the recognition of income taxes.

e)

Capitalized foreign exchange differences

As discussed in Note 2.j), under Argentine GAAP, the Company capitalized the foreign exchange loss derived from the devaluation of the peso as from January 6, 2002 to July 28, 2003, amounting to Ps. 177.3 million. The amortization expense amounted to Ps. 7.5 million for each year ended December 31, 2007, 2006 and 2005. Under US GAAP, such foreign exchange loss was charged to income every year.

f)

Discounted value of certain receivables

Argentine GAAP requires that long term receivables and liabilities (except for deferred tax assets and liabilities and asset tax credit) be valued based on the best estimate of the discounted value of amounts expected to be collected or paid, as applicable. Accordingly, the Company recorded an adjustment for Ps. 2.0 million and Ps. 0.1 million in fiscal years 2006 and 2005, respectively, over the nominal value of long term tax credits. Those adjustments were reversed for US GAAP purposes. In fiscal year 2006, under Argentine GAAP, the asset tax credit discount was reversed, in accordance with an accounting rule interpretation issued in 2006.

g)

Troubled debt restructuring

As mentioned in Note 6, on December 15, 2004, TGS concluded its debt restructuring process. Under Argentine GAAP the Company followed the provisions contained in TR No. 17 and, accordingly, recorded a Ps. 76.5 million gain on restructuring due to the forgiveness of default interest and a Ps. 20.1 million gain related to a decrease in interest rates applied retroactively as from January 1, 2004. In addition, the unamortized arrangement costs for the issuance of debt associated with Global Programs and debt issuance costs as of December 15, 2004 (amounted to Ps. 5.7 million) were expensed to statement of income, as well as the unamortized losses related to interest rate lock agreement as of this date (Ps. 8.3 million).

Under US GAAP, the Company followed the provisions contained in SFAS No. 15 which states that in the case of a troubled debt restructuring (as this term is defined by SFAS No. 15) involving a cash payment and a modification of terms, a debtor shall reduce the carrying amount of the payable by the total fair value of the assets transferred and no gain on restructuring of payables shall be recognized unless the remaining carrying amount of the payable exceeds the total future cash payments (including amounts contingently payable) specified by the terms of the debt remaining unsettled after the restructuring. Future interest expense, if any, shall be determined by applying the interest rate that equates the present value of the future cash payments specified by the new terms (excluding amounts contingently payable) with the carrying amount of the payable. Based on the above, as of December 31, 2004, no gain and loss on restructuring had been recorded by the Company under US GAAP and those gains and losses recorded under Argentine GAAP were amortized as adjustments to interest expensed during the term of the restructured debt until it was cancelled in June 2007, when the unamortized amounts were recorded in the Statement of Income.

h)

Accounting for current investments

As of December 31, 2005, the Company had government bonds which were sold in 2006. Under Argentine GAAP, these investments were valued at fair value with unrealized losses of Ps. 1.4 million charged to income.

Under US GAAP, the Company classified these investments as available-for-sale and valued them at market value with unrealized losses recorded in accumulated other comprehensive loss, in accordance with SFAS No. 115 “Accounting for Certain Investments in Debt and Equity Securities”. In 2006, the unrealized losses as of December 31, 2005, were expensed.

The Company has classified its mutual funds investments as trading securities which are reported at fair value with gains and losses reported in earnings.

i)

Valuation of property, plant and equipment

Under Argentine GAAP, assets transferred through the privatization of GdE were valued as described in Note 2.j). Under US GAAP, Accounting Principles Board Opinion No. 16 “Business Combinations” provides guidance for the valuation of property, plant and equipment in connection with an acquisition. As CIESA acquired 70% of the common stock of TGS, the fixed assets transferred should have been valued at the price effectively paid for that 70%, plus the inflation adjusted historical cost carried by GdE for the remaining 30%. The condition of GdE’s books and records, specifically that no separate financial statements or financial information was kept with respect to transportation operations or the operation of assets transferred to TGS, and the unavailability of any 1992 GdE financial information made it impossible to determine historical cost. TGS’ management believes, based on information maintained by the Argen tine government Public Notary, that the fair value of the transferred assets recorded on its books was significantly below the 1991 GdE historical book values brought forward to 1992 and restated in constant Argentine pesos at the Transfer Date. Therefore, no adjustment has been recorded in the US GAAP reconciliation related to the valuation of property, plant and equipment.

In accordance with SFAS No. 144, “Accounting for the Impairment or Disposal of Long-Lived Assets”, the Company periodically evaluates the carrying value of its long-lived assets for impairment. The carrying value of a long-lived asset is considered impaired by the Company when the expected undiscounted cash flows from such asset is separately identifiable and less than its carrying value. In that event, a loss would be recognized based on the amount by which the carrying value exceeds the fair market value of the long-lived asset. Fair market value is determined primarily using the anticipated cash flows discounted at a rate commensurate with the risk involved or based on independent appraisals.

As of December 31, 2007, under Argentine GAAP and US GAAP, the Company has recorded an impairment of Ps. 19.6 million in order to expense the total carrying amount of certain turbines as they became obsolete. No impairment losses have been recognized for 2006 and 2005.

II. Additional disclosure requirements

a)

Balance sheet classification differences:

Under Argentine GAAP, in accordance with the provisions contained in TR No. 9, net deferred tax assets (liabilities) are to be classified as non-current assets (liabilities). Under US GAAP, the Company applied the provisions contained in SFAS No. 109, which states that in a classified statement of financial position, an enterprise shall separate deferred tax liabilities and assets into a current amount and a non-current amount. Deferred tax liabilities and assets shall be classified as current or non-current based on the classification of the related asset or liability for financial reporting.  

b)

Statement of income classification differences:

Argentine GAAP provides that only returns and other allowances are deducted from net revenues, while direct taxes and other costs directly associated with revenues should be presented as operating costs, i.e. gross revenue taxes. Under US GAAP, direct taxes and other costs directly associated with revenues are deducted from revenues.

In 2007, TGS recorded a long-lived asset impairment of Ps. 19.6 million to reflect the obsolescence of some turbines. Under Argentine GAAP, in accordance with the provisions contained in TR No. 9, this loss was charged to "Net financial results". Under US GAAP, the long-lived asset impairment is presented as operating costs.

c)

Comprehensive income:

SFAS No. 130, “Reporting Comprehensive Income” establishes guidelines for the reporting and display of comprehensive income and its components in a full set of general-purpose financial statements. Comprehensive income represents the change in shareholders’ equity of the Company during the period from transactions and other events and circumstances from non-owner sources. It includes all changes in equity during a period except those resulting from investments by owners and distributions to owners.

F-19

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

 The following table summarizes the components of comprehensive income for the years ended December 31, 2007, 2006 and 2005:

	2007		2006	2005
Net income under US GAAP		219,556	405,582	270,620
Other comprehensive income:
Amortization of costs on interest rate lock agreements accounted for as cash flow hedges (net of income taxes of Ps. 1,863, Ps. 666 and Ps. 362 at December 31, 2007, 2006 and 2005, respectively)		3,369	1,237	673
Unrealized gains and losses – Available for sale securities -(net of income taxes of Ps. 493and Ps. 493 at December 31, 2006 and 2005 respectively)		-	916	(916)
Comprehensive income		222,925	407,735	270,377

Accumulated other comprehensive loss at December 31, 2007, 2006 and 2005, was as follows:

	2007	2006	2005
Deferred costs on interest rate lock agreements accounted for as cash flow hedges	(90)	(3,459)	(4,696)
Unrealized gains and losses - Available for sale securities -	-	-	(916)
Accumulated other comprehensive loss	(90)	(3,459)	(5,612)

d)

Separate presentation of Shareholders’ equity components:

The following table presents the shareholder’s equity components under US GAAP.

	Year ended December 31,
	2007	2006	2005
Common Stock - Class “A” 405,192,594 shares issued and   outstanding, Ps.1 par value	405,192	405,192	405,192
Common Stock - Class “B” 389,302,689 shares issued and outstanding, Ps.1 par value.	389,303	389,303	389,303
Total Common Stock	794,495	794,495	794,495
Inflation adjustment to common stock	1,145,012	1,145,012	1,145,012
Legal reserve	183,222	165,321	154,446
Accumulated retained earnings / (deficit )	35,784	(165,871)	(560,578)
Accumulated other comprehensive loss	(90)	(3,459)	(5,612)
Shareholders' equity under US GAAP	2,158,423	1,935,498	1,527,763

F-20

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

e)

Deferred income taxes:

The components of the net deferred tax liability under US GAAP as of December 31, 2007 and 2006, are the following:

	2007	2006
Deferred tax assets
Allowance for doubtful accounts	27	98
Present value other receivables	38	5,769
Present value advanced payments from clients	-	451
Provision for contingencies	16,838	17,547
Other provisions	869	835
Accrued interest from loans	-	18,221
Labor provisions	3,120	1,532
Deferred income for troubled debt restructuring and long term debt valuation	-	21,593
Tax loss carryforwards	-	110,750
Foreign exchange loss generated by current investments	177	651
	21,069	177,447
Deferred tax liabilities
Property, plant and equipment, net	722,446	760,746
Intangible assets	-	1,281
Deferred revenues	683	744
	723,129	762,771
Net deferred tax liability	(702,060)	(585,324)

As of December 31, 2007 and 2006, Ps.4,204 and Ps. 119,536, respectively, were classified as current assets, and Ps. 723,129 and Ps. 762,751, respectively,were classified as non-current liabilities.

Income tax expense for the years ended December 31, 2007, 2006 and 2005 consist of the following:

	2007		2006		2005
Current income tax expense		16,205		1,714		611
Deferred income tax expense / (benefit)		114,873		(4,651)		(14,356)
Income tax expense / (benefit)		131,078		(2,937)		(13,745)

Income tax benefit computed at the statutory tax rate (35%) on pre-tax income differs from the income tax benefit for the years ended December 31, 2007, 2006 and 2005 computed in accordance with US GAAP as follows:

	2007	2006	2005
Income tax expense at statutory tax rate on pre-tax income in accordance with US GAAP	122,722	140,926	89,906
Permanent differences:
Change in valuation allowance	-	(144,549)	(101,362)
Tax adjustments and others, net	8,356	686	(2,289)
Income tax expense / (benefit)	131,078	(2,937)	(13,745)

f)

Summarized financial information under US GAAP

Presented below is the summarized consolidated balance sheet and consolidated statement of income information of the Company as of and for the years ended December 31, 2007 and 2006, prepared in accordance with US GAAP, giving

F-21

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

effect to differences in measurement methods and disclosures as previously discussed.

	2007	2006
Current assets	687,377	831,378
Non-current assets	4,209,003	4,285,701
Total assets	4,896,380	5,117,079
Current liabilities	312,741	378,768
Non-current liabilities	2,425,215	2,802,811
Total liabilities	2,737,956	3,181,579
Minority interest	1	2
Shareholders’ equity under US GAAP	2,158,423	1,935,498

	2007	2006	2005
Net revenues	1,178,558	1,238,764	1,003,506
Cost of sales	(651,701)	(616,774)	(509,950)
Gross profits	526,857	621,990	493,556
Administrative expenses	(42,825)	(38,263)	(28,645)
Selling expenses	(7,059)	(6,439)	(4,858)
Operating Income	476,973	577,288	460,053
Other expenses, net	(2,594)	(731)	(6,110)
(Loss) / gain on related companies	(1,759)	(243)	2,642
Net financial results	(121,986)	(173,668)	(199,710)
Income before income tax	350,634	402,646	256,875
Income tax (expense) / benefit	(131,078)	2,937	13,745
Minority interest	-	(1)	-
Net income	219,556	405,582	270,620

g)

Disclosure about fair value of financial instruments

SFAS No. 107, “Disclosures About Fair Value of Financial Instruments”, requires disclosure of fair value information about financial instruments whether or not recognized in the balance sheet, for which it is practicable to estimate fair value. Financial instruments include such items as cash and cash equivalents and accounts receivable and other instruments. SFAS No. 107 excludes from its disclosure requirements certain significant assets and liabilities that are not considered to be financial instruments. SFAS No. 133, which is effective January 1, 2001, amends SFAS No. 107 to include within the scope of such statement certain disclosure requirements regarding credit risk concentrations.

Fair value estimates are made as of a specific point in time based on the characteristics of the financial instruments and the relevant market information. When available, quoted market prices are used. In other cases, fair values are based on estimates using other valuation techniques, such as discounting estimated future cash flows using a rate commensurate with the risks involved or other acceptable methods. These techniques involve uncertainties and are significantly affected by the assumptions used and the judgements made regarding risk characteristics of various financial instruments, prepayments, discount rates, estimates of future cash flows, future expected loss experience, and other factors. Changes in assumptions could significantly affect these estimates. Derived fair value estimates cannot be substantiated by comparison to independent markets and, in many cases, could not be realized in an immediate sale of the instru ment. Also, because of differences in methodologies and assumptions used to estimate fair value, the Company's fair values should not be compared to those of other companies.

Under SFAS No. 107, fair value estimates are based on existing financial instruments without attempting to estimate the value of anticipated future business and the value of assets and liabilities that are not considered financial instruments. Accordingly, the aggregate fair value amount presented does not represent the underlying value of the Company. For certain assets and liabilities, the information required under the SFAS No. 107 is supplemental with additional information relevant to an understanding of the fair value.

As of December 31, 2007 and 2006, the carrying amount of certain financial instruments used by the Company including cash, cash equivalents, receivables, payables and short term loans are representative of fair value because of the short-term nature of these instruments. The estimated fair value of other non-current assets does not differ significantly from the carrying amount. The estimated fair value of long-term debt is based on their quoted market prices.

The following table reflects the carrying amount and estimated fair value of the Company´s financial debt at December 31, 2007 and 2006:

	2007		2006
	Carrying amount	Fair value	Carrying amount	Fair value
	(in million of Pesos)
Long term debt	1,590	1,370	2,013	1,988

h)

Disclosure of capital lease information

The Company leases telecommunication equipment under capital lease agreements with a lease term of 60 months. Following is a summary of the assets under capital leases:

	As of December 31, 2007
Original cost	23,152
Less:
Accumulated depreciation	(13,837)
Net leased property	9,315

Future minimum lease payments for the above assets under capital leases as of December 31, 2007 are as follows:

	2007
2008		734
Total minimum obligations		734
Interest		(5)
Present value of minimum obligations		729
Current portion		(729)
Non-current portion as of December 31, 2007		-

i)

Earnings per share

In accordance with the disclosure requirements established by Argentine GAAP, the Company is required to disclose earnings per share information for each year for which a statement of income is presented. However, the information disclosed by the Company in its primary financial statements derives from figures calculated in accordance with the valuation criteria established by Argentine GAAP. Under US GAAP, basic and diluted earnings per share are presented in conformity with SFAS No. 128 “Earnings per Share” for all periods presented.

Basic earnings per share is computed by dividing the net income available to common shareholders for the period by the weighted average shares of common stock outstanding during the period. Diluted net income per share is computed by dividing the net income for the period by the weighted average number of common and dilutive potential common shares outstanding during the period. Pursuant to SAB No. 98, ordinary shares and convertible preferred shares issued or granted for nominal consideration prior to the anticipated effective date of an initial public offering must be included in the calculation of basic and diluted net income per share as if they had been outstanding for all periods presented. To date, the Company has not had any issuance or grants for nominal consideration.

Since the Company has no dilutive potential common stock outstanding, there are no dilutive earnings per share amounts as described in SFAS No. 128.

j)

Statement of cash flows classification differences

The statements of cash flows presented in the primary financial statements are prepared based on Argentine GAAP amounts.

Under Argentine GAAP, the Company considers all short-term, highly liquid investments that are readily convertible to known amounts of cash and with original maturities of three months or less to be cash equivalents. Under Argentine GAAP, mutual funds are considered to be cash equivalents since original maturity is determined by reference to the frequency with which liquidity is available according to current Argentine GAAP guidance and practice. However, under SFAS No. 95 “Statement of Cash Flows”, the original maturity is determined by reference to the stated term of the security or the timeframe for exercising any put features to the issuer, not by reference to the frequency with which liquidity may be available through an auction, a put feature to a third party, or otherwise.

As a result, differences exist between the total amount of the increase or decrease in cash and cash equivalents reported in the primary financial statements and the same totals that would be reported in a statement of cash flows prepared based on US GAAP amounts.

Under US GAAP, the total amounts of cash and cash equivalents at the beginning and end of the years shown in the statement of cash flows are required to be the same amounts as similarly titled line items shown in the balance sheets as of those dates. The following tables set forth the amounts of cash and cash equivalents at the beginning and end of each year and corresponding increases and/or decreases that would be reported in a statement of cash flows prepared in accordance with US GAAP:

	For the year ended December 31,
	2007	2006	2005
Cash and banks	2,816	6,583	2,418
Current investments	421,102	471,673	510,526
Less:
Mutual funds and other current investments	(150,826)	(230,425)	(153,709)
Cash and cash equivalents at the end of the year under US GAAP	273,092	247,831	359,235

	Years ended December 31,
	2007	2006	2005
(Decrease) Increase in cash and cash equivalents under US GAAP	25,261	(111,404)	339,687
Cash and cash equivalents at the beginning of the year	247,831	359,235	19,548
Cash and cash equivalents at the end of the year	273,092	247,831	359,235

In addition, differences exist between cash flows from operating, investing and financing activities reported in the primary financial statements and the cash flows from operating, investing and financing activities that would be reported under SFAS No. 95.

Under Argentine GAAP, advance payments from customers were reported as financing activities whereas these transactions would be classified as cash flows from operating activities for US GAAP purposes. Additionally, due to the difference in the definition of cash and cash equivalents, cash flows from purchasing and selling of mutual funds and other current investments would be reported as cash flows from operating and investing activities, respectively, under US GAAP.

In addition, under Argentine GAAP the effect of inflation and exchange rate changes on cash and cash equivalents were not disclosed by presenting a fourth cash flow statement category as required by US GAAP.

F-22

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

The following tables set forth the condensed statements of cash flows prepared in accordance with US GAAP:

	For the year ended December 31,
	2007	2006	2005
Cash flows provided by operating activities	721,474	568,830	756,780
Cash flows used in investing activities	(231,951)	(117,057)	(175,212)
Cash flows used in financing activities	(463,606)	(562,309)	(254,961)
Effect of foreign exchange rate changes on cash and cash equivalents	(656)	(868)	13,080
Increase / (decrease) in cash and cash equivalents	25,261	(111,404)	339,687
Cash and cash equivalents at the beginning of the year	247,831	359,235	19,548
Cash and cash equivalents at the end of the year	273,092	247,831	359,235

k)

Capitalization of interest cost

Details regarding the amount of the total interest and the effect of capitalized interest for the years ended December 31, 2007, 2006 and 2005 are as follows:

	December 31,
	2007	2006	2005
Total interest under US GAAP	161,166	177,448	180,469
- Capitalized interest under US GAAP	(3,701)	(2,561)	(3,392)
Total Interest charged to net income under US GAAP	157,465	174,887	177,077

l)

Accounting pronouncements issued but not yet adopted

1.

Fair value measurements

In September 2006, the FASB issued SFAS No. 157 “Fair value measurements” establishing a framework for measuring fair value in generally accepted accounting principles, and expands disclosures about fair value measurements. This Statement applies under other accounting pronouncements that require or permit fair value measurements, the Board having previously concluded in those accounting pronouncements that fair value is the relevant measurement attribute. Accordingly, this Statement does not require any new fair value measurements. The changes to current practice resulting from the application of this Statement relate to the definition of fair value, the methods used to measure fair value, and the expanded disclosures about fair value measurements. A single definition of fair value, together with a framework for measuring fair value, should result in increased consistency and comparability in fair v alue measurements. The expanded disclosures about the use of fair value to measure assets and liabilities should provide users of financial statements with better information about the extent to which fair value is used to measure recognized assets and liabilities, the inputs used to develop the measurements, and the effect of certain of the measurements on earnings (or changes in net assets) for the period. This Statement is effective for financial statements issued for fiscal years beginning after November 15, 2007, and interim periods within those fiscal years. In February 2008, the FASB approved FSP FAS 157-2, which grants a one-year deferral of SFAS No. 157 fair value measurement requirements for non-financial assets and liabilities, except for items that are recognized or disclosed at fair value on a recurring basis.The Company is currently evaluating the impact of SFAS No. 157 on its financial position and result of operations.

F-23

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

2.

Fair value option  for financial assets and financial liabilities

In February 2007, the FASB issued SFAS No. 159, “The fair value option for financial assets and financial liabilities”. SFAS No. 159 establishes a fair value option under which entities can irrevocably elect to report certain financial asset and liabilities at fair value, with changes in fair value recognized in earnings at each subsequent reporting date. SFAS No. 159 is effective for fiscal years beginning after November 15, 2007. The Company will evaluate the impact of SFAS No. 159 on its financial statements.

3.

Noncontrolling interest in consolidated financial statements

In December 2007, the FASB issued SFAS No. 160, “Noncontrolling interest in consolidated financial statements”. This statement amends Accounting Research Bulletin No. 51, “Consolidated Financial Statements” to establish accounting and reporting standards for the noncontrolling interest in subsidiaries and requires non-controlling interest to be treated as a separate component of equity. SFAS No. 160 is effective for fiscal years, and interim periods within those fiscal years, beginning on or after December 15, 2008. Early adoption is prohibited. This statement shall be applied prospectively as of the beginning of the fiscal year in which it is initially adopted, except for the presentation and disclosure requirements which shall be applied retrospectively. The Company will evaluate the impact of SFAS No. 160 on its financial statements.

4.

Disclosures about derivative instruments and hedging activities an amendment of SFAS No. 133

In March 2008, the FASB issued SFAS No. 161, “Disclosures about derivative instruments and hedging activities an amendment of SFAS No. 133”. This Statement requires enhanced disclosures about an entity’s derivative and hedging activities to provide information about (a) how and why an entity uses derivative instruments, (b) how derivative instruments and related hedged items are accounted for under SFAS No. 133 and its related interpretation, and (c) how derivative instruments and related hedged items affected an entity’s financial position, financial performance, and cash flows. This Statement is effective prospectively for financial statements issued for fiscal years and interim periods beginning after November 15, 2008, with early application encouraged. The Company will evaluate the impact of SFAS No. 161 on its financial statements.

5.

The hierarchy of generally accepted accounting principles

In May 2008, SFAS No. 162 “The hierarchy of generally accepted accounting principles” was issued by the FASB. This sets out the framework for selecting accounting principles to be used in preparing financial statements that are presented in conformity with US GAAP. Up to now, the US GAAP hierarchy has been defined in the US auditing literature. Because of the interrelationship with the auditing literature, SFAS 162 will be effective 60 days following the SEC’s approval of the PCAOB’s amendments to their auditing standards. The Company will evaluate the impact of SFAS No. 162 on its financial statements.

13. SUBSEQUENT EVENT

The Ordinary Shareholders’ Meeting held on April 10, 2008 approved a Ps. 32 million dividend payment (Ps. 0.040 per share or Ps. 0.201 per ADS) which was paid on May 7, 2008.

Regarding Note 9.f), on February 25, 2008, TGS filed a motion to dismiss before the BCRA requesting the dismissal of the summary proceedings on the grounds of lack of foreign exchange violation.

F-24

TRANSPORTADORA DE GAS DEL SUR S.A.

NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS

FOR THE YEARS ENDED DECEMBER 31, 2007, 2006 AND 2005

(Amounts stated in thousands of Argentine pesos as described in Note 2.b.,

except for per share and per ADS amounts in Argentine pesos or unless otherwise indicated)

14. OTHER CONSOLIDATED FINANCIAL STATEMENTS INFORMATION

The following tables present additional consolidated financial statement disclosures required by Argentine GAAP:

a)

Property, plant and equipment, net

b)

Intangible assets, net

c)

Non-current investments

d)

Current investments

e)

Allowances and provisions

f)

Cost of sales

g)

Foreign currency assets and liabilities

h)

Expenses incurred

i)

Detail of maturities of investments, receivables and liabilities.

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F-47

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F-53

SIGNATURES

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.

Transportadora de Gas del Sur S.A.

By:	/s/Gonzalo Castro Olivera
		Name:	Gonzalo Castro Olivera
		Title:	Chief Financial Officer

By:	/s/Carlos Ariosa
		Name:	Carlos Ariosa
		Title:	Senior Legal Counsel

F-53