PPENF Pampa Energia SA (PK)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

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FORM 6-K/A

 

REPORT OF FOREIGN ISSUER
PURSUANT TO RULE 13a-16 OR 15d-16 UNDER

SECURITIES EXCHANGE ACT OF 1934

 

For the month of May, 2024

(Commission File No. 001-34429),

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PAMPA ENERGIA S.A.
(PAMPA ENERGY INC.)

 

Argentina

(Jurisdiction of incorporation or organization)

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Maipú 1
C1084ABA
City of Buenos Aires
Argentina

(Address of principal executive offices)

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(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 Rule 12g3-2(b) under
the Securities Exchange Act of 1934.)

Yes ______ No ___X___

(If "Yes" is marked, indicate below the file number assigned to the
registrant in connection with Rule 12g3-2(b): 82- .)

 

  

 

This Form 6-K/A for Pampa Energía S.A. (“Pampa” or the “Company”) contains:

Exhibit 1: Earnings Release Q1 24

SIGNATURE

 

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

 

Date: May 8, 2024

 

Pampa Energía S.A.
By:	/s/ Gustavo Mariani
	Name: Gustavo Mariani Title:   Chief Executive Officer

 

 

FORWARD-LOOKING STATEMENTS

 

This press release may contain forward-looking statements. These statements are statements that are not historical facts, and are based on management's current view and estimates offuture economic circumstances, industry conditions, company performance and financial results. The words "anticipates", "believes", "estimates", "expects", "plans" and similar expressions, as they relate to the company, are intended to identify forward-looking statements. Statements regarding the declaration or payment of dividends, the implementation of principal operating and financing strategies and capital expenditure plans, the direction of future operations and the factors or trends affecting financial condition, liquidity or results of operations are examples of forward-looking statements. Such statements reflect the current views of management and are subject to a number of risks and uncertainties. There is no guarantee that the expected events, trends or results will a ctually occur. The statements are based on many assumptions and factors, including general economic and market conditions, industry conditions, and operating factors. Any changes in such assumptions or factors could cause actual results to differ materially from current expectations.

 

 

 

Pampa Energía, an independent company with active participation in the Argentine electricity and gas value chain, announces the results for the quarter ended on March 31, 2024.

 

Stock information   Share capital as of May 6, 2024 1,363.5 million common shares/ 54.5 million ADS Market capitalization AR$3,010 billion/ US$2,705 million Information about the videoconference Date and time Wednesday May 8 10 AM Eastern Standard Time 11 AM Buenos Aires Time Access link bit.ly/Pampa1Q2024VC For further information about Pampa Email investor@pampa.com Website for investors ri.pampa.com Argentina’s Securities and Exchange Commission www.argentina.gob.ar/cnv Securities and Exchange Commission sec.gov

Basis of presentation Pampa’s financial information adopts US$ as functional currency, converted into AR$ at transactional FX. However, Transener and TGS adjust their figures for inflation as of March 31, 2024, which are expressed in US$ at the period’s closing FX. The previously reported figures remain unchanged. Q1 24 main results[1] 7% year-on-year sales decrease, recording US$401 million[2] in Q1 24, explained by a drop in spot energy and petrochemical prices and lower gas exports and crude oil sales, partially offset by higher domestic gas sales due to better demand and the commissioning of GPNK. Operating performance highlighted by growing gas production: Adjusted EBITDA[3] reached US$189 million in Q1 24, an 8% decrease compared to Q1 23, mainly explained by a 22% reduction in power generation due to credit impairment on the January invoice to CAMMESA and a 22% reduction in holding and others, offset by improvements of 14% in oil and gas and 58% in petrochemicals. Net profit attributable to the Company’s shareholders of US$267 million, 89% higher than in Q1 23, mainly explained by higher non-cash credit on deferred income tax due to higher inflation than AR$ devaluation, also positively impacted our affiliates’ equity income. These effects were offset by the impairment of CAMMESA receivables and lower sales and devaluation profit from AR$ debt. Net debt increased to US$718 million, resulting in a net leverage ratio of 1.1x, mainly due to the substantial delays in the payment collections from CAMMESA.

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^[1] The information is based on FS prepared according to IFRS in force in Argentina.

^[2] Sales from the affiliates CTBSA, Transener and TGS are excluded, shown as ‘Results for participation in joint businesses and associates.’

^[3] Consolidated adjusted EBITDA represents the flows before financial items, income tax, depreciations and amortizations, extraordinary and non-cash income and expense, equity income, and includes affiliates’ EBITDA at our ownership. Further information on section 3.1.

1.

Relevant Events

1.1

Increased delays in the payments from CAMMESA and on-time changes in the settlement of certain past transactions

Since February 2024, CAMMESA has slowed down payments for our electricity and natural gas sales. As of today, transactions from December 2023, January and February 2024 are pending payment, totaling over AR$140 billion, including accrued interests and Value-Added Tax. The days of sales outstanding have risen to more than 120 days, whereas CAMMESA’s procedures stipulate 42 days.

The Company has learned that the SE would instruct CAMMESA to make a one-time change over the settlement of the December 2023 and January 2024 transactions by paying the outstanding due with sovereign bonds at face value. In light of this development and considering the fair market value of said debt security, Pampa has recorded a US$34 million impairment loss over CAMMESA receivables.

Pampa is analyzing the possible course of action and the legal measures against this resolution. It is important to highlight that the inability of CAMMESA to pay could substantially impact the Company’s cash flow, operating results and financial position. Nonetheless, Pampa has enough solvency to meet its operational and financial obligations as of the FS issuance date.

1.2

New permits to export natural gas

In February 2024, the SE approved additional gas export volumes to Chile on a ToP basis for 0.6 million m³/day, valid from October to December 2024. In summary:

Period	Volume in million m3/day
	Authorized	Traded
January 2024 – April 2024	1.5	0.8
May 2024 – September 2024	0.6	n.a.
October – December 2024	0.6	n.a.

1.3

Increases in regulated tariffs

Update on the natural gas price

On March 26, 2024, the SE set new PIST values for natural gas, denominated in US$, applicable seasonally from April 2024 to residential users “N1” (high income) and productive sectors (businesses and industries) (Res. SE No. 41/24), resulting in^[4]:

·

April: Between US$2.79 and US$2.95 per MBTU, depending on the utility company

·

May – September (winter period): Between US$4.26 and 4.49 per MBTU, depending on the utility company

·

October – December (summer period): Between US$2.79 and 2.85 per MBTU, depending on the utility company.

As of March 2024, the small businesses segment paid in AR$, equivalent to US$0.3 per MBTU and the residential N1 segment paid in AR$, equivalent to US$1 per MBTU.

The PIST increase will not be seasonal for residential users “N2” (low income/social tariff) and “N3” (middle income):

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^[4] PIST ranges depend on the area and type of user.

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N2: From an equivalent of US$0.3 (denominated in AR$), to 0.74 and 0.78 per MBTU

·

N3: From an equivalent of US$0.4 (denominated in AR$), to 1.12 and 1.17 per MBTU.

Furthermore, ENARGAS was instructed to issue tariff schemes reflecting monthly variations in the FX on PIST values (Res. ENARGAS No. 112 to 123/24).

This price adjustment increases the amount of Pampa’s sales to be charged directly to the utility distribution companies, decreasing the Plan Gas.Ar subsidy contribution.

Tariff increase granted to TGS

On March 27, 2024, ENARGAS authorized a 675% increase in natural gas transportation tariff schemes, effective between April 3, 2024 and any time before December 31, 2024, when a new Comprehensive Tariff Review is approved. Moreover, it includes a monthly adjustment formula (Res. No. 112/24). However, as of today, ENARGAS has not issued the corresponding May 2024 tariff schedules reflecting said monthly increase.

TGS commits to disburse and/or accrue in 2024 an AR$27,690 million investment plan, adjustable by the formula mentioned before, and focused on infrastructure works, as well as the system’s safety and reliability.

1.4

Transener news

Changes in CAMMESA’s payment priority order

On March 15, 2024, Res. SE No. 34/24 modified the payment priority order of CAMMESA’s transactions, ranking senior providers of high-voltage power transmission and main distribution services over power generation companies.

Power transmission Comprehensive Tariff Review

On April 15, 2024, the ENRE, through Res. No. 223/24 approved the 2024 power transmission tariff review program. The companies involved, including Transener and Transba, must submit their proposals before July 31, 2024, and the ENRE must approve the new tariff schedules before December 31, 2024. The approved proposals will be in force for five years from January 1, 2025.

1.5

Other news

Board’s appointments

The shareholders’ meeting of Pampa, dated April 29, 2024, approved the tenure renewal of Marcelo Mindlin, Damián Mindlin and María Carolina Sigwald as executive members, Mauricio Penta as an executive alternate member and Clarisa Vittone as independent alternate member. Furthermore, it appointed Julia Sofía Pomares in replacement of Darío Epstein, and Lucas Sebastián Amado in replacement of María Renata Scafati as independent members. Finally, María Vázquez and Veronica Cheja were appointed in replacement of Diana Mondino and Emilse Juárez, respectively, as independent alternate members.

Arbitration with POSA

On April 3, 2024, the International Chamber of Commerce Court notified the Final Award to the international arbitration brought by POSA against Pampa. In said award, all POSA’s claims were dismissed, except for ordering Pampa to pay 33.60% of the income received and to be obtained under the Leasing Contract with TGS in Río Neuquén block. Likewise, the Court grants Pampa’s counterclaim. The awarded amount, net of Pampa’s awarded counterclaim, was US$25 million plus interests. Having provisioned US$9 million before, US$16 million was accrued in Q1 24.

However, on April 10, 2024, Pampa filed a partial annulment appeal against the Final Award. Consequently, the payment was halted until further ruling.

2.

Financial highlights

2.1

Consolidated balance sheet

Figures in million		As of 03.31.2024			As of 12.31.2023
		AR$	US$ FX 858		AR$	US$ FX 808,45
ASSETS
Property, plant and equipment		2,218,134	2,585		2,056,974	2,544
Intangible assets		82,049	96		77,898	96
Right-of-use assets		22,319	26		17,259	21
Deferred tax asset		11,537	13		2	0
Investments in joint ventures and associates		744,633	868		542,978	672
Financial assets at fair value through profit and loss		29,758	35		28,040	35
Other assets		353	0		349	0
Trade and other receivables		17,136	20		14,524	18
Total non-current assets		3,125,919	3,643		2,738,024	3,387
Inventories		188,184	219		166,023	205
Financial assets at amortized cost		89,312	104		84,749	105
Financial assets at fair value through profit and loss		464,380	541		451,883	559
Derivative financial instruments		265	0		250	0
Trade and other receivables		428,589	500		238,294	295
Cash and cash equivalents		171,577	200		137,973	171
Total current assets		1,342,307	1,564		1,079,172	1,335
Total assets		4,468,226	5,208		3,817,196	4,722
EQUITY
Equity attributable to owners of the company		2,437,711	2,841		1,943,736	2,404
Total equity		2,445,850	2,851		1,950,696	2,413
LIABILITIES
Provisions		150,318	175		119,863	148
Income tax and presumed minimum income tax liabilities		101,955	119		44,614	55
Deferred tax liabilities		89,390	104		240,686	298
Defined benefit plans		19,173	22		13,172	16
Borrowings		1,110,787	1,295		989,182	1,224
Trade and other payables		40,313	47		37,301	46
Total non-current liabilities		1,511,936	1,762		1,444,818	1,787
Provisions		6,186	7		4,649	6
Income tax liabilities		14,009	16		14,026	17
Taxes payables		21,848	25		11,427	14
Defined benefit plans		2,624	3		2,695	3
Salaries and social security payable		13,573	16		15,537	19
Derivative financial instruments		110	0		191	0
Borrowings		230,254	268		181,357	224
Trade and other payables		221,836	259		191,800	237
Total current liabilities		510,440	595		421,682	522
Total liabilities		2,022,376	2,357		1,866,500	2,309
Total liabilities and equity		4,468,226	5,208		3,817,196	4,722

 

2.2

Consolidated income statement

		First quarter
Figures in million		2024			2023
		AR$	US$		AR$	US$
Sales revenue		337,376	401		83,915	431
Domestic sales		274,579	326		67,409	345
Foreign market sales		62,797	75		16,506	86
Cost of sales		(215,183)	(258)		(50,538)	(265)
Gross profit		122,193	143		33,377	166
Selling expenses		(13,580)	(16)		(3,193)	(16)
Administrative expenses		(34,238)	(41)		(8,521)	(41)
Exploration expenses		(82)	-		(48)	-
Other operating income		28,992	35		4,859	23
Other operating expenses		(26,385)	(31)		(3,845)	(20)
Impairment of financial assets		(29,830)	(34)		(80)	-
Recovery/(accrual) of impairment on int. assets & inventories		(32)	-		411	2
Results for part. in joint businesses & associates		51,416	61		3,200	15
Income from the sale of associates		1,458	2		-	-
Operating income		99,912	119		26,160	129
Financial income		1,347	2		193	-
Financial costs		(43,955)	(53)		(14,711)	(76)
Other financial results		43,805	52		14,643	84
Financial results, net		1,197	1		125	8
Profit before tax		101,109	120		26,285	137
Income tax		122,687	148		643	4
Net income for the period		223,796	268		26,928	141
Attributable to the owners of the Company		223,099	267		26,918	141
Attributable to the non-controlling int.		697	1		10	-
Net income per share to shareholders		164.0	0.2		19.5	0.1
Net income per ADR to shareholders		4,101.1	4.9		487.6	2.6
Average outstanding common shares1		1,360			1,380
Outstanding shares by the end of period1		1,360			1,380

Note: 1 It considers the Employee stock-based compensation plan shares, which amounted to 3.9 million common shares as of March 31, 2023 and 2024.

2.3

Cash and financial borrowings

 

As of March 31, 2024, in US$ million		Cash1			Financial debt			Net debt
		Consolidated in FS	Ownership adjusted		Consolidated in FS	Ownership adjusted		Consolidated in FS	Ownership adjusted
Power generation		816	815		578	578		(238)	(237)
Petrochemicals		-	-		-	-		-	-
Holding and others		0	0		-	-		(0)	(0)
Oil and gas		29	28		985	985		956	956
Total under IFRS/Restricted Group		845	844		1,563	1,563		718	719
Affiliates at O/S2		165	165		277	277		112	112
Total with affiliates		1,010	1,009		1,840	1,840		830	831

Note: Financial debt includes accrued interest. 1 It includes cash and cash equivalents, financial assets at fair value with changing results, and investments at amortized cost. 2 Under IFRS, the affiliates CTBSA, Transener and TGS are not consolidated in Pampa.

Debt transactions

As of March 31, 2024, Pampa’s financial debt at the consolidated level under IFRS amounted to US$1,563 million, slightly higher than the end of 2023, mainly explained by the increased delays in CAMMESA’s payments, which rose from 73 to 89 days. Debt issuances were carried out to manage the increased working capital, partially offset by debt repayments. In this sense, net debt amounted to US$718 million, 17% higher than December 2023 but 21% lower year-on-year. The table below shows the gross debt principal breakdown:

Currency	Type of issuance	Amount in million US$	Legislation	% over total gross debt	Avg coupon
US$	US$1	1,092	Foreign	73%	8.4%, primarily fixed
	US$ Cable	105	Argentine	7%	11.6%
	US$ MEP	128	Argentine	9%	5%
AR$	AR$	73	Argentine	5%	89.5%, variable
	US$-link	98	Argentine	7%	0%

The financial debt had an average life of 2.8 years. The chart below shows the principal maturity profile, net of repurchases, in US$ million by the end of Q1 24:

 

Note: The chart only considers Pampa consolidated under IFRS. It does not include affiliates TGS, Transener, and CTBSA.

During Q1 24, Pampa issued the Series 20 CB for US$55.2 million under Argentine law at a 6% rate maturing in March 2026. Moreover, Pampa paid net import financing for US$4 million, short-term bank borrowings for AR$900 million and took bank borrowing for US$50 million. After the quarter’s closing, Pampa borrowed from banks for US$40 million and paid net short-term bank borrowings for AR$25.5 billion and US$5 million in import financing.

Regarding our affiliates, in Q1 24, TGS paid net import financing for US$4 million and short-term bank borrowings for US$18 million. In contrast, Transener paid borrowings for AR$83 million. CTEB paid Series 8 CB for AR$4,236 million. After the quarter’s closing, TGS took import financing for US$2 million, Transener settled borrowings for AR$56 million and CTEB paid short-term bank debt for AR$27,066.

As of today, the Company complies with the covenants established in its debt agreements.

Summary of debt securities

Company In million	Security	Maturity	Amount issued	Amount net of repurchases	Coupon
In US$-Foreign Law
Pampa	CB Series 9 at par & fixed rate	2026	293	179	9.5%
	CB Series 1 at discount & fixed rate	2027	750	597	7.5%
	CB Series 3 at discount & fixed rate	2029	300	293	9.125%
TGS1	CB at discount at fixed rate	2025	500	470	6.75%
In US$-Argentine Law
Pampa	CB Series 20	2026	55.2	55.2	6.00%
In US$-link
Pampa	CB Series 13	2027	98	98	0%
CTEB1	CB Series 4	2024	96	96	0%
	CB Series 6	2025	84	84	0%
	CB Series 9	2026	50	50	0%
In US$-MEP
Pampa	CB Series 16	2025	55.7	55.7	4.99%
	CB Series 18	2025	72.1	72.1	5.00%
In AR$
Pampa	CB Series 15	2024	18,264	18,264	Badlar Privada +2%
	CB Series 19	2025	17,131	17,131	Badlar Privada -1%

Notes: 1 According to IFRS, affiliates are not consolidated in Pampa’s FS.

 

Credit ratings

In April 2024, S&P upgraded CTEB’s local scale rating from “A+” to “AA-” due to its low operational risk and its co-controlling companies’ operational robustness, in addition to a solid debt structure. Pampa holds 50% equity stake in CTBSA, a company whose only asset is CTEB. Moreover, due to the sovereign debt upgrade, S&P moved from “CCC-” to “CCC” Pampa and TGS’s global ratings. The table below shows the risk ratings for Pampa and its subsidiaries:

Company	Agency	Rating
		Global	Local
Pampa	S&P	b-1	na
	Moody's	Caa3	na
	FitchRatings2	B-	AA+ (long-term) A1+ (short-term)
TGS	S&P	CCC	na
	Moody's	Caa3	na
Transener	FitchRatings2	na	A+ (long-term)
CTEB	FitchRatings2	na	AA-

Note: 1 Stand-alone. 2 Local ratings issued by FIX SCR.

3.

Analysis of the Q1 24 results

Breakdown by segment Figures in US$ million	Q1 24			Q1 23			Variation
	Sales	Adjusted EBITDA	Net Income	Sales	Adjusted EBITDA	Net Income	Sales	Adjusted EBITDA	Net Income
Power generation	154	85	197	173	108	96	-11%	-22%	+105%
Oil and Gas	150	70	48	154	62	(1)	-3%	+14%	NA
Petrochemicals	120	11	11	125	7	5	-4%	+58%	+120%
Holding and Others	3	23	11	4	29	41	-25%	-22%	-73%
Eliminations	(26)	-	-	(25)	-	-	+4%	NA	NA
Total	401	189	267	431	206	141	-7%	-8%	+89%

Note: Net income attributable to the Company’s shareholders.

3.1

Reconciliation of consolidated adjusted EBITDA

Reconciliation of adjusted EBITDA, in US$ million		First quarter
		2024	2023
Consolidated operating income		119	129
Consolidated depreciations and amortizations		68	59
EBITDA		187	188
Adjustments from generation segment		1	(2)
Deletion of equity income		(21)	(2)
Deletion of gain from commercial interests		(13)	(11)
Deletion of CAMMESA's debt impairment		17	-
Deletion of PPE activation in operating expenses		1	1
Deletion of provision in hydros		1	4
CTBSA's EBITDA adjusted by ownership		16	7
Adjustments from oil and gas segment		(6)	(2)
Deletion of gain from commercial interests		(6)	(2)
Adjustments from holding & others segment		7	22
Deletion of equity income		(40)	(13)
Deletion of gain from commercial interests		(0)	(0)
Deletion of contigencies provision		16	-
Deletion of intang. assets' impairment/(recovery)		-	(2)
Deletion of the sale of associates		(2)	-
TGS's EBITDA adjusted by ownership		27	28
Transener's EBITDA adjusted by ownership		6	10
Consolidated adjusted EBITDA		189	206
At our ownership		185	202

3.2

Analysis of the power generation segment

Power generation segment, consolidated Figures in US$ million		First quarter
		2024	2023	∆%
Sales revenue		154	173	-11%
Domestic sales		154	173	-11%
Cost of sales		(77)	(84)	-8%
Gross profit		77	89	-13%
Selling expenses		(1)	(1)	-
Administrative expenses		(13)	(12)	+8%
Other operating income		17	18	-6%
Other operating expenses		(3)	(12)	-75%
Impairment of financial assets		(34)	-	NA
Results for participation in joint businesses		21	2	NA
Operating income		64	84	-24%
Finance income		1	-	NA
Finance costs		(17)	(25)	-32%
Other financial results		53	34	+56%
Financial results, net		37	9	NA
Profit before tax		101	93	+9%
Income tax		97	3	NA
Net income for the period		198	96	+106%
Attributable to owners of the Company		197	96	+105%
Attributable to non-controlling interests		1	-	NA
Adjusted EBITDA		85	108	-22%
Adjusted EBITDA at our share ownership		81	104	-22%
Increases in PPE		24	93	-74%
Depreciation and amortization		20	26	-23%

Power generation sales during Q1 24 recorded a decrease of 11% in comparison with Q1 23, mainly explained by lower spot/legacy energy sales, where the sharp AR$ devaluation in December 2023 affected its prices, partially offset by the 74% increase granted from February 2024. Although legacy energy represents 69% of the 5,332 MW operated by Pampa^[5], in Q1 24, it only comprised 31% of the segment’s sales. The decrease caused by the FX jump was particularly visible in the capacity remuneration: the thermal conventional units (GT and ST) were priced at US$3.5 thousand per MW-month (-23% vs. Q1 23 and -4% vs. Q4 23), US$1.6 thousand per MW-month for hydro (-25% vs. Q1 23 and -17% vs. Q4 23), and US$4.5 thousand per MW-month for CCGTs (-30% year-on-year and -1% vs. Q4 23). Only CCGTs benefit from the differential income in US$ (Res. No. 59/2023).

In addition to PEMC’s divestment in Q3 23, sales under contracts were affected by the CTLL TG05’s outage (resumed service in late January), lower dispatch with fuel oil and lower Energía Plus prices. The commissioning of PEPE IV partially offset these effects. Compared to Q4 23, sales increased by 9% due to higher thermal demand after El Niño affected our dispatch through increased water levels and mild weather conditions.

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^[5] Under IFRS the results of the affiliated CTEB (567 MW) are not consolidated in the FS. However, it is an asset co-operated by Pampa, and its EBITDA is incorporated at our ownership in the adjusted EBITDA.

In operating terms, Pampa’s operated power generation increased by 3% vs. Q1 23, in line with the 2% increase in the Argentine power grid. This increase is mainly explained by the commissioning of CTEB’s CCGT in February 2023 (+467 GWh), higher water and irrigation in HINISA and HIDISA due to El Niño effect (+247 GWh), higher dispatch in CTG, CTP and CTGEBA in response to the increased demand (+193 GWh), in addition to the commissioning of PEPE IV (+52 GWh). These increases were partially offset by lower dispatch in CPB, CTPP and CTIW (-516 GWh), CTLL’s outage mentioned before (-162 GWh), and the divestment of PEMC (-83 GWh).

The availability of Pampa’s operated units reached 96.2% in Q1 24, a 353-basis points improvement vs. Q1 23’s 92.6%, mainly due to CTLL, CTG and CPB’s outages in Q1 23. Therefore, a 95.2% thermal availability rate was registered in Q1 24, 470 basis points more than 90.5% from Q1 23.

Power generation's key performance indicators		2024					2023					Variation
		Hydro	Wind	Thermal	Total		Hydro	Wind	Thermal	Total		Hydro	Wind	Thermal	Total
Installed capacity (MW)		938	287	4,107	5,332		938	342	4,097	5,378		-	-16%	+0%	-1%
New capacity (%)		-	100%	33%	31%		-	100%	33%	31%		-	-	+0%	-1%
Market share (%)		2.1%	0.7%	9.4%	12.2%		2.2%	0.8%	9.5%	12.4%		-0%	-0%	-0%	-0%
First quarter
Net generation (GWh)		683	244	5,002	5,928		447	292	5,021	5,760		+53%	-16%	-0%	+3%
Volume sold (GWh)		683	246	5,215	6,144		448	292	5,299	6,038		+52%	-16%	-2%	+2%
Average price (US$/MWh)		11	72	31	31		20	73	31	32		-44%	-2%	+2%	-4%
Average gross margin (US$/MWh)		3	64	20	20		8	64	20	21		-60%	+0%	+5%	-3%

Note: Gross margin before amortization and depreciation. It includes CTEB, operated by Pampa (co-operated by Pampa, 50% equity stake). PEMC was de-consolidated in August 2023.

Without depreciation and amortizations, net operating costs decreased to US$57 million, 12% lower than Q1 23, mainly explained by lower labor, maintenance and power and gas transportation costs in AR$, in addition to higher interests from CAMMESA, due to increase in rate and delays. These effects were partially offset by higher insurance policies and contractors’ costs. Compared to Q4 23, operating costs rose 19%, due to lower electricity purchases to cover contracts in Q4 23 and CAMMESA’s payments were slower.

To reflect the on-time changes in the settlement of CAMMESA’s past transactions described before, we recorded a US$34 million impairment over trade receivables in Q1 24, of which US$17 million corresponds to the January 2024 transaction invoiced to CAMMESA.

Financial results from Q1 24 reached a net profit of US$38 million, higher than the US$9 million profit recorded in Q1 23, mainly due to gains from holding financial instruments and lower financial interests due to the repayment of AR$-denominated CBs.

Adjusted EBITDA from the power generation segment reached US$85 million, a 22% decrease year-on-year, mainly due to payment haircut on CAMMESA’s January 2024 invoice described above, lower sales associated with the reduction of spot energy prices and, to a lesser extent, Energía Plus prices, in addition to CTLL TG05’s outage and PEMC’s divestment. These effects were partially offset by lower operating expenditures, higher gas-fired power dispatch and the commissioning of PEPE IV. Adjusted EBITDA considers CTEB’s 50% ownership, which accrued US$16 million in Q1 24 vs. US$7 million in Q1 23, explained by the CCGT’s PPA. It excludes commercial interests for delayed collections, accrual of PPE’s expenses as operating expenditures, contingency provisions for the concession’s termination at Mendoza hydros and the impairment on CAMMESA’s December 2023 invoice for US$17 million.

Finally, without CTEB, capital expenditures registered US$24 million in Q1 24 vs. US$93 million in Q1 23, explained by the commissioning of PEPE IV in 2023 and the last disbursements of PEPE VI, which is estimated to be fully commissioned by October 2024. The following table shows the expansion projects in power generation:

Project	MW	Marketing	Currency	Awarded price				Estimated capex in US$ million1		Date of commissioning
				Capacity per MW-month	Variable per MWh	Total per MWh		Budget	% Executed @03/31/24
Renewable
Pampa Energía VI	139.5	MAT ER	US$	na	na	62(2)		269	60%	Q4 2024 (est.)

Note: 1 Without value-added tax. 2 Estimated average.

3.3

Analysis of the oil and gas segment

Oil & gas segment, consolidated Figures in US$ million		First quarter
		2024	2023	∆%
Sales revenue		150	154	-3%
Domestic sales		119	104	+14%
Foreign market sales		31	50	-38%
Cost of sales		(99)	(92)	+8%
Gross profit		51	62	-18%
Selling expenses		(13)	(12)	+8%
Administrative expenses		(18)	(18)	-
Other operating income		14	5	+180%
Other operating expenses		(5)	(5)	-
Operating income		29	32	-9%
Finance costs		(26)	(38)	-32%
Other financial results		(3)	5	NA
Financial results, net		(29)	(33)	-12%
Loss before tax		-	(1)	-100%
Income tax		49	-	NA
Net loss for the period		49	(1)	NA
Adjusted EBITDA		70	62	+14%
Increases in PPE and right-of-use assets		87	88	-1%
Depreciation and amortization		47	32	+47%

The slight decrease in Q1 24 sales from the oil and gas segment is mainly due to lower gas exports to Chile and crude oil sales, offset by higher gas sales in the domestic market, in line with the increased power demand and Plan Gas.Ar awarded volumes.

Oil and gas' key performance indicators		2024				2023				Variation
		Oil	Gas	Total		Oil	Gas	Total		Oil	Gas	Total
First quarter
Volume
Production
In thousand m3/day		0.7	11,684			0.8	8,898			-16%	+31%	+27%
In million cubic feet/day			413				314
In thousand boe/day		4.3	68.8	73.1		5.1	52.4	57.5
Sales
In thousand m3/day		0.6	11,807			0.9	8,968			-34%	+32%	+25%
In million cubic feet/day			417				317
In thousand boe/day		3.9	69.5	73.4		6.0	52.8	58.8
Average Price
In US$/bbl		68.6				67.7				+1%	-18%
In US$/MBTU			3.2				4.0

Note: The net production in Argentina. The gas volume is standardized at 9,300 kilocalories (kCal).

In operating terms, total production reached 73.1 kboe per day in Q1 24 (+27% vs. Q1 23 and +30% vs. Q4 23). Gas production recorded 11.7 million m³ per day (+31% vs. Q1 23 and +32% vs. Q4 23) mainly explained by the higher volumes awarded under Plan Gas.Ar, thanks to the commissioning of GPNK in August 2023, lightening bottlenecks in the main gas pipelines. Moreover, the demand from power thermal plants increased due to higher temperatures.

Analyzing the gas output by block, 64% of our total output in Q1 24 came from El Mangrullo, which recorded 7.4 million m³ per day (+29% vs. Q1 23 and +58% vs. Q4 23). In Sierra Chata, the production increased to 2.4 million m³ per day (+94% vs. Q1 23 and +8% vs. Q4 23) due to the outstanding productivity of its shale wells. At non-operated blocks, Río Neuquén remained at 1.5 million m³ per day (similar to Q1 23 and Q4 23), while Rincón del Mangrullo continued the natural depletion, contributing 0.2 million m³ per day (-5% vs. Q1 23 but similar to Q4 23).

Our gas price in Q1 24 was US$3.2 per MBTU (-18% vs. Q1 23 but similar to Q4 23), explained by lower volumes and prices exported to Chile. It is worth noting that in Q1 23, a sharp drought affected Chile and Argentina, shooting up the gas demand. Compared to Q4 23, foreign demand recovered substantially, reaching ToP levels stipulated in contracts.

Regarding our gas deliveries, during Q1 24, 66% was destined for thermal power generation and 9% for the retail segment, both under Plan Gas.Ar framework. Moreover, 14% was sold to the industrial/spot market, 8% was exported, and the remaining was sold as raw material to our petchem plants. In contrast, in Q1 23, 49% supplied thermal power units, 21% to the industrial/spot market, 15% was exported, 11% to the retail segment and the remaining was sold to our petchem plants.

Oil production reached 4.3 kbbl per day in Q1 24 (-16% vs. Q1 23 and -4% vs. Q4 23), explained by year-on-year drops of 0.8 kbbl per day at El Tordillo due to its natural depletion and 0.5 kbbl per day at Los Blancos due to temporary well shut-in, partially offset by associated crude oil from Sierra Chata and the completion in March of a shale oil well in Rincón de Aranda (+0.6 kbbl per day).

Our oil price in Q1 24 was slightly higher than in Q1 23, reaching US$69.9 per bbl, being domestic and foreign prices very close. 69% of our sales were destined to the domestic market vs. 80% in Q1 23.

By the end of Q1 24, we accounted for 804 productive wells vs. 813 as of 2023.

Net operating costs in Q1 24, excluding depreciation, amortization, Plan Gas.Ar compensation and the gains from the settlement of exports at a differential FX decreased 11% vs. Q1 23 to US$82 million but remained stable vs. Q4 23, mainly due to variations in the crude oil stock, higher commercial interests due to increased collection delays from CAMMESA and lower labor costs, partially offset by higher maintenance, treatment and gas transportation costs due to increased gas activity.

The lifting cost per boe decreased, reaching US$5.8 per boe produced in Q1 24 (-19% vs. Q1 23 and -22% vs. Q4 23), mainly explained by larger production volumes.

Plan Gas.Ar compensation and gains from exporting at a differential FX reached US$7 million and US$1 million in Q1 24, respectively—a sharp three-time increase in Plan Gas.Ar is due to the AR$ devaluation impacting the regulated PIST gas price, making wider the difference with the contracted price in US$. The differential FX income decreased vs. Q4 23 because of the shrinking gap between official FX and CCL.

Financial results in Q1 24 recorded net losses of US$29 million, a 12% improvement vs. Q1 23, mainly explained by lower financial interests due to the decrease in AR$-debt stock. Lower gains from holding financial securities partially offset these effects.

Our oil and gas adjusted EBITDA amounted to US$70 million in Q1 24 (+14% vs. Q1 23), mainly explained by higher gas sales in the domestic market, partially offset by lower exports to Chile and crude oil sales. The adjusted EBITDA of Q1 24 excludes commercial interests for late collection, mainly charged to CAMMESA.

Finally, capital expenditures amounted to US$88 million in Q1 24 (similar to Q1 23), mainly driven by the beginning of the shale oil pilot plan in Rincón de Aranda, partially offset by the shale gas ramp-up activity during 2023.

3.4

Analysis of the petrochemicals segment

Petrochemicals segment, consolidated Figures in US$ million		First quarter
		2024	2023	∆%
Sales revenue		120	125	-4%
Domestic sales		76	89	-15%
Foreign market sales		44	36	+22%
Cost of sales		(108)	(114)	-5%
Gross profit		12	11	+9%
Selling expenses		(2)	(3)	-33%
Administrative expenses		(2)	(2)	-
Other operating income		3	-	NA
Operating income		10	6	+67%
Finance costs		(1)	(1)	-
Financial results, net		(1)	(1)	-
Profit before tax		9	5	+80%
Income tax		2	-	NA
Net income for the period		11	5	+120%
Adjusted EBITDA		11	7	+58%
Increases in PPE		1	2	-50%
Depreciation and amortization		1	1	-

 

The petrochemicals segment’s adjusted EBITDA reached US$11 million in Q1 24, a 58% increase vs. Q1 23, mainly explained by higher sales of reforming products, both in local and foreign markets, and, to a lesser extent, higher SBR exports. In addition, lower operating costs related to the FX variation and the profit from the settlement of exports at a differential FX were recorded, reaching US$3 million. The drop in international reference prices partially offset these effects and, except for the reforming, lower dispatch of all the segment’s products in the domestic market, correlated with the lower economic activity.

Total volume sold increased by 7% vs. Q1 23, reaching 110 thousand tons, mainly explained by higher octane basis sales in the local market and higher exports of naphtha, in line with the increased processing of virgin naphtha. Lower local demand for styrene, polystyrene, and SBR partially offset these effects.

Petrochemicals' key performance indicators		Products				Total
		Styrene & polystyrene1	SBR	Reforming & others
First quarter
Volume sold Q1 24 (thousand ton)		23	10	77		110
Volume sold Q1 23 (thousand ton)		29	9	66		103
Variation Q1 24 vs. Q1 23		-21%	+19%	+17%		+7%
Average price Q1 24 (US$/ton)		1,711	1,639	845		1,098
Average price Q1 23 (US$/ton)		1,857	1,938	846		1,219
Variation Q1 24 vs. Q1 23		-8%	-15%	-0%		-10%

Note: 1 Includes Propylene.

In Q1 24, financial results reached a net loss of US$1 million, similar to Q1 23, mainly explained by lower net gains from the AR$ devaluation over payables, partially offset by lower losses from holding financial securities.

3.5

Analysis of the holding and others segment

Holding and others segment, consolidated Figures in US$ million		First quarter
		2024	2023	∆%
Sales revenue		3	4	-25%
Domestic sales		3	4	-25%
Gross profit		3	4	-25%
Administrative expenses		(8)	(9)	-11%
Other operating income		1	-	NA
Other operating expenses		(22)	(3)	NA
Recovery from impair. (Impairment) of intangible assets		-	2	-100%
Income from the sale of associates		2	-	NA
Results for participation in joint businesses		40	13	+208%
Operating income		16	7	+129%
Finance income		2	2	-
Finance costs		(10)	(14)	-29%
Other financial results		3	45	-93%
Financial results, net		(5)	33	NA
Profit before tax		11	40	-73%
Income tax		-	1	-100%
Net income for the period		11	41	-73%
Adjusted EBITDA		23	29	-22%
Increases in PPE		1	2	-50%
Depreciation and amortization		-	-	NA

The holding and others segment, excluding the affiliates’ equity income (Transener and TGS), posted a US$24 million operating loss in Q1 24, while it was a US$6 million loss in Q1 23, mainly explained by the provision for the arbitration award result with POSA for US$16 million, along with other requirements for contingencies, partially offset by lower labor costs.

In Q1 24, financial results reached a net loss of US$7 million, while it was a US$33 million net gain in Q1 23, mainly due to lower FX profit from the dilution of fiscal liabilities.

The adjusted EBITDA of our holding and others segment decreased by 22% year-on-year, reaching US$23 million in Q1 24. The adjusted EBITDA excludes the equity income from our participation in TGS and Transener. In turn, it adds the EBITDA adjusted by equity ownership in these businesses.

In TGS, the EBITDA adjusted by our stake was US$27 million in Q1 24, similar to Q1 23, mainly explained by higher US$-denominated sales, due to the inflation evolution that resulted higher than the AR$ devaluation. In addition, the midstream segment also increased its sales, mainly because of higher transportation and conditioning services for natural gas in Vaca Muerta, and the operation and maintenance of the GPNK. Furthermore, the liquids segment’s EBITDA grew because of a decrease in US$-denominated gas costs, partially offset by lower traded volumes of gasoline and ethane, the latter due to client operational restrictions. However, the regulated business continues to perform below inflation, as the tariff increase set in Res. ENARGAS No. 112/24 will be applicable from April 2024.

In Transener, the EBITDA adjusted by our stake was US$6 million loss in Q1 24 vs. a US$10 million loss in Q1 23, mainly due to the tariff increase applicable from February 2024 (179.7% Transener and 191.1% Transba). The EBITDA excludes insurance collection for the failure of synchronous compensators at Ezeiza transformer station, which amounted to US$3 million in Q1 24.

3.6

Analysis of the quarter, by subsidiary and segment

Subsidiary In US$ million	First quarter 2024					First quarter 2023
	% Pampa	Adjusted EBITDA	Net debt2	Net income3		% Pampa	Adjusted EBITDA	Net debt2	Net income3
Power generation segment
Diamante	61.0%	0	(0)	1		61.0%	(1)	(0)	0
Los Nihuiles	52.0%	(0)	(0)	2		52.0%	(1)	(0)	0
VAR	100.0%	4	0	4		1.00	5	-	3
Greenwind		-	-	-			5	56	1
Subtotal Greenwind adjusted by ownership	0.0%	-	-	-		100.0%	5	56	1
CTBSA		32	219	49			13	297	5
Non-controlling stake adjustment		(16)	(109)	(25)			(7)	(148)	(2)
Subtotal CTBSA adjusted by ownership	50.0%	16	109	25		50.0%	7	148	2
Pampa stand-alone, other companies, & adj.1		65	(238)	166			93	20	88
Subtotal power generation		85	(129)	197			108	225	96
Oil & gas segment
Pampa Energía	100.0%	70	956	48		100.0%	62	827	(1)
Subtotal oil & gas		70	956	48			62	827	(1)
Petrochemicals segment
Pampa Energía	100.0%	11	-	11		100.0%	7	-	5
Subtotal petrochemicals		11	-	11			7	-	5
Holding & others segment
Transener		21	(28)	12			38	(3)	21
Non-controlling stake adjustment		(16)	20	(9)			(28)	2	(15)
Subtotal Transener adjusted by ownership	26.3%	6	(7)	3		26.3%	10	(1)	5
TGS		103	39	65			95	84	27
Non-controlling stake adjustment		(76)	(29)	(48)			(67)	(59)	(19)
Subtotal TGS adjusted by ownership	26.2%	27	10	17		29.1%	28	24	8
Pampa stand-alone, other companies, & adj.1		(10)	(0)	(9)			(8)	(0)	28
Subtotal holding & others		23	3	11			29	23	41
Deletions		-	(112)	-			-	(172)	-
Total consolidated		189	718	267			206	903	141
At our share ownership		185	830	267			202	1,075	141

Note: 1 The deletion corresponds to other companies or inter-companies. 2 Net debt includes holding companies. 3 Attributable to the Company’s shareholders.

 

4.

Appendix

4.1

Power generation’s main operational KPIs by plant

Power generation's key performance indicators		Hydroelectric				Wind						Subtotal hydro +wind	Thermal											Total
		HINISA	HIDISA	HPPL		PEMC1	PEPE2	PEPE3	PEPE4	PEA			CTLL	CTG	CTP	CPB	CTPP	CTIW	CTGEBA	Eco- Energía	CTEB2	Subtotal thermal
Installed capacity (MW)		265	388	285		-	53	53	81	100		1,225	780	361	30	620	100	100	1,253	14	848	4,107		5,332
New capacity (MW)		-	-	-		-	53	53	81	100		287	184	100	-	-	100	100	565	14	279	1,343		1,630
Market share		0.6%	0.9%	0.6%		0.0%	0.1%	0.1%	0.2%	0.2%		2.8%	1.8%	0.8%	0.1%	1.4%	0.2%	0.2%	2.9%	0.03%	1.9%	9.4%		12%
First quarter
Net generation Q1 24 (GWh)		311	208	164		-	38	45	79	82		926	1,121	135	28	102	44	37	2,267	17	1,251	5,002		5,928
Market share		0.8%	0.5%	0.4%		0.0%	0.1%	0.1%	0.2%	0.21%		2.4%	2.9%	0.3%	0.1%	0.3%	0.1%	0.1%	5.8%	0.0%	3.2%	12.8%		15.1%
Sales Q1 24 (GWh)		311	208	164		-	41	45	79	82		929	1,091	229	28	102	44	37	2,394	38	1,251	5,215		6,144
Net generation Q1 23 (GWh)		176	97	175		83	49	52	27	80		739	1,282	38	23	482	108	109	2,177	19	783	5,021		5,760
Variation Q1 24 vs. Q1 23		+77%	+116%	-7%		-100%	-22%	-14%	na	+2%		+25%	-13%	na	+26%	-79%	-60%	-66%	+4%	-10%	+60%	-0%		+3%
Sales Q1 23 (GWh)		176	97	175		83	49	52	27	80		740	1,282	154	23	482	108	109	2,322	37	783	5,299		6,038
Avg. price Q1 24 (US$/MWh)		9	14	12		na	76	64	64	80		27	20	34	13	66	na	na	31	39	28	31		31
Avg. price Q1 23 (US$/MWh)		16	34	16		70	79	66	66	79		41	20	75	25	20	92	72	33	37	25	31		32
Avg. gross margin Q1 24 (US$/MWh)		3	3	2		na	58	72	72	55		19	16	13	(3)	9	na	145	18	18	23	20		20
Avg. gross margin Q1 23 (US$/MWh)		7	11	7		60	64	62	62	68		30	17	33	7	8	72	54	20	14	16	20		21

Note: Gross margin before amortization and depreciation 1 Fully owned by Pampa from August 2022 to July 2023. 2 Operated by Pampa (50% equity stake).

4.2

Production in the main oil and gas blocks

In kboe/day at ownership		First quarter
		2024	2023	Variation
Gas
El Mangrullo		43.7	33.8	+29%
Río Neuquén		8.9	8.7	+2%
Sierra Chata		13.8	7.1	+94%
Rincón del Mangrullo1		1.5	1.5	-5%
Others		0.9	1.1	-25%
Total gas at working interest		68.8	52.4	+31%
Oil
El Tordillo2		1.6	2.3	-31%
Gobernador Ayala		1.1	1.2	-10%
Associated oil3		1.3	1.0	#VALOR!
Others		0.4	0.6	-41%
Total gas at working interest		4.3	5.1	-16%
Total		73.1	57.5	+27%

Note: Production in Argentina. 1 It does not include shale formation. 2 It includes the La Tapera – Puesto Quiroga block. 3 From gas fields.

 

5.

Glossary of terms

Term	Definition
ADR/ADS	American Depositary Receipt
AR$	Argentine Pesos
Bbl	Barrel
BCRA	Banco Central de la República Argentina (Argentina Central Bank)
Boe	Barrels of oil equivalent
ByMA	Bolsas y Mercados Argentinos (Buenos Aires Stock Exchange)
CAMMESA	Compañía Administradora del Mercado Mayorista Eléctrico S.A. (Argentine Wholesale Electricity Market Clearing Company)
CB	Corporate Bonds
CCGT	Combined Cycle
CCL	An AR$ security settled in foreign markets
CNY	Renminbi Chinese currency
CPB	Piedra Buena Thermal Power Plant
CTBSA	CT Barragán S.A.
CTEB	Ensenada Barragán Thermal Power Plant
CTG	Güemes Thermal Power Plant
CTGEBA	Genelba Thermal Power Plant
CTIW	Ingeniero White Thermal Power Plant
CTLL	Loma De La Lata Thermal Power Plant
CTP	Piquirenda Thermal Power Plant
CTPP	Parque Pilar Thermal Power Plant
E&P	Exploration and Production
EBITDA	Earnings before interest, tax, depreciation and amortization
EcoEnergía	EcoEnergía Co-Generation Power Plant
ENARGAS	Ente Nacional Regulador del Gas (National Gas Regulatory Entity)
ENRE	Ente Nacional Regulador de la Electricidad (National Electricity Regulatory Entity)
FS	Financial Statements
FX	Nominal exchange rate
GPNK	Presidente Néstor Kirchner Gas Pipeline
GT	Gas turbine
GWh	Gigawatt-hour
HIDISA	Diamante Hydro Power Plant
HINISA	Los Nihuiles Hydro Power Plant
HPPL	Pichi Picun Leufu Hydro Power Plant
IFRS	International Financial Reporting Standards
Kbbl/kboe	Thousands of barrels/thousands of barrels of oil equivalent
M3	Cubic meter
MBTU	Million British Thermal Units
MW/MWh	Megawatt/Megawatt-hour
N.a.	Not applicable
O/S	Share ownership
Pampa / The Company	Pampa Energía S.A.

 

 

PEA	Arauco II Wind Farm, stage 1 and 2
PEMC	Ingeniero Mario Cebreiro Wind Farm
PEPE	Pampa Energía Wind Farm
PIST	Punto de Ingreso al Sistema de Transporte (System Entry Point for Transportation)
Plan Gas.Ar	Re-assurance and Strengthening of the Federal Hydrocarbon Production through Self-Supply, Exports, Replacement of Imports and the Expansion of the Transportation System to All the Country’s Hydrocarbon Basins 2023 – 2028 Plan (Executive Order No. 730/22) and the Argentine Natural Gas Production Promotion Plan – 2020 – 2024 Supply and Demand Scheme (Emergency Executive Order No. 892/20 and supplementary provisions)
POSA	Petrobras Operaciones S.A.
PPA	Power Purchase Agreement
PPE	Property, Plant and Equipment
Q4 23	Fourth quarter of 2023
Q1 24/Q1 23	First quarter of 2024/First quarter of 2023
Res.	Resolution/Resolutions
RTI	Comprehensive tariff review
SE	Secretariat of Energy
ST	Steam turbine
TGS	Transportadora de Gas del Sur S.A.
Ton	Metric ton
ToP	Take or pay
Transba	Empresa de Transporte de Energía Eléctrica por Distribución Troncal de la Provincia de Buenos Aires Transba S.A.
Transener	Compañía de Transporte de Energía Eléctrica en Alta Tensión Transener S.A.
US$	U.S. Dollars
US$-link	A security in which the underlying is linked to US$ wholesale exchange rate
US$-MEP	A security in which the settlement uses US$ in the domestic market

 

Pampa Energía ● Earnings release Q1 24 ● 23

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