Savannah Energy Plc, the British independent energy company focused around the delivery of Projects that Matter, has announced its unaudited results for the year ended 31 December 2024.
The FY 2024 Unaudited Results show a Total Income of US$393.8 million, compared to US$289.8 million in FY 2023. This comprises of Total Revenues of US$258.9, compared to US$260.9 million in FY 2023, and other operating income of US$134.9 million, compared to US$28.9 million in FY 2023.
The results also show that Savannah Energy achieved or exceeded its previously issued financial guidance for the year, with its total revenues as of December 31 2024 standing at US$ 258.9 million, 6% ahead of previously issued guidance of greater than US$245 million.
Likewise, its operating and administrative expenses for the year came to US$71.0 million, 5% below previous guidance of up to US$75.0 million, with its capital expenditure at US$23.1 million, well below the previously issued guidance of up to US$50 million due to the phasing of spend.
The company also reported a record cash collection of US$248.5 million in FY 2024, an over 21% increase on its FY 2023 cash collections of US$206 million. Its cash balances as of 31 December 2024 stood at US$32.6 million, compared to US$107.0 million as of 31 December 2023, and a net debt of US$636.9 million, compared to US$473.7 million by the end of December 2023. In the same vein, its gross debt as of 31 December 2024 was US$669.5 million, of which US$630.6 million (94%) was non-recourse to PLC.
Savannah’s FY 2024 Adjusted EBITDA stood at US$181.2 million, broadly in line with prior year’s US$184.1 million, while maintaining its Adjusted EBITDA margin at 70% which was 71% in FY 2023.
In terms of assets, its Total Group assets increased to US$1.6 billion as of 31 December 2024, compared to US$1.5 billion in 2023.
In terms of operations, the results show that its average gross daily production was 23.1 Kboepd, broadly in line with FY 2023’s 23.6 Kboepd, of which 88% was gas which was 91% in FY 2023.
The highlighted a 21% increase in 2P Reserves at its flagship Uquo field in Nigeria, bringing the total Reserves increase on the field since acquisition to 81%. This follows its announcement of a 29% increase in 2P Reserves on the Stubb Creek field in May 2025.
The report further showed that Savannah agreed and extended three gas contracts with customers in FY 2024 for a total of up to 105 MMscfpd (17.5 Kboepd), and realized an average sales price of US$4.68/Mscfe, an over 4% increase on the prior year average realised price of US$4.51/Mscfe.
Savannah reported that as of 31 December 2024, ₦332 billion of then ₦340 billion term facility signed by Accugas in January 2024 with a consortium of five Nigerian banks had been drawn down, with the resulting funds converted to US$, which, along with cash held, was used to partially prepay the existing Accugas US$ Facility, leaving a balance as at 31 December 2024 of approximately US$212.3 million.
It also reported that it signed a US$60 million debt facility in October 2024 with The Standard Bank of South Africa Limited and Stanbic IBTC Bank Limited to fund the SIPEC Acquisition.
Andrew Knott, CEO of Savannah Energy, said:
“I am pleased to announce our FY 2024 results today, in line with our trading statement released in January 2025, and to announce a 21% increase in 2P Reserves at our flagship Uquo field in Nigeria, bringing the total Reserves increase on the field since acquisition to 81%. This follows our announcement of a 29% increase in 2P Reserves on the Stubb Creek field in May 2025.
2025 continues to be an exciting year for the business and we continue to work towards “ticking-off” the delivery of the nine focus area projects that we outlined at the beginning of the year, being: (1) securing a further increase in our rate of cash collections in Nigeria1; (2) completion of the refinancing of our principal Nigerian debt facilities; (3) completion of the planned acquisition of 100% of Sinopec International Petroleum Exploration and Production Company Nigeria Limited (the “SIPEC Acquisition”) which was achieved during Q1 2025; (4) commencement of the Stubb Creek expansion project; (5) the advancement of our Chad/Cameroon arbitration processes2; (6) the commencement of the safe and successful drilling of our planned Uquo development well and potential Uquo exploration well; (7) the potential advancement of our R3 East development in Niger3; (8) the refinement of our power sector business model; and (9) the delivery of further transformational acquisitions. I would also highlight that we anticipate achieving a strong increase in cash collections in 2025 (even when set against our long-term 13% CAGR4), with significant production capacity growth expected in 2026 once our heavy Uquo field investment programme is completed.”
FY 2024 Highlights
Average gross daily production was 23.1 Kboepd, broadly in line with the prior year (FY 2023: 23.6 Kboepd), of which 88% was gas (FY 2023: 91%)5;
FY 2024 Total Income6 of US$393.8 million (FY 2023: US$289.8 million), comprising Total Revenues7 of US$258.9 million (FY 2023: US$260.9 million) and Other operating income8 of US$134.9 million (FY 2023: US$28.9 million);
FY 2024 record cash collections of US$248.5 million (+21% on FY 2023 cash collections of US$206 million). As at 31 December 2024, cash balances were US$32.6 million (31 December 2023: US$107.0 million) and net debt stood at US$636.9 million (31 December 2023: US$473.7 million). Gross debt as at 31 December 2024 was US$669.5 million, of which US$630.6 million (94%) was non-recourse to PLC;
FY 2024 Adjusted EBITDA9 of US$181.2 million broadly in line with prior year (FY 2023 of US$184.1 million) and Adjusted EBITDA9 margin maintained at 70% (FY 2023: 71%);
Total Group assets of US$1.6 billion as at 31 December 2024 (2023: US$1.5 billion);
Financial guidance for the year achieved or exceeded:
Total Revenues7 of US$258.9 million (6% ahead of guidance of ‘greater than US$245 million’);
Operating expenses plus administrative expenses10 of US$71.0 million (5% below guidance of ‘up to US$75.0 million’); and
Capital expenditure of US$23.1 million lower than guidance of ‘up to US$50 million’ due to the phasing of spend;
Three gas contracts with customers agreed and extended in FY 2024 for a total of up to 105 MMscfpd (17.5 Kboepd);
Average realised sales price of US$4.68/Mscfe (+4% increase on the prior year average realised price of US$4.51/Mscfe);
NGN340 billion term facility signed by Accugas in January 2024 with a consortium of five Nigerian banks (the “Transitional Facility”). As at 31 December 2024, NGN 332 billion of the Transitional Facility had been drawn down, with the resulting funds converted to US$, which, along with cash held, was used to partially prepay the existing Accugas US$ Facility, leaving a balance as at 31 December 2024 of approximately US$212.3 million;
US$60 million debt facility signed in October 2024 with The Standard Bank of South Africa Limited and Stanbic IBTC Bank Limited to fund the SIPEC Acquisition11; and
Uquo Marginal Field and the Stubb Creek Marginal Field were converted to new 20-year Petroleum Mining Leases, both effective 1 December 2023, in accordance with the Republic of Nigeria’s Petroleum Industry Act 2021.
Updated Competent Persons Reports
As previously announced on 19 May 2025, the Company appointed McDaniel & Associates Consultants Ltd. (“McDaniel”) to prepare updated Competent Persons Reports (“CPRs”) for the oil and gas assets of the Group. McDaniel have completed their assessment (prepared in accordance with the 2018 Petroleum Resource Management System) of the Reserves and Resources for the Stubb Creek and Uquo fields. The results from this CPR are set out in the tables below, along with comparisons vs. the Reserves and 2P + 2C Resources presented in the Company’s March 2024 Nigeria CPR as adjusted for production since publication.
Summary Comparison of Nigeria Gross Reserves
| Uquo Field Summary of Gross Gas Reserves (Bscf) | |||
| 1P | 2P | 3P | |
| CPR, March 2024* | 233.5 | 400.5 | 493.6 |
| McDaniel, March 2025 | 320.2 | 484.9 | 544.8 |
| Changes (%) | 37% | 21% | 10% |
*Prepared by CGG Services (UK) Ltd
| Stubb Creek Field Summary of Gross Oil Reserves (MMstb) | |||
| 1P | 2P | 3P | |
| CPR, March 2024* | 3.3 | 10.7 | 20.4 |
| McDaniel, March 2025 | 9.7 | 13.8 | 18.1 |
| Changes (%) | 194% | 29% | -11% |
* Prepared by CGG Services (UK) Ltd
| Nigeria Gross 2P Reserves and 2C Resources | ||||
| CGG, 2024* | McDaniel, 2025 | Changes (%) | ||
| Uquo 2P Gas | Bscf | 400.5 | 484.9 | 21% |
| Uquo 2P Condensate | MMstb | 0.6 | 0.7 | 21% |
| Uquo 2C Gas | Bscf | 82.8 | 55.1 | -33% |
| Stubb Creek 2P Oil | MMstb | 10.7 | 13.8 | 29% |
| Stubb Creek 2C Gas | Bscf | 515.3 | 513.1 | 0% |
| Nigeria 2P+2C | MMboe | 177.7 | 190.0 | 7% |
*Prepared by CGG Services (UK) Ltd
2024 Sustainability Highlights
Publication today of our 2024 Sustainability Review and 2024 disclosure reports in accordance with the Task Force on Climate-Related Financial Disclosures (“TCFD”) and the Sustainability Accounting Standards Board (“SASB”) standards;
Strong safety record maintained during 2024 with a zero Lost Time Injury rate and Total Recordable Incident rate;
2024 scope 1 carbon intensity ratio fell 47% to 5.7 kg CO2e/boe (2023: 10.7 kg CO2e/boe), driven primarily by an absence of pipeline maintenance and by initiatives to reduce emissions at source (such as flare reduction) at the Uquo Central Processing Facility;
Total Contributions12 to our host nations increased 22% year-on-year to US$63.4 million (2023: US$52.0 million); and
Training hours per employee increased 32% year-on-year to 75 hours per employee with the increase largely due to a three-fold increase in health, safety and environment training hours.
Post-year End Update
On 4 March 2025, we announced the completion of an equity issuance raising, in aggregate, gross proceeds of approximately £30.6 million and the signing of a US$200 million acquisition debt facility providing access to potential funding for future hydrocarbon asset acquisitions (currently undrawn);
On 10 March 2025, we announced the completion of the SIPEC Acquisition and have commenced work on an up to 18-month expansion programme, anticipated to increase gross production to approximately 4.7 Kbopd;
The US$45 million compression project at the Uquo Central Processing Facility is almost complete, with one compressor online and the second to be commissioned before the end of this month. This project, which will be delivered under budget, will allow us to maximise the production from our existing and future gas wells;
The procurement process of long lead equipment is progressing in Nigeria in preparation for a potential two-well drilling campaign on the Uquo Field commencing in Q4 2025. Well site and flowline surveys have been completed for the Uquo NE development well (“Uquo NE”). This well is forecast to provide gas volumes of up to 80 MMscfpd. An additional exploration well in the Uquo Field (“Uquo South”) is also currently under consideration, which may be drilled back-to-back with the Uquo NE well. Uquo South is targeting an Unrisked Gross gas initially in place of 131 Bscf of incremental gas resources on the Uquo licence area as audited by McDaniel;
We are continuing to seek to progress the 35 MMstb (Gross 2C Resources) R3 East oil development in South-East Niger, subject to satisfactory stakeholder agreements being entered into.
We continue to progress our existing portfolio of up to 696 MW of wind, solar and hydroelectric projects, with our principal focus being on the up to 250 MW Parc Eolien de la Tarka wind farm project in Niger and the up to 95 MW Bini a Warak hybrid hydroelectric and solar project in Cameroon;
We are in the process of refining our Power Division business model, the remit of which has now been expanded to include potential thermal as well as potential renewable energy projects;
Cash collections YTD to 30 April 2025 were US$135.3 million (4 months to 30 April 2024: US$132.2 million). Delivering an increase in our rate of cash collections in Nigeria remains a key focus area in 2025. As at 30 April 2025 cash balances were US$77.2 million and net debt stood at US$601.6 million; and
Final documentation has been agreed with the lenders in respect of an increase in the Transitional Facility from NGN340 billion to up to NGN773 billion. It is expected that the agreements will be signed this month, and this upsized facility will be utilised to enable the remaining outstanding balance of the Accugas US$ Facility to be repaid. It is currently expected that this will be completed in H2 2025 and, once completed, this will align Accugas’ primary debt facility with the currency in which gas revenues are received.
