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| Share Name | Share Symbol | Market | Type | Share ISIN | Share Description |
|---|---|---|---|---|---|
| Afentra Plc | LSE:AET | London | Ordinary Share | GB00B4X3Q493 | ORD 10P |
| Price Change | % Change | Share Price | Shares Traded | Last Trade
|
|
|---|---|---|---|---|---|
| 0.00 | 0.00% | 43.20 | 7,014 | 08:15:34 |
| Bid Price | Offer Price | High Price | Low Price | Open Price | |
|---|---|---|---|---|---|
| 43.50 | 44.60 | ||||
| Industry Sector | Turnover | Profit | EPS - Basic | PE Ratio | Market Cap |
|---|---|---|---|---|---|
| Crude Petroleum & Natural Gs | USD | USD -9.09M | USD -0.0413 | -10.46 | 95.06M |
| Last Trade Time | Trade Type | Trade Size | Trade Price | Currency |
|---|---|---|---|---|
| 08:25:02 | O | 2,000 | 43.9125 | GBX |
| Date | Time | Source | Headline |
|---|---|---|---|
| 20/3/2024 | 09:53 | UK RNS | Afentra PLC Incentive Plan Awards & PDMR Dealings |
| 13/3/2024 | 17:39 | ALNC |  Afentra to finalise Angolan acquisition in "coming weeks" |
| 13/3/2024 | 07:00 | UK RNS | Afentra PLC Company Update |
| 16/2/2024 | 15:04 | UK RNS | Afentra PLC Notification of Major Holdings |
| 24/1/2024 | 17:41 | ALNC | TRADING UPDATES: MetalNRG's legal settlement; Impellam confirms payout |
| 24/1/2024 | 07:00 | UKREG | Afentra PLC Operations and Financial Update |
| 23/1/2024 | 14:15 | UKREG | Afentra PLC Director/PDMR Dealings |
| 22/1/2024 | 16:04 | ALNC | IN BRIEF: Afentra named preferred bidder for two blocks in Angola |
| 22/1/2024 | 12:56 | UKREG | Afentra PLC Participation in Angolan Onshore Bid Round |
| 15/1/2024 | 12:07 | UKREG | Afentra PLC DIRECTOR / PDMR DEALINGS |
Afentra (AET) Share Charts1 Year Afentra Chart |
|
1 Month Afentra Chart |
Intraday Afentra Chart |
| Date | Time | Title | Posts |
|---|---|---|---|
| 23/4/2024 | 15:54 | AFENTRA - High Growth Second Phase O&G Sector Specialist | 130 |
| 23/4/2024 | 15:52 | Afentra PLC - energy transition in Africa | 1,083 |
| 05/4/2024 | 19:05 | AET with Charts & News | 27 |
| 23/12/2008 | 08:14 | Canadian Energy Trusts | 19 |
| Trade Time | Trade Price | Trade Size | Trade Value | Trade Type |
|---|---|---|---|---|
| 07:25:02 | 43.91 | 2,000 | 878.25 | O |
| 07:24:17 | 43.91 | 1,500 | 658.69 | O |
| 07:18:45 | 43.74 | 3,442 | 1,505.38 | O |
| 07:00:18 | 42.60 | 72 | 30.67 | O |
| 2024-04-23 15:35:19 | 43.20 | 10,654 | 4,602.53 | UT |
| Top Posts |
|---|
Posted at 19/4/2024 21:48 by tim000 AET’s assets do seem like the proverbial gold mine. It will just take a little time to get each field up to peak efficiency. As non-operator, AET management have the time to focus on M&A to replicate this business model. The potential of the company looks amazing. |
Posted at 12/4/2024 23:42 by yumyum Thank you very much Mount Teide. Appreciated. I will ponder on all that and see if I can concoct an improved spreadsheet. Your share price thoughts look cautiously modest perhaps. |
Posted at 12/4/2024 13:35 by mount teide YY - Ref: Production costs per bbl - have not seen any specific data.However, what we do know is that after the second working interest on the Block 3/05 asset was announced in July 2022, the following information was provided: * Break even economics of $35/bbl * Potential to improve OPEX to $20/bbl * Average FCF, after Capex, of $30m PA at $75 Brent. * Average production of circa 16,800 bopd when AET first commenced asset negotiations Since then, the following changes have been reported based on completion of the Sonangol (18%) and INA (5.33%) deal metrics: * Potential to improve and MAINTAIN OPEX at $20/bbl * Average FCF, after Capex, of $35m PA at $75 Brent. * Full year 2022 gross production of 18,660 bopd * Minimum Capex to realise P2 Case of 115 million bbls Post the Azule completion: * Average FCF, after Capex of $50m PA at $75 Brent based on 18,600 bopd (at $90 Brent and 22,550 bopd the FCF could potentially increase to $60-$70m a year). * Average production March 2024 of 22,500 bopd (recent peak of 25,000 bopd YE 2023) * Every 1% incremental recovery factor = 9 million bbls additional resources net to AET * Debt - If the Azule deal closes during the next few weeks, assuming an average of current Brent price and an average of 22,500 bopd production, AET is likely to be debt free during Q3/2024. * Apparently 80% of management time has been spent on M&A in the last 18 months . IR confirmed in January 2024 that the next webinar and strategy presentation will come after completion of Azule. * Infill Drilling Campaign for 2025-26 - first for over 20 years, will be interesting when considering that Pacassa alone has another circa 500m barrels. Thoughts: A further 5,000 bopd deal during 2024 with similar non dilutive metrics could well see AET trading at 100p plus. AIMHO/DYOR |
Posted at 11/4/2024 21:19 by mount teide Oil - Top traders and forecasters, as well as investment banks, have upgraded their price and demand forecasts in recent weeks on a tightening oil market, over which OPEC+ has now regained control.OPEC+ Rules in an Increasingly Tight Oil Market - Oilprice.com 10 April 2024 'The OPEC+ group is firmly back in control of the oil market and has the power to have it extremely tight in the second half of the year should it choose to do so, industry executives and hedge fund managers say. The market is growing increasingly bullish on oil, expecting robust global demand growth and supply constraints, including OPEC and Russia’s production cuts, to push prices even higher in the summer. With Brent oil prices breaking above $90 a barrel, there is room for further upside amid tighter markets and heightened geopolitical risks, investment banks say, not ruling out $100 oil this year. The trajectory of oil prices over the next year is largely in the hands of the OPEC+ alliance of the top Middle Eastern producers and Russia, according to Sebastian Barrack, head of commodities at hedge fund giant Citadel, which had $61 billion in investment capital as of April The OPEC+ group has “definitely regained control” of the market, Barrack said at the FT Commodities Global Summit in Lausanne, Switzerland, this week. If the alliance decides in early June to keep its current cuts after the end of the first half, we could see an “extremely tight” oil market in the second half of the year, Citadel’s executive said, adding that the timing of OPEC+’s potentially eased cuts and their volume “will define where prices go in the next 12 months.” Right now, prices are going up, as geopolitical concerns linger in the Middle East, demand holds strong and could turn out stronger than expected, and supply and infrastructure issues hold back production and exports, from Mexico to Russia. Top traders and forecasters, as well as investment banks, have upgraded their price and demand forecasts in recent weeks. Oil prices are set to trade in the range between $80 and $100 per barrel this year, Russell Hardy, chief executive at Vitol Group, said at the FT summit this week. The world’s largest independent oil trader also expects robust global oil demand growth in 2024, at around 1.9 million barrels per day (bpd) higher than in 2023, Hardy said. If this forecast pans out, this year’s growth in oil consumption will not be too far off the bumper increase in demand in 2023. The U.S. Energy Information Administration (EIA) raised its 2024 and 2025 forecasts of global oil consumption by between 400,000 bpd and 500,000 bpd, due to a revision of historical data for 2022 and to the “current market dynamics,” the EIA said in its monthly Short-Term Energy Outlook (STEO) on Tuesday. Morgan Stanley sees heightened geopolitical risk pushing Brent prices to $94 per barrel in the third quarter as the bank lifted its price forecast by $4 a barrel compared to its previous projection. Last month, Morgan Stanley had already hiked its third-quarter oil price forecast by $10 per barrel, to $90, on the back of expected tighter markets in the summer. In recent weeks, banks, including JP Morgan, have said that oil prices could hit $100 per barrel by the end of the summer. However, demand destruction could prevent prices from reaching triple digits, JP Morgan says. Still, analysts and industry executives believe that OPEC+ would reverse at least part of the cuts if prices run up to $100 as it would look to avoid demand destruction, stronger response to high prices from U.S. shale, and a potential loss of longer-term demand for OPEC+ crude. If OPEC+ rolls over the cuts beyond June, “we will see a level of tightness in the market that will be very constraining to the market, and high prices will have to go and help destroy demand to solve that problem,” Citadel’s Barrack said at the FT Commodities Global Summit. As tempting as it may sound for OPEC to sell oil at $100 a barrel, the cartel may not be willing to risk another inflation shock that could cripple demand.' |
Posted at 10/4/2024 03:10 by xxnjr MT - apologies for being disagreeable but as a shareholder in Tullow that is not how I remember it.the share price of TLW is about 34p today. In 20 yrs the share price has increased from err 32p to 34p. Nothing much to shout home about. The business wasn't really built by McDade. It was initially built by founder/CEO Aidan Heavey and CFO Tom Hickey. As far as i can recall they were the ones who would have steered the negotiations on UKNS acquisitions from Esso and BP and they were the ones who negotiated the Energy Africa acquisition in 2003/4 which was arguably the making of Tullow Phase 1. The explosive share price grown of Tullow Phase 2 which reached £16 at one point (in old money b4 a capital raise) was driven by very high risk frontier exploration with big discoveries in Uganda, Ghana, Kenya, not from buying low risk mature assets from exiting majors. It all went to their heads in Tullow Phase 3 when in relative terms Tullow probably had the highest exploration spend of any E&P on the planet. billions and billions on exploration. And billions and billions written off on failed wells. McDade made such a mess of Tullow after being appointed CEO that the company were obliged to fire him. So yeah, Afentra is a bit like early Tullow Phase 1 was the UKNS. And hopefully McDade has learnt from past mistakes..... |
Posted at 06/4/2024 23:04 by xxnjr tim000,good question "MT: rather than apportion sales volumes per cargo according to field interests, it appears AET is allocated a proportion of cargoes per annum. That is very odd, for example it means pricing and end-of-year inventory could vary significantly between partners according to when they were allocated cargoes. Unless there is some accounting balancing procedure at, say, the end of each calendar year. Do you know exactly how the allocation of oil revenues is handled? Thanks." Unless I misunderstood your central point tim000, I'm not sure this is "very odd", at least in 'West Africa'. For example in Ghana dedicated cargoes are allocated to equity partners; Tullow, Kosmos, GNPC in respect of Jubilee and TEN fields and to ENI, Vitol, GNPC in respect of Sankofa field, respective to their equity share of fields. I believe this is pretty standard practise. At least in 'West Africa'. One recent exception has been where as part of Impact's farm out deal with Total Energies in Namibia, Impact elected to share their cargoes with Total as it would facilitate oil sales and reduce price volatility but that was driven by the structure of that particular farm out deal whereby Total were providing Impact a gross carry before netting out of say $6bn to $8bn to first oil (all seismic, exploration wells, development wells and first fpso development to 1st oil) with the carry being reclaimed out of a portion of Impact's revenues once Namibia production starts. In effect an interest free loan from Total to Impact. But once the 'loan' is repaid Impact will revert to dedicated cargoes. But getting back to what I believe is fairly standard practise in Angola and elsewhere in 'West Africa', (1) as MT mentioned, the price is what it is when a dedicated cargo loads to tanker for export from the Palanca FSO. This is usually 5 day ave brent price from Bill of Lading date, adjusted for oil grade and in the case of Afentra, whatever 'take' Trafigura apply under the Trafigura Offtake Agreement. The revenue goes to whichever partner that particular cargo was allocated to and (2) at year end in the accounts for each partner there will be either an "overlift" or "underlift" to take account of any variances between equity produced barrels and actual volume of barrels offloaded by allocated tanker cargos. To your point on pricing/revenues; yes there may well be timing/pricing anomalies in any one year but over say 20 yrs of a typical field life the "pluses and minuses" will in all likelihood average out to such an extent that individual equity partners carry that risk themselves. But of course smaller, non IOC/NOC type companies usually will additionally offset part of that risk through their OP hedging strategies. |
Posted at 24/1/2024 07:28 by nickiegaul Afentra PLC Operations and Financial UpdateSource: UK Regulatory (RNS & others)TIDMAETRNS Number : 6783AAfentra PLC24 January 202424 January 2024AFENTRA P L COperations and Financial UpdateAfentra plc ('Afentra' or the 'Company'), the upstream oil and gas company focused on acquiring mature production and development assets in Africa, provides an operational and financial update for 2023. Afentra currently holds non-operated 18% and 5.33% working interests in Blocks 3/05 and 3/05A, respectively, offshore Angola with working interests to increase to 30% and 21.33%, respectively, following completion of the impending Azule transaction.Operatio |
Posted at 29/12/2023 17:04 by mrnumpty Afentra is being strongly tipped by Small Company Share Watch . However , whilst I do realise that this is going back a quarter of a century , the share price was about £ 15 in August 1997 , rising to about £ 18 in December 1997 . Does anyone know why the share price then collapsed ? I am tempted here , and I’m sure the board of directors has changed in the intervening 25 years , but knowledge of the reason for the fall all those years ago would be useful . |
Posted at 20/12/2023 14:57 by ashkv Share Price - AET: 37.5AET Current Share Price vs 52 Week low of 18.85p on 24 Mar 23: 92.31% AET Current Share Price vs 52 Week High of 34p on 11 Dec 23: 10.29% Brent: $80.10 Shares Outstanding: 220,053,520 Market Cap (GBP): £82,520,070 GBPUSD: 1.265 Market Cap (USD): $104,387,889 Production Average FY 2022: 4,478 Production Assuming Acquisition Completion 3/05 & 3/05A (Nov 2023): 6,427 Block 3/05 2023 Production Forecast as of 8 Dec 23 (AET 30%): 5,730 Cash (HY 2023 Results): $15,700,000 Cash Outlay For Equity Component of Acquisitions: $20,700,000 Net Debt Forecast YE 2023 at $75 Brent (8 Dec 23 RNS) : $20,700,000 AET Crude Stock at $75 Brent (8 Dec 23): $11,900,000 Enterprise Value (Market Cap + Debt - Cash at HY 22) (USD): $125,087,889 EV/Barrel (FY 2022 Production Average): $27,931 EV/Barrel Production Assuming Acquisition Completion 3/05 & 3/05A (Nov 2023): $19,463 EV/Barrel Block 3/05 2023 Production Forecast as of 8 Dec 23 (AET 30%): $21,830 EV/Barrel November 2023 Production including YE Crude Stock: $17,611 2P Reserves Post Revised Acquisitions: 33,000,000 EV/2P: $3.79 |
Posted at 24/10/2023 14:25 by zengas AET should mirror Panoros growthPanoro 3 year history on production, revenue, reserves, net debt, dividends and m/cap. 2020 Production = 2200 bopd. Revenue $26.9m. Cash $5.7m. Debt $21.3m. -------------------- 9th Feb 2021 Eq Guinea & Gabon acquisitions of 6900 bopd + 25 mmbo 2P for $140m . Financed with $70m placing and debt of $90m from Trafigura. 113m shares in issue 21 NOK at this date = N2.37 billion = £174m m/cap. -------------------- RNS 23/2/22 = Year end 2021 Production 7495 bopd. Total 35.8 mmbo P2, Revenue $119.7m. Net debt $72m . RNS 30/11/22 = "USD 20 million core dividend paid on a quarterly basis in cash weighted towards H2 and subject to average oil price realisation remaining above USD 80 per barrel after the effects of any hedging. Target distribution for 2023 of USD 30 million subject to higher oil price realisation of USD 90 per barrel being achieved for the year after the effects of any hedging" -------------------- 2023 Production Q1 = 6,320 bopd H1 2023 results = Revenue $66m. 'Net debt' at 30/6/23 = $50.4m Working interest production averaged 7,220 bopd in the first half (H1 2022: 7,860 bopd). 71m NOK paid out in Dividends to end H1 = $6.7m paid out so far for H1 $6.7m paid out so far for H1. 117m shares in issue NOK 30 = N3.5 Billion = £260m m/cap against a an average broker target price of $4.18 or £390m m/cap -------------------- AET = same 2P, approx 6,600 bopd. A $10m future dividend = 3.5p or 12.5% at the current share price or 3.3% yield at a £1 target price = £220.5m m/cap or 15% discount to Panoro. Should track Panoros rising production via 3/05 peak target programme and 3/05A commercial start up - not to mention any further acquisitions. |
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