Share Name Share Symbol Market Type Share ISIN Share Description
Challenger Energy Group Plc LSE:CEG London Ordinary Share IM00BN2RD444 ORD 0.02P
  Price Change % Change Share Price Shares Traded Last Trade
  0.00 0.0% 0.10 2,676,519 08:00:23
Bid Price Offer Price High Price Low Price Open Price
0.095 0.105 0.10375 0.10 0.10
Industry Sector Turnover (m) Profit (m) EPS - Basic PE Ratio Market Cap (m)
Oil & Gas Producers -10.23 -0.37 10
Last Trade Time Trade Type Trade Size Trade Price Currency
16:35:00 O 4,761 0.105 GBX

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Challenger Energy Daily Update: Challenger Energy Group Plc is listed in the Oil & Gas Producers sector of the London Stock Exchange with ticker CEG. The last closing price for Challenger Energy was 0.10p.
Challenger Energy Group Plc has a 4 week average price of 0.09p and a 12 week average price of 0.09p.
The 1 year high share price is 2.66p while the 1 year low share price is currently 0.09p.
There are currently 9,620,199,479 shares in issue and the average daily traded volume is 23,351,090 shares. The market capitalisation of Challenger Energy Group Plc is £9,620,199.48.
12bn: coxypete,I sold out of this in 2015 at 3p a share,which is equivalent to 720p a share now (after 2 x consolidations and a merger). I have seen PIs who know little about the old LGO/Cerp join,ramp and then get wiped out by over 95%,more than once! Basically all the income CEG gets is from old LGO assets and these old wells have declining production. CEG now has a potential new asset,Uruguay, to raise money against but imo it does not have the funds to do anything with it. LGO/CERP/BPC had an old trick to keep the gravy train running,they simply issued more shares at ever lower prices. This has been good for various directors but catastrophic for long term holders. My negativity has proved very accurate and you need only to look at the share price decline to see this.
mistt: Fair enough, I will play nicely Is their share price liquid and stable? Highly volatile share price over the past 3 months Share Price Fail Have shareholders been diluted over the past year? Shareholders have been substantially diluted in the past year Section 7.3 Fail Do they have sufficient financial data available? Latest financial reports are more than 6 months old Section 3.0 Fail Do they have meaningful levels of revenue? Does not have meaningful revenue ($4M) Section 3.1 Fail Do they have a meaningful market capitalization? Does not have a meaningful market cap (£10M)
12bn: CEG survives by issuing shares at lower and lower prices,this creates an ever lower price in the long run. CEG has litigation and this could be very expensive,imo it is best to avoid this dog. CEG does not make a profit even at these high oil prices,it loses money,if you want a pump n dump shares then this isn't it,imo. Many traders have been sucked in here over the years and lost massively,beware.
12bn: Off-shore drilling is expensive and CEG is low on funds imo. BPC put all its eggs in one basket of off-shore Bahamas drilling but all they got was a duster and debts and a collapsing share price This idea has failed once and I do not think CEG has the funds to try it again. It smacks of trying to persuade PIs to take a gamble on jam tomorrow. There are far better companies out there than this imo.
12bn: RNS Number : 6734F Challenger Energy Group PLC 23 March 2022 23 March 2022 Challenger Energy Group PLC ("Challenger Energy" or the "Company") Activity Update and Work Programme Challenger Energy (AIM: CEG), the Caribbean and Atlantic -margin focused oil and gas company, with oil production, appraisal, development and exploration assets across the region, is pleased to provide the following activity update and work programme guidance. Highlights -- Given the current strong oil price environment, the Trinidad business unit is profitable at current production levels of 350 to 400 bopd -- Near-term upside potential from production enhancing work presently underway, that is aiming to boost production, with resulting cashflow benefits -- Balance of the 2022 work programme being finalised, including infill drilling and EOR programs in Trinidad and pilot well testing in Suriname, in support of further increasing production and cashflow -- Appointed new Country Head in Trinidad with robust technical and production management expertise -- Company to enter Q2 2022 substantially debt free and with cash reserves available to support ongoing operations and investment in the planned production growth focused work programme Eytan Uliel, Chief Executive Officer of Challenger Energy said: "With our restructuring and recapitalisation process now complete, full attention is on growing the core business, through building production and generating cashflow. The higher oil price environment creates an even greater imperative to increase production and maximise every barrel of oil sold, and to that end we are immediately moving forward with some 'low-hanging fruit' operational items. The aim of this work is to stabilise and offset natural decline of baseline production, and then add 10% or more of new production, which can be readily monetised. Thereafter, we can begin to roll out our 2022 work programme, which will see drilling and EOR deployment across the fields, as we work towards achieving our overall sustainable production growth and cashflow targets. I look forward to keeping shareholders appraised of our progress." Oil Price and Financial Performance To date, this year, the Company has benefitted from more favourable oil prices compared to 2021. In the year 2022 to date, the Company has realised an average crude sales price of US$76.50 per barrel compared to US$60.00 per barrel for the full year 2021. The Company's crude production is sold to Heritage Petroleum Company Limited ("Heritage"), the Trinidadian state-owned oil company, at an approximate 10% to 12% discount to the West Texas Intermediate ("WTI") crude benchmark price. The Company does not currently use any hedging instruments in relation to its oil sales so is making full gain of the current pricing regime. Should the WTI benchmark continue to range between US$100.00 per barrel and US$120.00 per barrel as it has in recent weeks, the Company would expect to see realised prices in the range of US$90.00 and US$105.00 per barrel (assuming the discount to the WTI benchmark is consistent with the Company's recent past sales to Heritage). At realised prices within this range and based on current production levels (i.e., before any increased impact from near-term production enhancement / growth initiatives, or the broader 2022 work programme) the Company expects that its business in Trinidad will generate free-cash from operations for the 2022 calendar year. The Company would be able to direct some or all of this free-cash toward offsetting a portion of the Company's ongoing corporate overhead. As previously advised, the Company's ongoing corporate overhead has been substantially reduced following the recent restructuring and recapitalisation process, and is currently less than US$200,000 per month. Indicative netback calculations are included in the 'Illustrative Economic Outcomes' presented below. Illustrative Economic Outcomes The table below sets out indicative high-level potential economic outcomes for the Company's Trinidad business unit, on a per month basis, at each of 350, 400 and 600 bopd production levels, and assuming a range of realised oil price outcomes. This should not be read as Company forecasts, but is provided for illustrative purposes only. At US$75 per barrel At US$90 per barrel At US$105 per barrel US$000 unless 350 400 600 350 400 600 350 400 600 stated otherwise bopd bopd bopd bopd bopd bopd bopd bopd bopd ------- ------ ------ ------- ------ ------ ------- ------- ------ Gross Oil Sales p/m(1) 800 900 1,350 960 1,080 1,620 1,120 1,260 1,890 ------- ------ ------ ------- ------ ------ ------- ------- ------ CEG Sales Revenue p/m(2) 575 680 1,130 690 810 1,350 790 930 1,560 ------- ------ ------ ------- ------ ------ ------- ------- ------ Deductions p/m(3) (200) (240) (390) (240) (280) (460) (290) (340) (550) ------- ------ ------ ------- ------ ------ ------- ------- ------ SPT p/m(4) - - - (75) (90) (160) (100) (170) (210) ------- ------ ------ ------- ------ ------ ------- ------- ------ Operating Approximately 300 per month Costs p/m(5) -------------------------------------------------------------------------- Operating Netback p/m 75 140 440 75 140 430 100 170 500 ------- ------ ------ ------- ------ ------ ------- ------- ------ Annualised Netback p/a 0.9m 1.6m 5.2m 0.9m 1.6m 5.2m 1.2m 2.0m 6.0m ------- ------ ------ ------- ------ ------ ------- ------- ------ (Refer to footnotes at the end of this announcement.) Near-Term Production Enhancement Activities A programme of well recompletions at five identified wells has been approved by the Board and commenced. This will be complemented by targeted workovers at other identified offline and / or underperforming wells across the Company's producing fields. The necessary government permits for all of the planned works have been obtained, and it is expected that this work will be completed by the end of May 2022. In performing the recompletions, the Company will re-enter existing wells and perforate new sand reservoir horizons, potentially resulting in an immediate increase in oil production from the wells subject to recompletion. The Company is targeting a 10% or more increase in aggregate total production from these activities, with any incremental production able to be monetised immediately and thereby benefit from current strong oil prices. These near-term production enhancing activities will be supplemented by a package of well equipment and infrastructure purchases and upgrades (utilities, road and facilities) with the objective of maintaining and increasing production integrity, thereby improving field performance and reliability. This includes additional downhole pumps and well swabbing equipment, an increased capacity circulation pump to improve workover pace and efficiency, in-field generator sets to protect against frequent grid power outages, and road upgrades to improve year-round field access and rig cycle time. This program of purchases and upgrades is expected to be completed by the end of Q2 2022. The total anticipated cost of the above activities, purchases and upgrades is, in aggregate, approximately US$0.5 million, with rapid payback expected across the full range of activities. 2022 Work Programme In addition to the above-noted near-term production enhancement activities, Mr. Sohan Ojah-Maharaj, the newly appointed Trinidad Country Head, will lead the operations team in finalising of the work programme for the remainder of 2022, focusing on production growth. Highlights of the upcoming work programme are expected to include: -- an additional infill production well at South Erin (consistent with licence obligations), currently scheduled to be drilled in Q4 2022 with an estimated cost of less than US$1.5 million and targeting an additional 50 bopd of production; -- drilling an initial pilot production well in Suriname which is currently scheduled for Q3 2022. On completion the well will be put on an extended well test (EWT). The cost of the well and associated extended test is expected to be approximately US$0.7 million and will target an additional 20 bopd of production. The EWT is aimed at establishing the proof of concept for a broader field development which, in a success case, could result in production in excess of 500 bopd for the Company with favourable economics; and -- deployment of enhanced oil recovery ("EOR") techniques, including both waterflood and CO(2) injection, at the Goudron and Inniss-Trinity fields (consistent with licence obligations). This work is scheduled to commence in Q2 2022 and will run through the remainder of this year. The estimated cost of the initial EOR programme is US$1.2 million in aggregate and targets an additional 50 to100 bopd of production. The Company's objective is to exit 2022 with a stable production run-rate of approximately 600 bopd, which is expected to provide a springboard toward the Company's targeted stable production base of more than 1,000 bopd by the end of 2024 . Based on the outcomes of its production focused work programme during 2022, the Company would also expect to undertake a review of its reserves / resources in the first half of 2023. M&A As was noted in the Notice of Extraordinary General Meeting sent to shareholders on 9 February 2022, in addition to work designed to enhance and grow organic production from existing fields, the Company intends to pursue value-based, production accretive acquisition opportunities, as well as seek monetisation opportunities for exploration assets. To this end, management has intensified its focus on a number of potentially complementary opportunities in Trinidad, as well as various farm-out type opportunities. At this time, the Company is engaging in initial discussions and early-stage due diligence, and will provide updates, as applicable, in due course. Creditor Restructuring The majority of payments due under the previously announced creditor settlement agreements were paid as required during February 2022. A small number are due for payment in March 2022, and which are all expected to be made on time, in line with the description of creditor settlements as set out in the Notice of Extraordinary General Meeting sent to shareholders on 9 February 2022. As a result of these payments, the Company will have substantially eliminated all residual debts and payables associated with the drilling of the Perseverance-1 well. In addition, the non-recourse liabilities of the Company's various subsidiaries in Trinidad and Tobago have been reduced to less than US$2.5 million, an amount considerably lower than the approximate US$8 million inherited as part of the acquisition of Columbus Energy Resources PLC in August 2020. The Company expects that these remaining subsidiary-level liabilities will be gradually discharged in the ordinary course of business over the coming 12-18 months using operations derived income. The Company therefore expects to commence Q2 2022 debt and liability free at the corporate level, with subsidiary company liabilities significantly reduced and managed in the ordinary course of business. The Company's cash reserves will be applied toward general working capital and supporting a work programme through 2022 and 2023 which is focused on production growth, as previously described. No Russian Exposure The Company has no exposure to Russian oil production, and recently enacted sanctions have had no impact on the Company's business or operations. Corporate Presentation Additional information is set out in a new corporate presentation that was released on 16 March 2022, which is available on the Company's website ( ). --- Footnotes:
12bn: RNS Number : 4520J Challenger Energy Group PLC 27 April 2022 27 April 2022 Challenger Energy Group PLC ("Challenger Energy" or the "Company") Q1 2022 Update Challenger Energy (AIM: CEG), the Caribbean and Atlantic -margin focused oil and gas company, with oil production, appraisal, development and exploration assets across the region, provides the following update on its Trinidad and Tobago business unit's operating results for Q1 2022: -- Total gross oil production for Q1 2022 was 32,183 barrels, representing an average daily production rate of approximately 358 barrels. The gross production rate of approximately 400 bopd at the end of Q1 2022 has sustained consistently into April 2022. This current level of production is approximately 12% higher than the overall daily average for Q1 2022. The increase in average daily gross production is principally because of the successful recompletion work undertaken in March and April 2022 as communicated in the Company's previous announcement dated 20 April 2022. Additional near-term production enhancement activities are being planned for the coming months, with the objective of further increasing production by up-to an additional 10%. -- Total oil sales in Q1 2022 amounted to 29,727 barrels with a gross realised average price per sold barrel of US$83.37. It is noted that the realised gross average price per barrel sold in March 2022 was US$97.13, approximately 17% higher than the quarterly average, reflecting the rise in global oil prices seen through the quarter. The prices realised by the Company are at an approximately 10% discount to the quoted WTI prices. The Company does not currently use any hedging instruments in relation to its oil sales so is making full gain of the current pricing regime. -- Revenue received by the Company from oil sales (being gross revenues less Government royalties and mandatory source deductions and adjustments applicable under the relevant licences)(1) , amounted to approximately US$1.17 million in Q1 2022 and represents average net revenue to the company of US$39.29 per barrel sold. It is noted that average net revenue for the month of March was US$46.20 per barrel sold, approximately 17% higher than the quarterly average and, again, reflecting the increase in global oil prices seen through the quarter that continue to be sustained. -- In total, the Company's operations in Trinidad and Tobago generated an (unaudited) pre-tax operating cash surplus in Q1 2022 of approximately US$0.2 million. This surplus is stated after field operating costs, in-country G&A and other Trinidad expenses, but before corporation and other taxes (including supplemental petroleum tax, where applicable). It is noted however that, given large carry-forward tax losses in Trinidad and Tobago, t he Company is currently largely shielded from corporation taxes. -- The improved operating and financial performance of the Company's Trinidad and Tobago operations during Q1 2022 was achieved despite a number of material disruptions to operations and production caused by grid power supply issues. This included an extended nationwide grid outage in February 2022 that caused production facilities and well pumps to go offline for an extended time. To mitigate against potential recurrences, the Company is upgrading in-field power infrastructure including installation of a new transformer and several generator-sets in the Company's primary producing fields. In addition, other planned facilities and infrastructure upgrade works continue, so as to improve day-to-day production integrity and operational resilience. The objective of this work is to protect and maximise the Company's cash generating capacity. Eytan Uliel, Chief Executive Officer of Challenger Energy, said: "During the first quarter of 2022 our Trinidad and Tobago operations generated a cash operating surplus, based on production that averaged around 360 bopd, and realised oil prices across the quarter averaging approximately US$83 per barrel. This encouraging first quarter result reflects a renewed focus on routine operations, stringent cost control, and the committed efforts of everyone in the Challenger Energy team. I'd also note that both average production and realised prices achieved in the first quarter of 2022 are considerably below the levels we are seeing as we start the second quarter, where the Company is benefitting from continued strong oil prices globally and higher production. The increased and more stable base line production we are currently enjoying has been gained through a targeted work programme aimed at production enhancement, made possible due to the successful completion of our restructuring and recapitalisation in March 2022. We have more production accretive work being planned for the coming quarters and I look forward to reporting on further improvements as the year progresses". --- Note 1: Oil sales are predominantly made to Heritage Petroleum Company Limited, the Trinidadian national oil company, who then apply certain deductions and adjustments before payment of funds to the Company. These vary between various licences, and include deduction of Government royalties, Heritage overriding royalties, facilitation fees, escrow and mandatory contributions to the abandonment fund, oil impost, and in respect of Goudron and Inniss-Trinity only, deduction of agreed first tranche volume and addition of an agreed handling fee. This announcement contains inside information for the purposes of Article 7 of EU Regulation 596/2014, which forms part of United Kingdom domestic law by virtue of the European Union (Withdrawal) Act 2018 (as amended). For further information, please contact:
12bn: No one knows where the share price will go for certain but we do know the fundamentals here are poor. CEGs income comes from old CERP legacy wells which tend to have falling production rates and do not create a group profit. Most of these wells are under an IPSC contract which means CEG only gets a net back from the Trinidad govt. The recent price rises took this net back to $46 a barrel,up from $39 a barrel in Q1,so don't think that a big price spike results in a massive change in CEGs income,it doesn't. Shares are valued by what MMs see with supply and demand,so a loss maker like this with a new 'fairy story' can rise above what fundamentals suggest but CEG could at any point issue new shares and the share price could then crash.
tomboyb: Challenger Energy Group PLC Uruguay Licence Signing 26/05/2022 7:01am UK Regulatory (RNS & others) Challenger Energy (LSE:CEG) Intraday Stock Chart Thursday 26 May 2022 Click Here for more Challenger Energy Charts. TIDMCEG RNS Number : 8985M Challenger Energy Group PLC 26 May 2022 26 May 2022 Challenger Energy Group PLC ("Challenger Energy" or the "Company") Uruguay Licence Signing Challenger Energy (AIM: CEG), the Caribbean and Atlantic-margin focused oil and gas company, with oil production, appraisal, development and exploration assets across the region, provides the following update in relation to the AREA OFF-1 petroleum licence offshore Uruguay. -- The AREA OFF-1 licence was awarded to the Company in May of 2020. Since that time there has been an extended period on non-activity, largely as a result of the Covid-19 pandemic, during which formal signature of the licence was pending. -- Following final approvals being granted by decree of the President of Uruguay, the AREA OFF-1 licence was formally signed on 25 May 2022. Consequently, the first 4-year exploration period under the licence has commenced. -- The Company's minimum work obligation during this initial period is to undertake relatively modest, low-cost reprocessing and reinterpretation of selected historical 2D seismic data. There is no drilling obligation in the initial phase. The Company's work program and budget for the balance of 2022 and into 2023 includes sufficient allocation of funds to progress the agree minimum work obligation on AREA OFF-1. -- AREA OFF-1 contains a management estimated resource potential exceeding 1 billion barrels of oil equivalent recoverable (BBOE), based on current mapping from multiple exploration plays and leads in relatively shallow waters, and with significant upside running room. This estimate is corroborated by formal resource estimates provided by ANCAP (the Uruguayan national oil company) of 1.36 BBOE as a P50 expected ultimate recoverable resource. -- The AREA OFF-1 play system is directly analogous to the recent prolific, conjugate margin discoveries made offshore Namibia by Total (the Venus well) and Shell (the Graff well), where reported multi-billion-barrel Cretaceous turbidite reservoirs have been encountered. The AREA OFF-1 licence exhibits the same Aptian play source rock and petroleum systems being present. -- The Company has received multiple indications of interest in relation to potential partnerships for the AREA OFF-1 licence. The Company intends to explore such possibilities, with a view to potentially expediting a 3D seismic acquisition into the first licence exploration period. Further updates will be provided as and when appropriate. Eytan Uliel, Chief Executive Officer of Challenger Energy, said: "Two years ago, at the peak of a period of industry inactivity due to the pandemic, we identified a compelling opportunity to apply for the OFF-1 licence in Uruguay. For very low cost we were able to secure an exploration licence of an extremely high quality, with a greater than 1-billion-barrel recoverable resource potential. Since then, while waiting for formal approval of the licence, the world has changed in a way that makes this licence even more attractive. Globally significant developments are now underway along the South American Atlantic margin in Guyana and Suriname - basins with analogous technical characteristics. Even more significantly, very recent mega-discoveries from the South Atlantic conjugate margin to Uruguay, offshore Namibia, from two wells drilled by majors in the past few months, have calibrated and confirmed the play source rock and petroleum systems evident on seismic in OFF-1. With the licence formally signed, we are now able to begin pushing ahead with our initial low-cost work program. At the same time, over the remainder of 2022 and into 2023 we will explore partnering options that could lead to an accelerated work program - the object being to quickly and fully evaluate the licence's potential, and to thereby create what we hope will be an opportunity of great value to shareholders." A presentation in relation to OFF-1 will be placed on the Company's website - . About AREA OFF-1 The AREA OFF-1 licence has a total area of approximately 15,000 km(2) and is situated in water depths from 20 to 1000 meters, approximately 100 kms off the Uruguayan coast. There has been modest prior legacy activity on and adjacent to the AREA OFF-1 block, comprising historical 2D seismic (approximately 8,500 -kilometres acquired from the early 1970's to 2011 on block). Only two historic wells have been drilled to-date in the area (both in 1976 by Chevron), with no 3D coverage over AREA OFF-1. Current mapping reveals a diversity of exploration plays and leads in relatively shallow water and the slope margin, with a preliminary estimated resource potential of more than 1 billion barrels of oil equivalent (BBOE) recoverable. Given the successfully bid fiscal regime and the water depths of the identified prospects, Challenger Energy's preliminary analysis suggests that any of the individually mapped current prospects is likely to be economic, even if historically low oil prices are assumed. During 2019, oil majors Shell, BP, Total and Equinor bid for and were awarded various licences offshore Argentina, adjacent to AREA OFF-1 proximal to the Argentina-Uruguay maritime border, and where the primary well targets in these Saladio Basin licences are likely to be the same as the Cretaceous syn rift and turbidite plays potentially present in AREA OFF-1. In January 2022 both Total and Shell announced multi-billion-barrel discoveries from wells drilled in the Namibia offshore margin. The AREA OFF-1 exploration play is analogous to these recent Namibia conjugate margin discoveries, with the Namibian well results significantly de-risking the technical understanding of the analogous Uruguay South Atlantic margin. AREA OFF-1 also has technical characteristics in common with the prolific Guyana - Suriname basin currently being successfully explored / developed by multiple oil companies, offshore north-eastern South America. Uruguay is located in south-east South America, bordering Brazil and Argentina, and with a broad Atlantic Ocean coastline. The country has a relatively high income per-capita in the region, and represents an advantaged operating regime, frequently ranking first in Latin America in measures such as democracy, anti-corruption, and ease of doing business. AREA OFF-1 Licence Terms The following table provides a summary of the key AREA OFF-1 licence terms:
12bn: 12bm is not me,I am 12bn,12bm is probably another alias of arry. This is a loss maker losing $200k a month and earning only $200k every 3 months. If they issue more shares here then you could all get burned imo. CEG have the right to issue up to another 8000 million new shares.////////BigSi2 - 29 Apr 2022 - 11:08:35 - 11112 of 11461 challenger energy group - CEG My prediction - Ceg Will burn through its recently raised cash to marginally increase its production over the next 12 months, during which natural steep decline rates will continually offset increases- all this time running at a loss due to existing states corporate shortfall. Then CEG within 12 months will resort to share issuance and utilise the 8BN ADDITIONAL shares it recently voted itself the authority to issue
12bn: 12bn - 20 May 2022 - 08:34:14 - 11355 of 11379 challenger energy group - CEG CER1TH - 29 Jun 2021 - 07:54:17 - 1782 of 11355 challenger energy group - CEG 2p looks doable?? You mean 20p..?/////////CER1TH - 04 Aug 2021 - 15:38:44 - 3873 of 11356 challenger energy group - CEG Get the news to the 88E boards..They'll love this ride in the next couple of weeks 5-6p here we come..////////// PMSL again,what an idiot. 12bn - 20 May 2022 - 08:30:18 - 11354 of 11379 challenger energy group - CEG CER1TH - 22 Jun 2021 - 09:34:53 - 1399 of 11354 challenger energy group - CEG 3p share price has triggered some nice buying .. Next run up??//////////CER1TH - 24 Jun 2021 - 07:55:42 - 1551 of 11355 challenger energy group - CEG 10p very soon.. GLA////////// PMSL 12bn - 20 May 2022 - 08:27:33 - 11353 of 11379 challenger energy group - CEG CER1TH - 21 Jun 2021 - 16:07:44 - 1274 of 11353 challenger energy group - CEG Looking good here with buys coming in.. GLA//////// This where you bought in,around the 4p area and the share price is now 0.115p bid. You are a typical CEG MUG.
Challenger Energy share price data is direct from the London Stock Exchange
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