25 June 2019
Genel Energy plc
Commencement of share buy-back
Genel Energy plc ('Genel' or 'the Company') will commence a share buy-back programme of up to $10 million in the period up to and including 5 July 2019 (being the last day of trading prior to the Company entering a close period ahead of its half-year results).
The programme will be effected in accordance with the authority granted by the shareholders at the most recent AGM, pursuant to which the maximum number of ordinary shares that may be bought back is 27,924,235.
Genel believes that the current share price does not accurately reflect the value of the Company's assets, and that utilising its balance sheet to repurchase shares represents a value accretive use of its cash resources.
Genel has ongoing material cash generation from producing assets that more than funds our significant organic growth opportunities - with Sarta, Qara Dagh, Bina Bawi and Miran providing an attractive mix of near-term production and long-term growth potential. Organic growth from our existing portfolio has the potential to significantly increase production in coming years, and the ongoing cash generation led to the instigation of a material and sustainable dividend, as we look to provide investors with a compelling mix of growth and returns.
It is currently intended that the purchased shares will be held as treasury shares.
Following the share buy-back, Genel will retain more than sufficient liquidity to further add to the strength of the portfolio, and is actively pursuing opportunities to do so.
The Company has entered into an agreement with Canaccord Genuity Wealth Limited to conduct the programme.
Any buy-back of the Shares pursuant to the Programme will be effected in accordance with Chapter 12 of the UKLA Listing Rules, the EU Market Abuse Regulation 596/2014 and the Commission Delegated Regulation (EU) 2016/1052 (and within the meaning of this Regulation the purpose of the
Programme is to reduce the capital of the Company). The market will be notified in accordance with those rules if and when purchases are made.
8 May 2019
Genel Energy plc
Update on Tawke PSC
Genel Energy plc ('Genel') notes that DNO ASA, as operator of the Tawke PSC (Genel 25% working interest), has today issued an update on licence activity:
Gross production from the Tawke licence, containing the Tawke and Peshkabir fields, averaged 126,759 bopd during the first quarter of 2019.
Tawke production currently averages c.73,000 bopd, and Peshkabir c.54,000 bopd. There is an active 2019 drilling campaign underway at the Tawke and Peshkabir fields, with a total of up to four Peshkabir wells and up to 14 Tawke wells.
The Peshkabir-9 well was completed and placed on production during the first quarter. The Peshkabir-10 well was spud in February and will come onstream shortly. The Peshkabir-11 well will spud later this month. Peshkabir production averaged 53,830 bopd during the first quarter.
Peshkabir has now generated $1 billion in gross revenue, or four times the total spend to date.
At the Tawke field, the Tawke-52 Cretaceous well was completed and placed on production during the quarter. The Tawke-54 Cretaceous well was spud in February and came onstream in mid-April, and the Tawke-55 Cretaceous well spud in April. Tawke field production averaged 72,929 bopd during the first quarter.
RNS Number : 4613X
Regal Petroleum PLC
30 April 2019
30 April 2019
REGAL PETROLEUM PLC
2018 AUDITED RESULTS
Regal Petroleum plc (the "Company", and with its subsidiaries, the "Group"), the AIM-quoted (RPT) oil and gas exploration and production group, today announces its audited results for the year ended 31 December 2018.
Aggregate average daily production from the MEX-GOL, SV and VAS fields over the year to 31 December 2018 of 3,391 boepd, which compares with an aggregate average daily production rate of 2,235 boepd during 2017, an increase of nearly 52%.
Aggregate 2018 year end production of approximately 4,377 boepd, compared with approximately 2,811 boepd at 2017 year end, representing an increase of nearly 56% during the year, largely as a result of the significant contributions from the MEX-109 and SV-2 wells, which were operational for the full year, and additional contributions coming on stream during the year from the SV-12 and VAS-10 wells
Reserves upgrade at MEX-GOL and SV fields announced in July 2018, approximately quadrupling 2P reserves to 50.0 MMboe, enabling an enhanced development programme for these fields
Workover of SV-12 well successfully completed and brought on production in July 2018
VAS-10 well successfully completed and brought on production in November 2018
Revenue for the year to 31 December 2018 up 88.3% to $66.1 million (2017: $35.1 million)
Gross profit for the year up 216.7% to $34.2 million (2017: $10.8 million)
Cash generated from operations during the year of $36.8 million (2017: $18.0 million)
Net profit for the year of $54.3 million (2017: $2.3 million), including a one-off item of $36.1 million relating to impairment reversal of oil and gas development and production asset (as a result of reassessment of the remaining reserves and resources at the MEX-GOL and SV fields as at 31 December 2017)
Average realised gas, condensate and LPG prices in Ukraine for the year to 31 December 2018 of $312/Mm3 (UAH8,528/Mm3), $72/bbl and $64/bbl respectively (2017: $241/Mm3 (UAH6,412/Mm3) gas, $67/bbl condensate and $56/bbl LPG)
Cash and cash equivalents of $53.2 million at 31 December 2018 (31 December 2017: cash resources of $30.2 million comprising cash and cash equivalents of $14.2 million and short-term investments of $16.0 million), with cash and cash equivalents at 25 April 2019 of $54.2 million, held as $24.2 million equivalent in Ukrainian Hryvnia and the balance of $30.0 million equivalent predominately in US Dollars, Euros and Pounds Sterling.
Development work for 2019 at MEX-GOL and SV fields: completion of geophysical studies on existing seismic data and refinement of new geological model; completion of MEX-119 well; commencement of new well in SV field; planning for further new well in SV field; hydraulic fracturing of MEX-120 well; assessment and workover of existing wells; installation of compression equipment; and continued investment in gas processing facilities, pipeline network and other infrastructure
Development work for 2019 at VAS field: completion of processing and interpretation of new 3D seismic data; development of new geological model; reassessment of remaining reserves and resources; planning for a new well; installation of compression equipment; and continued investment in gas processing facilities, pipeline network and other infrastructure
2019 development programme expected to be funded from existing cash resources and operational cash flow
The Annual Report and Financial Statements for 2018, together with the Notice of Annual General Meeting, will be posted to shareholders and published on the Company's website during May/June 2019.
This announcement contains inside information for the purposes of Article 7 of EU Regulation 596/2014.
Genel Energy plc ('Genel' or 'the Company') provides the following update on the Bina Bawi licence.
As previously announced, the deadline to meet the conditions precedent relating to the Bina Bawi gas lifting agreement ('GLA') was extended until 30 April 2019, as discussions with the Kurdistan Regional Government ('KRG') on the commercial framework relating to the development of the licence continued.
Having reached agreement that the existing GLA does not reflect the commercial realities of the proposed development, Genel and the KRG ('the Parties') have jointly agreed to let the GLA lapse on 30 April 2019 and focus on negotiating updated commercial terms based on a staged and integrated oil and gas development. The Parties are progressing the negotiation of a project scope based on a phased approach and ramp up of the gas development, with an initial phase of c.250 MMscfd raw gas capacity, and an accelerated development of the oil scope, where the KRG and Genel will jointly fund the first phase gas development utilising the revenue from Bina Bawi oil.
The Parties have agreed to focus on finalising the commercial arrangement for this solution as soon as practical. The current production sharing contract ('PSC') provides a further 12 month period from 30 April 2019 within which to agree a new GLA. Should no agreement be reached in twelve months, the KRG has a right to terminate the PSC.
In line with our capital allocation strategy, the Company will only proceed with significant investment in Bina Bawi once an agreement is reached on a commercial framework that provides a clear route to monetisation.
The deadline for the Miran conditions precedent will be reached on 31 May 2019 and the Company similarly expects that the Miran GLA will lapse.
RNS Number : 8699W
TransGlobe Energy Corporation
24 April 2019
This Announcement contains inside information as defined in Article 7 of the Market Abuse Regulation No. 596/2014 ("MAR"). Upon the publication of this Announcement, this inside information is now considered to be in the public domain.
TRANSGLOBE ENERGY CORPORATION ANNOUNCES
AN OPERATIONS UPDATE
AIM & TSX: "TGL" & NASDAQ: "TGA"
Calgary, Alberta, April 24, 2019 - TransGlobe Energy Corporation ("TransGlobe" or the "Company") announces a Q1 operations update. All dollar values are expressed in US dollars unless otherwise stated.
· Production averaged ~15.9 MBoepd in Q1 2019 (January ~15.8 MBoepd, February ~15.0 MBoepd and March ~16.9 MBoepd) versus 15.3 MBoepd in Q4 2018;
· Drilled 2 oil wells (M 10, NWG 38A8) and re-entered/deepened 2 water disposal wells (K 8 & K 10) during the quarter;
· Drilled a new pool oil well (HW 2X) in West Bakr with an estimated 113 feet of net oil pay subsequent to the quarter;
· Submitted South Ghazalat 6X development lease to EGPC for approval;
· Equipped and tied in six Cardium oil wells (2018 program) in the Harmattan area, Canada during January;
· Net proceeds of ~$25 million received in April for a cargo lifted in mid-March;
Corporate production increased during the first quarter due to drilling and well optimization results in Egypt and new wells in Canada, which was partially offset by reduced ethane production in Canada.
ARAB REPUBLIC OF EGYPT
During the quarter:
Drilled and completed the M-10 replacement well (M-10 Twin) as an Asl A oil producer which was placed on production in February and is currently producing ~400 Bopd.
Drilled the NWG 38A-8 well to a total depth of 5,350 feet and cased as a potential Red Bed oil well/water injector. NWG 38A-8 was targeting the southern area of the NWG 38A Red Bed pool to provide water injection/reservoir pressure support for the 38A pool. The well was completed and placed on production at an initial average rate of 45 Bopd and 100 Bpd of water, confirming the well had intersected the oil water contact for the pool. Based on early production results, the well will be converted to water injection during Q2 to initiate water injection and pressure support for the NWG 38A pool.
Re-entered/deepened two suspended oil wells and converted them to water disposal wells (K-8 WDW and K-10 WDW).
Subsequent to the quarter:
Drilled a discovery oil well in H Block. The HW-2X exploration well was drilled to a total depth of 1,654 meters (5,425 feet) and cased as a Yusr oil well. Based on open-hole logs and wireline samples, the well encountered an internally estimated 34.5 meters (113 feet) of net oil pay in the Yusr formation. The HW 2X well is scheduled for completion this month and expected to be on production in early May. Following HW-2X, the drilling rig is scheduled to drill two development wells at (H-30 and K-63) and one exploration well (NWG 38 D-1).
Based on the previously announced (11/19/18) well test results* from SGZ-6X (3,840 Bopd of light oil), the Company filed a South Ghazalat development lease application with EGPC in late February.
Subject to final approvals by EGPC, the Ministry and necessary regulatory approvals, the Company is targeting first production prior to year end. Concurrent to the construction of an early production facility and equipping SGZ 6X for production, the Company has submitted permits to drill an appraisal well in the SGZ 6X pool during the second half of 2019 and initiated a project to merge and reprocess two existing 3D seismic surveys over the proposed development lease area. In addition to the planned appraisal well, the Company is committed to drill a minimum of one additional exploration well.
*The SGZ-6X tested a combined 3,840 barrels per day of light oil from the upper and lower Bahariya. The lower Bahariya formation flowed naturally at an average rate of 2,437 barrels per day of light (38 API) oil, 21 barrels per day of water and 1.4 million cubic feet of natural gas per day on a 40/64 inch choke from a 42 foot perforated interval. A total of 918 barrels of oil and 7 barrels of water were produced during the 10 hour test. The upper Bahariya formation flowed at an average rate of 1,403 barrels per day of light (35 API) oil, 210 barrels per day of water and 1.0 million cubic feet of natural gas per day on a 64/64 inch choke from a 23 foot perforated interval. A total of 456 barrels of oil and 65 barrels of water were produced during the 8 hour test. Although encouraging, test rates are not necessarily indicative of long-term performance or ultimate recovery.
The Company continued South Alamein extension discussions with EGPC during the first quarter and resubmitted a request for military access to drill the SA 24X Jurassic exploration prospect, which was rejected by the military in April. Based on the 2017 well results in the Boraq area, the limited commerciality of the original Boraq 2 discovery (2009) and continued access restrictions in the eastern area of the concession, the Company is exploring a variety of extension options with EGPC, which include partial, or possibly complete, relinquishment of the concession.
In early January, the Company completed the equipping and tie-in of the six Cardium wells drilled and completed in the Harmattan area in late 2018. The wells were brought on production in a systematic manner in order to maximize ultimate recoveries, however this process was hampered somewhat by facility outages and extremely cold winter weather during the quarter.
The main gas processing plant (third party) for the Company's gas production shut down their deep cut ethane extraction plant in January due to low ethane prices and pipeline egress issues in Alberta. It is expected that the ethane will remain in sales gas until the fourth quarter at a minimum, which will be sold with a higher energy content and is expected to be generally revenue neutral, due to the low prices for ethane. It is estimated that approximately 250 boepd of ethane is now sold as natural gas.
RNS Number : 8694W
Diversified Gas & Oil PLC
24 April 2019
Diversified Gas & Oil PLC
("Diversified" or the "Company")
Enlarged Credit Facility Borrowing Base
Diversified Gas & Oil PLC (AIM: DGOC), a U.S.-based owner and operator of natural gas, natural gas liquids, oil wells and midstream assets in the Appalachian Basin, is pleased to announce details of its expanded and fully underwritten borrowing base of $950 million.
Following the Company's recent successful acquisition of Appalachian gas producing assets from HG Energy II Appalachian, LLC, Diversified's bank syndicate, led by KeyBank National Association, has been enlarged. Accordingly, the borrowing base available under its $1.5 billion facility has been increased 31% from $725 million to $950 million. Funded in part by its senior secured revolving credit facility first agreed to in March 2018, the Company has acquired more than $1.3 billion of long-life, low-decline gas and oil producing assets in the Appalachian Basin contributing to pro-forma daily net production of more than 90,000 barrels of oil equivalent per day.
The bank syndicate has been increased from twelve to fourteen banks and now includes Deutsche National Bank ("DNB") and BBVA Compass. Royal Bank of Canada ("RBC") also joined the bank syndicate at the Company's previous redetermination in December 2018.
In addition, the Company has negotiated a 25 basis points reduction to each tier of the facility's pricing grid, lowering the spread by nearly 10%. The current pricing grid for amounts drawn on its facility is LIBOR plus 2.0%-3.0% depending on utilization.
Reflective of the higher borrowing base underpinned by the quality of the acquired assets, the Company's post-acquisition liquidity exceeds pre-acquisition levels while leverage remains unchanged at 1.8x Net Debt-to-EBITDA. Diversified's current liquidity is approximately $330 million and remains available to fund organic development and further acquisitions.
Rusty Hutson, Jr., CEO of Diversified commented "I would like to express my gratitude to our banking group for their continued commitment to Diversified's vision. We are thrilled to welcome RBC, DNB and BBVA Compass to the family of world-class banks participating in our facility. It's hard to believe that the credit facility we established in March 2018 with a borrowing base of $200 million has grown nearly 500% in just one year to its current $950 million level, which is a reflection of the high quality, long-life reserves that underpin our assets. With liquidity exceeding $330 million and a lower interest rate on borrowings, we can complete meaningful acquisitions without the need for additional share placings while simultaneously maintaining our commitment to low leverage with Net Debt-to-EBITDA of approximately 2x."
This announcement contains inside information for the purposes of Article 7 of EU Regulation 596/2014.
HH Portland Oil Field Declared Commercially Viable
RNS Number : 4111E
UK Oil & Gas PLC
18 October 2018
UK Oil & Gas PLC
("UKOG" or the "Company")
Horse Hill Portland Oil Field Declared Commercially Viable
Horse Hill-1 ("HH-1") Portland and Kimmeridge Oil Discovery, Weald Basin, UK
UK Oil & Gas PLC (London AIM: UKOG) announces that Horse Hill Developments ("HHDL"), a UKOG subsidiary company and the operator of the HH-1 Kimmeridge Limestone and conventional Portland Sandstone oil discovery, has informed the Company that, following the successful Portland Extended Well Test ("EWT") programme, it now considers the Portland oil field to be commercially viable.
HHDL now targets the start-up of long term Portland oil production during 2019, subject to the grant of necessary regulatory consents. The first future horizontal production well, HH-2, for which planning and Environment Agency consents are in place, is planned to be drilled in early 2019. HH-1 is located in licence PEDL137 in which UKOG holds a 46.735% beneficial interest. Key points and further details are summarised below:
· Following analysis of EWT results and economic modelling of HHDL's and Xodus Group's ("Xodus") forecast oil production profiles, HHDL now considers the Portland oil field to be commercially viable. Work is now underway towards a targeted long-term production start-up in 2019.
· HHDL currently envisages the Portland field development plan to consist of up to 3 production wells and up to 2 pressure support wells.
· A planning application for Portland and Kimmeridge field development is nearing completion and is targeted for submission to Surrey County Council ("SCC") before year-end.
· Xodus' calculated future Portland oil production profiles, based upon observed pressure and volumetric data from the EWT, show that oil recoveries of up to 45% of connected Oil in Place could be attained if a successful full voidage replacement pressure support scheme is incorporated into the field's development.
· The Portland field's first new horizontal production well, HH-2, which has SCC planning and Environment Agency consents, is planned to spud in early 2019 following completion of the Kimmeridge Limestone 4 EWT.
· As reported on 10 September, the HH-2 horizontal well has a targeted* sustainable daily Portland production rate of 720 to 1,080 bopd, 2 to 3 times the calculated* sustainable vertical well rate of 362 bopd derived from the EWT programme.
· Following submission of the planning application, Xodus' 2018 Portland Competent Persons Report will be updated to include recoverable reserves and net present values of cash flows associated with the envisaged Portland oil field development.
Note: * There can be no absolute guarantee that forecast, targeted or calculated rates of production will be achieved.
Stephen Sanderson, UKOG's Chief Executive, commented:
"HHDL's declaration of Portland commercial viability is a significant milestone for the Company. It transforms Horse Hill from solely exploration into a fully-fledged field development with a full-scale oil production start-up targeted in 2019.
The better than expected EWT results have robustly demonstrated that the Portland has significant daily production potential in its own right, which could see the first planned horizontal producer attain sustained oil rates of 720-1,080 bopd. If realised, these rates could make the Horse Hill Portland oil field one of the UK onshore's top producers.
We also eagerly anticipate the possibility of combined long-term production from both the Portland and Kimmeridge, an exciting and potentially transformational prospect for Horse Hill and the Company."
RNS Number : 0583A
International Cons Airlines Group
06 September 2018
THEFT OF CUSTOMER DATA AT BRITISH AIRWAYS
International Airlines Group's subsidiary, British Airways, is investigating, as a matter of urgency, the theft of customer data from its website, ba.com and the airline's mobile app. The stolen data did not include travel or passport details.
From 22:58 BST August 21 2018 until 21:45 BST September 5 2018 inclusive, the personal and financial details of customers making bookings on ba.com and the airline's app were compromised.
The breach has been resolved and ba.com is working normally.
British Airways is communicating with affected customers and the airline advises any customers who believe they may have been affected by this incident to contact their banks or credit card providers and follow their recommended advice.
British Airways has notified the police and relevant authorities.
Alex Cruz, British Airways' Chairman and Chief Executive said: "We are deeply sorry for the disruption that this criminal activity has caused. We take the protection of our customers' data very seriously."
British Airways will provide further updates when appropriate.
TULLOW OIL: The production vessel at Tullow's flagship Jubilee oilfield off Ghana's west coast will shut down next week for 21 days while it undergoes repairs, the country's power utilities said on Monday.
Glencore on Friday said it could not comment on a report by Bloomberg that it may face an enquiry from Britain's Serious Fraud Office into allegations of bribery linked to its operations in Democratic Republic of Congo.
Watch out for increased shorts.
FAROE/DNO: Norwegian oil firm DNO, which early on Wednesday bought a 15.4 percent stake in Faroe Petroleum, said after market close that it aims to further raise its holdings in the British company to around 25 percent.
RNS Number : 6678A
02 January 2018
US tax changes - estimated impact on BP results
BP expects its future US after-tax earnings to be positively impacted by the recently-enacted changes to US corporate taxes, largely due to the reduction of the US federal corporate income tax rate from 35% to 21% (effective 1 January 2018). The ultimate impact of the change in the US corporate income tax rate is subject to a number of complex provisions in the legislation which BP is reviewing.
The lowering of the US corporate income tax rate to 21% requires revaluation of BP's US deferred tax assets and liabilities. The current estimated impact of this will be a one-off non-cash charge to the Group income statement of around $1.5 billion that will impact BP's fourth quarter 2017 results. Details of the final actual charge are expected to be disclosed in BP's fourth quarter 2017 results announcement, due on 6 February 2018.
BP press office, London: +44 (0)20 7496 4076, firstname.lastname@example.org
In order to utilize the 'safe harbor' provisions of the United States Private Securities Litigation Reform Act of 1995 (the 'PSLRA'), BP is providing the following cautionary statement. This press release contains certain forward-looking statements - that is, statements related to future, not past events - which may relate to one or more of the financial condition, results of operations and businesses of BP and certain of the plans and objectives of BP with respect to these items. These statements are generally, but not always, identified by the use of words such as 'will', 'expects', 'is expected to', 'aims', 'should', 'may', 'objective', 'is likely to', 'intends', 'believes', 'anticipates', 'plans', 'we see' or similar expressions. Actual results may differ from those expressed in such statements, depending on a variety of factors including the risk factors set forth in our most recent Annual Report and Form 20-F under "Risk factors" and in any of our more recent public reports.
Our most recent Annual Report and Form 20-F and other period filings are available on our website at www.bp.com, or can be obtained from the SEC by calling 1-800-SEC-0330 or on its website at www.sec.gov.
Do you guys think this is going back to 115.00 soon?
Always on a friday we see SP drop.
Brent at $58.18 this afternoon.
I think we could see $60 a barrel before end of September.
Let's see what today's EIA data has to say.
Broadly in line with expectations with Revenue and Other Income together in excess of £100 million and bottom line before exchange variances near breakeven.
No real surprises in trading update as said before the real growth will come over the next few years, but nice to see making positive progress.
I do however, think given current Crude prices and entering the winter months as demand increases the SP is well undervalued especially with DELEK in the background.
IMO only a short time before this is trading above £1.