Member Info for Gotham

Hi, can the existing compressors be upgraded to produce more gas if needed. Thankyou. Asked on 1 July 2022
We left space for a third compressor in order to handle any potential pressure drop in the two existing wells. If the sidetrack pressure keeps the average across the three high, then we could use the third compressor to increase flow rates. All of the units were sized around 10mmscfd (the target production after side-track) but were build with a degree of redundancy and subject to risk assessment we could increase flow beyond that amount. That assessment will be easier to do once we have steady flow

Angus investor questions

Question:You expect the 2 wells to produce 1.5 mil therms of gas a month. But am I correct in thinking those 2 wells could produce more?

And would I be correct in assuming there is enough capacity onsite for gas from the two wells up to 3 mil therms?

Regardless of the sidetrack

Answer: The field having been shut in for so long, all the technical experts expect increased deliverability during the first six months of production. Additionally it was always open to the old Operator to run the wells a bit harder. Generally there are technical risks to pushing a well too hard, but we think that we could do better than 1.5m therms and, likewise the site equipment has some flex in terms of capacity but it would require some thought and planning.

Before the side track HITs. Nice to leave stuff out.

Mirasol a troll for the loan company.

Thats your opinion not a fact. Back it up?

No one pays a hedge up front with no gas !

Just a reminder

The Saltfleetby Gas Field is located onshore UK in licence PEDL005, East Lincolnshire. The field was discovered in 1996 and produced gas from both the Westphalian Sandstones and Namurian reservoirs and was, upon discovery, the largest onshore gas field in the UK with a GIIP of 114 BCF. Production began in 1999 at rates exceeding 50 MMScf per day and produced gas, water, and condesnate was piped via a 10” pipeline to the nearby Theddlethorpe Gas Terminal (TGT) where it was processed and sent into the National Grid. Eight wells and several sidetracks have been drilled on the site.

https://twitter.com/angusenergyplc/status/1537714896271458306?t=u1wyMqxfX4iBR8wafsiBdw&s=19

Western Gas is planning to drill up to four exploration wells in Exploration Permits WA-518-P and WA-519-P, located in Commonwealth Waters in the Carnarvon Basin offshore Western Australia. Drilling activities are planned to start at the earliest in Q4 2020 subject to approvals, vessel availability and weather constraints. Western Gas will advise relevant stakeholders once well locations and timing have been finalised. An Environment Plan for the proposed activities will be submitted to the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA) and will be made available for public comment following a completeness check by NOPSEMA. NOPSEMA acceptance of this plan is required before any petroleum activity can commence. The Environment Plan will cover well design and drilling operations, installation and testing of well safety equipment, well evaluation and plugging activities prior to abandonment of the wells. Western Gas is Operator and 100% owner of WA-518-P and WA-519-P and the adjacent Equus Gas Project, which is currently in planning phase with first gas planned for 2024.

David confirming 10% of the large block and all targets. Not just this drill.

https://www.oedigital.com/news/496258-east-timor-aiming-for-greater-sunrise-offshore-gas-field-output-by-2030

HFB the goverment have no choice. Their only source of income for the island dies shortly.

Mr P
Thats from January and gas prices are much higher now. Also rumours that the 3d scan has shown up oil and a bigger resource of gas.

Next year they have to drill as per T&Cs. They say they will enter via the old Shell drill site but drill side ways to the sweet spot.

Look at the presentations on Barons website
https://www.baronoilplc.com/

From their report

Valuation

Our valuation methodology for Baron is based on a sum-of-the-parts calculation where the parts are the different projects. Chuditch is by far the most influential which leaves the stock very much a play on the project. For each project the key components of the valuation are the net resource base, a risking factor which takes into account our assessment of commercialisation at this stage of development and a valuation quotient expressed in $/boe. We have used $0.5/boe for this purpose. Note, we adjust working interests where appropriate for anticipated farm-ins for the first stage of appraisal/exploration. In the case of Chuditch we have assumed that Baron will be seeking a free-carry farm-in and that this will necessitate conceding 50% of the equity in the project. Its working interest will therefore drop from 75.0% to 37.5%.

We are leaving our absolute and per/share valuations unchanged from our September 2021 interim report at £30.9m and 0.27p/share respectively. In a success case for the initial drilling programme at Chuditch we would probably need to boost the valuation quotient to at least $2/boe and the probability of commercialisation to 60%. This would boost the absolute valuation to £110m, equivalent to 0.949p/share

https://www.allenbycapital.com/our-research/

Search for Baron oil.

https://www.forbes.com/sites/davidblackmon/2022/05/10/timor-lestes-energy-ambitions-could-make-it-the-next-guyana/?sh=498027595b62&utm_campaign=socialflowForbesMainTwitter&utm_source=ForbesMainTwitter&utm_medium=social

https://www.energyvoice.com/oilandgas/asia/395942/chuditch-gas-discovery-stirs-excitement-offshore-east-timor/

Even if Boil never develop it. How much is the asset worth firmed up with new 3d maps. More than the MCAP.

Rare groove filtered complete Troll