Amerisur Resources Share Discussion Threads

[foiledagain] 30/7/2018 21:31

A query on royalties. If royalties go up above 5,000bopd per field, is it a good enough reason to keep plat within it, and on to next.

[lucyp00p] 30/7/2018 21:01

and how would you transport the surplus?

[oilandgas1] 30/7/2018 19:53

It’s all about production numbers now not acquiring for the future .. if they were at 9kbopd I would say go for it but it’s not good enough!

[oilandgas1] 30/7/2018 19:45

It’s hard to believe we have 3 fields to get drilling in and we are at the end of jul tomorrow and none have spud yet!

I would sell the company for 30p today and move on .. if I could .,

[kaos3] 30/7/2018 19:38

why did gpx pay amer to take PUT 14? on surface makes no sense

[d1nga] 30/7/2018 15:01

someone sold them and someone else bought 'em

[juuunx2] 30/7/2018 14:52

Looks like nice buys to me

[moneylender] 30/7/2018 14:29

Price is moving north so that would suggest they are buys, but could def be wrong!

[runner2018] 30/7/2018 14:17

any idea if the big trades are buys or sells anybody?

[juuunx2] 30/7/2018 14:12

Wrong thread Tewks

[tewkesbury] 30/7/2018 13:03

Reabold (RBD)

Smallcap about to rocket.

Fully funded 6 well program and good news from California this morning.

[davwal] 30/7/2018 12:37

Whilst today's news is very positive, more pertinent to potential buyers right now is the forthcoming production update. That's the Sword of Damocles hanging over the share price ..

[3roach] 30/7/2018 12:37

Fair point Foiled.
Fingers xd this news is backed up by more positive updates soon. Makes a change.

[davwal] 30/7/2018 12:27

Gulfsands also has big problems with its second interest in Colombia, the Llanos 50 field, where the licence has been suspended. I'd guess Amer must be in prime position to grab that one too, if they wanted it..

[foiledagain] 30/7/2018 12:25

Years ago we had Rex buying

[3roach] 30/7/2018 12:15

Years ago we'd have put on a couple of pence today.

[moneylender] 30/7/2018 12:03

FA thanks for that link. Asyou say some really good info in there. Love the way they state "proven updip migration" in North plat, should be some good drills there for us!

Shame Amer presentations don't offer as much detail, JW take note!

[foiledagain] 30/7/2018 11:42

Some good information on PUT-14

[sleveen] 30/7/2018 11:20

A second pipeline is that a pipe dream?

AMER have to discover oil before any such pipeline is built.

OBA capacity 20k bopd current 4k and declining.

[davwal] 30/7/2018 11:16

Mention of the X Factor led me to check how/when its applied by the Colombian Government. For info the piece below explains the payment processes. Note the High Prices charge which hits Amer...

Government Take
Under the current E&P contracts, the hydrocarbons produced belong to the contractor, after paying royalties and other elements of government take.
According to the law, the royalty for light crude oil is a proportion of between 8% and 25% of the daily gross production based on the monthly average per field. The royalty is reduced by 20% for onshore gas fields and offshore gas fields at depths equal to or less than 1,000 ft., and by 40% for offshore gas fields at depths greater than 1,000 ft. and for hydrocarbons extracted from unconventional deposits. Royalty payments are deductible expenses for income tax purposes.
If an E&P Contract is awarded through a bid process, the contractor must pay to the ANH, in cash or in kind, the so-called X-Factor, which is the percentage of gross production after royalty offered by the contractor during the bidding process.
Under certain E&P Contracts, the contractor must pay to the ANH a fee for “High Prices” (which is similar to a windfall profits tax). In the case of liquid hydrocarbons (except for extra-heavy hydrocarbons) the fee is payable when accumulated gross production exceeds 5 MM Barrels, and the price of the “West Texas Intermediate” marker crude exceeds the Base Price Po set out in the E&P Contract. In the case of natural gas, the fee is payable after 5 years of production and when the average sales price of the natural gas exceeds the Base Price Po set out in the E&P Contract.
The contractor also pays a fee for the right to use the subsurface, during each phase of the exploration period after the first phase, which on average amounts to US$ 0.75/hectare, depending on the phase, the size and location of the area, and US$ 0.10/bbl (liquids) or US$ 0.01/mscf (gas) during the exploitation period.

[acv74] 30/7/2018 11:02

ML, 6-8 wells in 2018 would be great...then continue the drilling programme in early 2019.

[juuunx2] 30/7/2018 10:23

Probably cus it's more jam tomorrow mate. 36 months until ready to drill. They need to crack on with existing wells that are due to be drilled. Way behind schedule. It's even beginning to grind me down and I've been forever the optimist here. Can't see why they couldn't get a second rig. They got plenty of cash on hand and so many to drill or is that too difficult to mobilise another one to the region???

[moneylender] 30/7/2018 10:08

Think the best we can do now is about 6-8 wells this year! We have 5 months to get cracking.