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Notwithstanding any other reservoir or connectivity variables, I'd have thought the column height difference between WD and LC ( nearly 200m) would give some fluid density difference - basic fizzics, given the hydrocarbons have had a few years settling period. Drill high enough in the crest, and the fluid might be, er, gas. Isn't 43 API in the condensate region? I believe the determination of source/ reservoir is done spectrographically, so if the two samples match, they almost certainly come from the same source.
Maybe a reservoir eng could wade in here?
Unconcerned about the API delta, but - like many, I guess, would like to see/hear some form of tech update regarding WD's fissure-finding-failure and it's/ any ramifications and how such will be managed.
Gla
Completly agree with londoner7 on api variations.
Also remember they only have a 1 litre sample from warwick so probably a fair bit of uncertainty on the 40 number.
"In my mind, there is no doubt that is the plan."
Pretty easy to have high confidence in that, considering it is stated as so in the Interim Presentation pack! :-)
"In my mind, there is no doubt that is the plan."
Pretty easy to have high confidence in that, considering it is stated as so in the Interim Presentation pack! :-)
Not only that but AM contains eleven storage tanks.
API variations within a reservoir are not unusual. Google it and you'll find lots of examples.
Could the difference in the in APIs have a bearing on the connectivity of both well s Lincon C and Warwick D? ( just a thought. )
Biffa,
"WD was 40 API and Lincoln 43 API. Therefore they are broadly similar."
Yes, they are broadly similar, but no, the RNS did NOT say that WD was 40 API. It said it was APPROXIMATELY 40. That's important.
Also, you're right, whether the WD sample turns out to be 40, 43 or 38, makes no difference to the Lincoln tie-in.
"We were delighted to announce the results of a successful drill stem test on the Lincoln Crestal well on 12 September 2019. Consent for suspension of the well, with gauges downhole, was granted for the purposes of: completing pressure build-up tests, gathering interference data between the Lincoln Crestal and Warwick West wells, and gathering data from the early wells that are planned to be drilled in 2020. The suspension consent provided requires that the well is re-entered to be plugged and abandoned by 22 June 2020.
Following the successful test of the Lincoln Crestal well, Hurricane, as licence operator, intends to apply for regulatory consent to tie this well back to the Aoka Mizu during 2020, concurrent with the West of Shetland Gas Pipeline system (WOSPs) tie-in and Aoka Mizu debottlenecking. This application will be subject to further technical evaluations and final investment decision by the joint venture. If regulatory consent for the tie-back is granted, first oil from the Lincoln Crestal well is currently forecast for Q4 2020 / Q1 2021. In order to maintain the target schedule, regulatory consent must be obtained by end Q1 2020."
It's really simple for me. Lincoln Crestal will absolutely be tied back to the Aoka Mizu. We will re-enter Lincoln Crestal before June 2020 and prepare it for tie back for Q4 2020 / Q1 2021.
In my mind, there is no doubt that is the plan.
JoeSoap,
Oil samples were taken from WD and Lincoln.
WD was 40 API and Lincoln 43 API. Therefore they are broadly similar.
Whether the oil in WD and Lincoln are similar or not has absolutely no bearing on whether a tie-back from Lincoln is viable.
As a stand alone field HUR have demonstrated from the recent drill results from the Lincoln horizontal that it is a viable option for a tie-back to the AM.
I think you might be clutching at straws here.
GLA.
Anotheer attempt...
The second comment, scratched from the initial post of this thread, relates to the oil.
"Lincoln confirmed to contain light, 43° API oil"
and yet, later in the same RNS we learn that
"We believe that following more detailed analysis than can be achieved on the rig, the oil recovered from Lincoln Crestal will be demonstrated to be broadly similar to that from Warwick Deep."
and as
"Results from laboratory analysis of oil recovered to surface from Warwick Deep indicates a light oil of approximately 40° API."
how is 43° confirmed?
It seems a little odd that the readily obtained volume sample is assessed in error when compared to the meagre volume obtained from WD.
But, the accompanying presentation tells us that "fluid compatibility studies to confirm ability to tie-back," are required, but does not identify who the arbiters are, is it BPInt that are buying and selling or the refinery that buys and processes?
Overall, both comments show that the tie-back is not a slam dunk.
jimo
joe
.
It is clear the well is being suspended as a future producer.
You're all over thinking it.
There is a process to follow with the regulatory body. HUR has requested a suspension with gauges installed until 22 June 2020, when another request will be made. The plan is still to tie it into the AK, but before then it has a useful function to provide interference data from the other GWA wells.
Maybe they missed out "or prepared for production" ?
JoeSoap
The sentence you refer to is on page 6:
"Greater Warwick Area
We were delighted to announce the results of a successful drill stem test on the Lincoln Crestal well on 12
September 2019. Consent for suspension of the well, with gauges downhole, was granted for the purposes
of: completing pressure build-up tests, gathering interference data between the Lincoln Crestal and Warwick
West wells, and gathering data from the early wells that are planned to be drilled in 2020. The suspension
consent provided requires that the well is re-entered to be plugged and abandoned by 22 June 2020. "
I was confused by it and assumed it to be an error.
it has a guage in it.
I've seen several comments that there was nothing new info in the RNS, but I beg to differ as there were a couple of things that I was not aware of and I don't think have been disussed here.
Firstly, I found this surprising:-
" The suspension consent provided requires that the well is re-entered to be plugged and abandoned by 22 June 2020. "
afaik, HUR still have two suspended wells without any such conditions, Halifax and Lancaster 4. I think the XEL well is still suspended following the EWT, lol.
So, why has this been applied?
It seems to be completely at odds with the plans presented by HUR, as all three were intended to be suspended as future producers in much the same way as 6 & 7z.
Now we know that is does not matter for WD as that has been plugged and abandoned but what of WW, where current planning is for production as part of the FDP 2023/4?
I might find time for the second point, tomorrow.
Any views/info on this one?