Confidential records reveal limitations of Cuadrilla’s Lancashire fracking operation

pnr 181128 Ros Wills 1

Fracking equipment at Cuadrilla’s shale gas site at Preston New Road, 28 November 2018. Photo: Ros Wills

Two-thirds of the UK’s first horizontal shale gas well was not fracked during a nine-week operation last autumn, according to reports that the company, Cuadrilla, tried to keep secret.

The documents reveal that the Preston New Road site near Blackpool experienced mechanical problems and lost equipment.

They show that quantities of frack fluid used in the operation were too low to qualify for the legal definition of associated hydraulic fracturing. They also confirm for the first time that a majority of earth tremors around the site were on days when fracking was carried out.

The reports are daily logs sent by Cuadrilla to regulators, giving information about operations, induced seismicity, frack fluid volumes, proppant and fracture lengths.

They are marked confidential and were not published on the company’s website, despite a recommendation by the industry organisation, UK Onshore Oil and Gas (UKOOG).

Cuadrilla did not reveal most of the contents to local residents or councillors and it sought to prevent release under freedom of information legislation (FOI).

The Environment Agency did release the logs recently in response to an FOI request by a member of the public. Analysis by DrillOrDrop has revealed:

  • Cuadrilla carried out just 15 main fracks between mid-October and mid-December 2018

  • Just 36% of the planned stages of the well had a main frack

  • Whole sections of the well were not fracked at all

  • On two-thirds of the fracking days there was at least one seismic event

  • Fracking used a fraction of the expected volume of fluid and proppant

  • Fracking paused for more than a month

  • Fracking equipment suffered a mechanical failure

  • The well had to be cemented and milled to solve the problem

  • Equipment became stuck in the well and was abandoned

Despite this, Cuadrilla said it had enough data to predict “a potential initial flow rate range of between 3 million and 8 million standard cubic feet per day”. Based on Cuadrilla’s figures, UKOOG upgraded its UK production estimates by 70% and predicted that at peak levels domestic shale gas could wipe out the need for gas imports.

First UK high volume frack for seven years

Cuadrilla announced the start of fracking at Preston New Road on 15 October 2018. There was intensive interest from the media, onshore gas industry and opposition groups. The well, known as PNR1z, would see the first high volume hydraulic fracture in the UK since 2011 and the first ever frack of a UK horizontal shale gas well.

181015 1045 pnr dod

Protest outside Cuadrilla’s shale gas site at Preston New Road on the first day of fracking, 15 October 2018. Photo: DrillOrDrop

The operation continued until 17 December 2018. The following day, the company issued a statement that it was moving equipment off the site for Christmas.

Equipment began to return three weeks ago but there has been no public statement that fracking has resumed. In February 2019, Cuadrilla indicated that it would not frack again at Preston New Road until there had been a relaxation of regulations on induced seismicity.

41% of days fracked

Cuadrilla had permission to frack on weekdays and Saturday mornings. This gave it 56 available days between 15 October and 17 December.

The logs show that the company fracked on just 23 (41%) of these available days.

The operation was most intensive in the first fortnight when there were mini and/or main fracks on every available day.

But from 3 November to 17 December, Cuadrilla fracked on just seven of the 39 (18%) available days.

36% of stages fracked

Cuadrilla’s hydraulic fracturing plan said the company would frack up to 41 stages of the well. It planned to start at stage 1, the toe of the well, furthest from the site, and continue progressively towards stage 41, nearest the well head.

According to the daily logs, the company carried out main fracks on just 15 of the 41 stages (36%).

Fracking began at stage 1, as planned, and continued in the first week to stages 2 and 3. It then moved on to stages 12, 13 and 14, before jumping to the stages closest to the well head.

According to the logs, a total of 24 stages, making up entire sections of the well, were not fracked. These included stages 4-11, 15-17, 19-21 and 23-29.

Two stages, 18 and 25, had a mini frack only.

The company told the community liaison group of residents and councillors on 12 November 2018 that it had changed the order of the fracks to “further understand seismicity and obtain data”. It did not say it had missed out entire sections of the well.

17 main fracks

During the operation, Cuadrilla carried out 17 main fracks. Of these, 11 were in October.

There were no main fracks in November or the first week in December. There were six main fracks from 8-17 December 2018.

Two stages of the well each had two main fracks: stage 3 on 18 and 20 October and stage 37 on 8 and 10 December. 12 mini fracks were carried out during the operation.

Fracking and tremors

181214 bubble chart refracktion

Seismic events at Cuadrilla’s Preston New Road shale gas site up to 14 December 2018. Source: Refracktion

Cuadrilla’s chief executive, Francis Egan, told BBC Radio 4’s Today programme on 15 October 2018 that fracking at Preston New Road would not cause earthquakes.

Very small tremors began on 18 October 2018, three days after fracking started. They continued until 14 December 2018. The British Geological Survey recorded a total of 56 seismic events, ranging from minus 0.8ML to 1.5ML on the local magnitude scale. Just two tremors were felt at the surface but opponents of the operation expressed concerns about the risks of seismic activity to the well.

The company never suggested that the tremors were unrelated to fracking. But until the release of the daily logs it had not been possible to see how closely they corresponded with pumping operations because Cuadrilla would not reveal all the days that it fracked.

We now know there were tremors on 15 of the 23 days (65%) when there were main or mini fracks. With one exception, there were no tremors on Sundays when Cuadrilla did not have permission to frack.

A gap in fracking corresponded with a gap in seismic activity. When fracking resumed, earth tremors began two days later.

Of the 23 days when there were main or mini fracks, eight days (35%) had no seismic activity. Three of these dates were when the company carried out mini fracks only. Three of the dates were at the start of the operation (15-17 October) and two were at the end (15 and 17 December). On 2 days, there was seismic activity but no fracking.

The strongest earth tremors happened when Cuadrilla was carrying out main fracks on the stages of the well closer to the well pad. For example, the 1.5ML tremor on 11 December was on the day that stage 38 was fracked. The second strongest tremor, 1.1ML, on 29 October, was the day that stage 32 was fracked. This was followed by a 39-day gap in main fracks.

The daily logs don’t provide information on the timing of fracturing so it is not possible to see how soon after injection there was seismic activity. This means it is not possible to check the number of red events under the traffic light system regulations. These are defined as seismic activity above 0.5ML that happen during fracking.

There does not appear to be a close relationship between the strength of seismic activity and the volume of frack fluid or proppant.

Frack fluid and proppant

pnr daily log 181217

Extract from daily log for 17 December 2018

Cuadrilla’s hydraulic fracturing plan, which describes how fracking will be carried out at the Preston New Road site, said up to 756m3 of fluid would be used per fracking stage.

If the company had used the maximum volume on all 41 proposed stages, the fluid would have amounted to just under 31,000m3. This would have complied with the definition of associated hydraulic fracturing under the 2015 Infrastructure Act: fracking of shale involving the injection of more than 1,000 cubic metres of fluid at each stage or more than 10,000 cubic meters of fluid in total.

The logs show that the total volume of fluid injected at Preston New road for the 17 main fracks and 12 mini fracks was 3,869m3. The average volume for the main fracks was 218m3.

According to the logs, there were just three dates when the operation used at least half the proposed maximum volume: 417m3 on 17 December, 393m3 on 18 October, 384m3 on 22 October.

On three dates, main fracks each used less than 100m3: 19 October 33.9m3; 8 December 78.4m3; 10 December 99.5m.

The hydraulic fracturing plan said each frack stage would use up to 75 tonnes of proppant – the material used to prop open fractures. Cuadrilla later said it had expected to use 50 tonnes per stage but because of the seismicity regulations it had achieved this on only two dates.

The logs confirm this statement. Fracks using about 50 tonnes were on 17 December, the final injection of the 2018 operation, and 18 October, the third main frack.

According to the logs, seven fracking stages used proppant weights below 10 tonnes.

Month long fracking gap and mechanical failure

The logs showed there was no fracking between 3 November and 7 December 2018. This gap largely coincided with a mechanical failure with fracking equipment and efforts to solve the problem.

We asked Cuadrilla whether the fracking pause was caused by the equipment problem. The company replied that on this, and our other questions, it had nothing to add to the information in the logs.

We do know from the logs that the problem concerned mechanical sleeves surrounding the well that open during fracking.

Two sleeves, at stages 30 and 31, became stuck in the open position. These sections of the well had been fracked on 26 October and 27 October 2018.

There were seismic events on both these dates. Cuadrilla confirmed that the tremor on 26 October, measuring 0.8ML, counted as a red event under the regulations. This meant fracking had to pause for 18 hours. There was also a 0.8ML event on 27 October, which was described as a trailing event.

On 1 November, the log recorded that fluid from fracking both these stages of the well was flowed back. The following day, the company announced that it had begun to see gas reach the surface and it released a 12-second video of gas being burned in the flare.

Stages 30 and 31 were flowed back again on 2 November, according to the logs. Two days later, on 4 November, the log recorded:

“Coiled Tubing ran in hole to try to close sleeves 30 and 31.”

The following day, 5 November, Cuadrilla tried again to solve the problem. The log said:

“Coiled Tubing finished a logging run, came to surface, switched the BHA, ran in hole, tried to close sleeves, came to surface, re-dressed the BHA [bottom hole assembly on surface.”

According to the logs, the company tried again on 6 November:

“Coiled Tubing run into the well to attempt to close sleeves 30 and 31, pull coiled tubing to surface, and close well head master valve.”

The log recorded that the well was cleaned on 7 November and a day later prepared for a cement job to solve the sleeve problem. The record for 9 November said:

“Equipment maintenance and preparedness for the upcoming cement job.”

On three days, from 10-12 November, the logs reported:

“Waiting for equipment and material for the upcoming cement job”.

Cuadrilla told the High Court in October 2018, a day’s delay would cost £94,000. If this rate were applied to the sleeve problem, the cost by mid-November would have topped £1m. Cuadrilla did not respond to our question about delays.

On 12 November, there was a monthly meeting of the community liaison group (CLG) for Preston New Road.

The minutes, written by Lexington Communications for Cuadrilla, recorded that Cuadrilla’s then technical director, Mark Lappin, “provided an overview of operational activity”. There was no reference to the sleeve problems or the upcoming cement job.

According to the minutes:

“Mark Lappin advised that [gas flow] is now being analysed and confirmed that Cuadrilla intends to commence hydraulic fracturing over the coming days.”

The daily logs show that the next main frack would not be for nearly a month.

Calls for information release

pnr 181225 ros wills4

Cuadrilla’s Preston New Road shale gas site, 25 December 2018. Photo: Ros Wills

The CLG minutes also recorded a question about why the daily logs were not published on Cuadrilla’s website.

“Mark Lapin confirmed that daily reports are issued to the OGA [Oil & Gas Authority], EA [Environment Agency] and HSE [Health & Safety Executive], but advised that it is not a requirement to publish on the operator’s website. Clarifying this, he noted that the United Kingdom Onshore Oil and Gas (UKOOG), the representative body for the industry, had recommended this, but that was not a requirement.”

The minutes also suggested that the Environment Agency may be required to provide the logs if there was a freedom of information request.

According to the minutes, the Environment Agency officer at the CLG suggested:

“it may be beneficial for Cuadrilla and the regulators to be on the front foot by providing information that would be useful for the community.”

“No stage-by-stage fracking updates”

At around this time, people started to notice that seismic activity around Preston New Road had stopped. The British Geological Survey (BGS) last recorded earth tremors in the area on 4 November 2018. There were also rumours about why fracking had stopped (DrillOrDrop report).

On 11 November, DrillOrDrop asked Cuadrilla whether it had fracked in the week before the CLG meeting. The company told us:

“We are continuing to test our exploration well in Preston New Road, Lancashire, including testing the responsiveness of the shale to fracturing. We are also analysing the recent natural gas flow at the surface and other data which is available to us following the start of our hydraulic fracture fracturing programme last month. However, we are not giving a stage by stage update on each frac.”

After the CLG meeting, the logs for the next three days recorded more waiting for the cement job on the well.

On 15 November, DrillOrDrop asked Cuadrilla about suggestions that the well had been damaged. The company replied:

“There are no integrity issues with the PNR1z well”.

The next day, we asked:

“Are there any other problems with the well that might be considered to be damage but which don’t involve well integrity with PNR1z?”

Cuadrilla responded on 22 November with a statement:

“We are continuing to test the shale gas exploration well in Preston New Road, Lancashire, and the coiled tubing remains clearly and visibly attached to the coiled tubing tower on site above the well.

“We have completed a series of smaller fracks along the length of the horizontal well to gather data to assess the micro-seismic response of the shale rock 2km below the surface.

“We have said many times in recent days and weeks, to both local people and any media who have asked for an update, that we are now analysing that data as well as drawing on expert advice to determine how we can further optimise our hydraulic fracturing programme within the very rigorous operating boundaries of the micro-seismic traffic light system.”

A freedom of information request by DrillOrDrop revealed that the Environment Agency had been asked for the daily logs. A heavily-redacted email showed that Cuadrilla told the agency:

“We believe that all the data contained in our daily reports is commercially confidential”.

It also said:

“Please would you confirm that the Environment Agency will not be releasing any of these reports to the public without our consent.”

The company’s lawyers later asked for more time to respond to the request.

Cement job, cleaning and lost equipment

On 16 November, the logs recorded the cement job had been carried out on sleeve 30. The work on sleeve 31 took place on 17 November. The next day, the company waited for the cement to harden.

On 19 November, the log recorded:

“Ran coiled tubing into the well to mill to stage # 31.”

According to the logs, milling took place from 20-22 November. Four days of cleaning then began on 23 November.

On 26 November, the log recorded:

“Pulled coiled tubing to surface. Boot basket was empty. Upon inspecting BHA [bottom hole assembly], the mill, crossover, and bottom piece of the motor were left in the well.”

The solution, reported in the log for 27 November, was to push the equipment to the end of the well:

“Ran in hole with the bullnose BHA on coiled tubing and pushed the missing part of the previous BHA to TD.”

Fracking resumed on 8 December and continued for another eight days.

Relaxation of regulations

Francis Egan BBC North West tonight 181015

Francis Egan, chief executive of Cuadrilla, BBC North West Tonight 15 October 2018

Since last year’s operation, Cuadrilla has called for a raising of the seismicity limit at which fracking must pause.

In a statement in February, the company said it had acquired 40,000 micro-seismic data points during fracking the PNR1-z well.

The company’s chief executive, Francis Egan, said:

“We believe there is more than ample evidence to justify an expert technical review of the TLS [traffic light system] and, based on the outcome of that review, a revision at the PNR site, without compromising on safety.”

190328 Sir Ed Davey Parliament tv2

Sir Edward Davey, 28 March 2019. Photo: Parliament TV

But Sir Edward Davey, the former energy secretary who approved the 0.5ML threshold, said in a parliamentary debate last week that any review must be based on “a significant amount of evidence”.

He said:

“So far we have had very few fracking experiences in this country, so we do not have anywhere near the number of data points or the amount of evidence that we would need to possibly allow anything to go forward.”

Information from the company’s logs raises questions about the limitations of last year’s operation at Preston New Road and whether the data meets the requirement of “a significant amount of evidence”.

DrillOrDrop acknowledges the help of Refracktion with data assembly. If you would like to see the daily logs please get in touch

105 replies »

    • In the report on the Preese Hall well the BGS state that the size, rate and type of induced seismicity would therefore be dependent on the rate and amount of fluid injected.
      Even with the small volumes of injected fluid at PNR, seismic activity has stopped Cuadrilla and produced non commercially viable amounts of gas.
      The Bowland shale gas model doesn’t look to promising. If Cuadrilla with all their experience can’t get the gas out without unacceptable seismic activity then no one can.

      • What is “acceptable” John??

        Think your acceptable is zero, think scientifically acceptable is something else altogether.

        • Acceptable? Something which doesn’t breach regulations or trigger limiting actions for safety reasons might satisfy that definition? The TLS is based on science after all Martian.

          • The TLS was based on science but our understanding of this subject has changed quite significantly since the TLF was introduced. A particular advance is that we now know that the limit of 0.5 doesn’t correspond to a threshold that signifies the start of mode 2 or mode 3 fractures. This was a major reason why the authors of the original report went for a 0.5 ML limit and was based on production from a certain part of the Barnett shale. Recent work (focal plane solutions to the seismic events) on this particular region shows very clearly that they are actually shear fractures. This means that the limit of 0.5 ML was based on a false assumption.

              • Refracktion -there is not a single reference that addresses this issue. I know that it is the centre of many people’s lives but most scientists think it’s totally safe and irrelavent. If you really want to know what’s happening you could put a few FOIs into the right place. However, I wouldn’t waste too much time because you’ll get answers that you don’t like.

                • So that’s a “no” then Simon.

                  You could always give us more than one reference to back that all up with evidence if you want.

                  I love it when people say things like “most scientists think” – it’s such an obvious spurious appeal to authority that you just know they are’t going to able to back up what they are claiming.

                • I was hoping you might be able to give something which supports your contention that the decision re the TLS limit was based on this. The bibliography for the Styles Baptie report which I believe forms the basis for the TLS decision is overwhelmingly UK / Europe focused.

                • Refraktion – in the comment above I mentioned that if you were really interested in knowing the key factors on which the recommendation for the TLS were based (which actually I doubt if you are that interested as it might not agree with your view of the world) you will need to put in a couple of clever FOI requests as much of the logic for the recommendation isn’t published but has been shared by two of the authors of the report to subject matter experts.

  1. Yes there are limitations to Cuadrillas operations, namely people who don’t understand the Exploration of Drilling & Fracking an Oil and Gas well.

    These are confidential papers which have been released and are similar to that of an operations log, so i dont know the significant to this being public knowledge… the regulations by the OGA and the TLS are strangling Cuadrillas progress.

    • It’s funny how UKOOOG recommended that these reports be made available on a daily basis on the operators website and yet Cuadrilla and you seem to be claiming that they should be highly confidential. Maybe it’s UKOOOOG who don’t understand the Exploration of Drilling & Fracking an Oil and Gas well then?

      Actually I suppose we can see why Cuadrilla wouldn’t be keen to have their problems publicised at so sensitive a time, so maybe UKOOOOOG with their recommendation were assuming a level of successful performance to which it seems the current UK frackers can only aspire?

      Their efforts to hide the information don’t really help their case though – especially as it didn’t work.

      • I don’t know of anywhere in the world that provides this information to the public as soon as it is obtained – usually there is a 5 year gap. As far as I can see, the key people in the UK who have the knowledge to interpret the data have reviewed it.

        • Judith, very good but you can’t get away from the fact UKOOG (“We are United Kingdom Onshore Oil and Gas (UKOOG). We represent the onshore oil and gas industry”) still have on their website guidance which very clearly states their position on this subject (

          It says

          “Reporting to Regulators

          Reporting to regulators on Seismic issues should take two forms:

          Daily Report

          A daily report should be submitted via email to BEIS, OGA, HSE, EA during hydraulicfracturing activity. This should include:

          • A summary frac treatment report that includes; the volumes of proppant and fluid pumped, chemical volumes used, summary of injection pressures and depths.

          • A schematic showing frac growth/extent in relation to the permitted boundary(EA permit).

          • Any induced seismicity detected within the Yellow or Red zones of the traffic light system and/or Surface Vibration detected that exceeds the vibration threshold VT1 or VT2. Where no seismicity has been reported, an estimate of the detection threshold.

          • Summary text on well integrity.

          This daily report should be made available on the Operator’s website.

          Event Reporting

          The OGA and EA should be notified in the following instances;

          •The occurrence of a red-light event during pumping
          •The exceedance of VT1 and/or VT2
          •A fracture has extended beyond the permitted boundary(EA permit).

          Notification of a red-light event should be made via email within onehour of confirmation.If there are indications that the fracture has extended beyond the permit boundary, then the required information and contributing factors will be gathered, including a provisional analysis and submitted to theEA as early as possible, but no later than 12 hours after its detection or in-line with time scales as agreed within the HFP.”

          When challenged as to why they are not publishing the data on their website as UKOOG say they should. Cuadrilla seem to have claimed that this is guidance only and not something they actually have to comply with.

          Maybe if there is usually a 5 year gap as you claim somebody should have told UKOOG that a daily report on the website was not appropriate? With your extensive experience I’m surprised you didn’t do so. After all the guidance was there way before they started fracking and you must have been aware of it – we certainly were. But you kept quiet about the problem and here we are now.

          Or maybe this is just another example of the industry agreeing to something only to find they can’t keep to it and then trying to wriggle out of it like the TLS?

          Or maybe UKOOG just don’t know what they are talking about generally?

          It’s all so very Brexit isn’t it?

          • UKOOG are a trade organization – they are just offering advise on how they think it’s best for companies to handle these issues in terms of how it looks to the public. My view is that there is absolutely no point in releasing this information to the general public particularly as it just gets all the people with degrees in geophysics from the University of Google rather hot under the collar. On the other hand, releasing data before it’s been properly interpreted means that people end up writing blogs that will, at a later date, show them to have a very poor understanding of modern day technology/industry practice (that’s not you i’m referring to either Refraktion) – just this situation happened last week and it’s still causing a massive amount of amusement within the community of professional geophysicists.

  2. Looks promising!

    If they had produced the gas forecasts based upon a smooth, complete frack that would be one thing. But, to do so after teething problems of this magnitude would point towards vast quantities of gas being available if it all was conducted perfectly! So, looks as if the speculation/fabrication of not being commercially viable might be adrift.

    Not sure if this item does the antis cause any good whatsoever.

      • No, we can’t, reaction.

        Nothing has changed to the fundamentals. We already knew the frack was limited, and we know why.

        If you wish to become exciting again about the same thing, that is up to you. But, excuse me if I don’t join in with such illuminating items like seismic activity coincided with the days fracking took place. DOH. Wasn’t that reported on a daily basis? Is that not the objective of fracking, to produce underground fractures that will be able to be recorded if the equipment to do so is in place?

        Seems to be a quiet news period for the antis. Interesting how without that it becomes necessary to re-excite around old news.

        • Except that Mr Egan promised it wouldn’t happen Martian! How funny that you are now telling us you expected seismicity to coincide on a daily basis with fracking.

          And do you remember Cuadrilla making the Telegraph remove a report saying they had caused fracking at Preese Hall? I do!

          We seem to be along way from that now don’t we?

          Keep on Collywibbling!

          • Francis said earthquakes wouldn’t happen – none of the people who do this for their day jobs thing that 1.5 is an earthquake.

              • Refracktion- the staff at BGS do an amazing job. Nick Riley, who contributes regularly to this forum, has done more good for reducing GHG emissions than everyone else put together.

                I one thing that I would criticise them for in the context of this debate is the release/interpretation of the microseismic data from PNR. I could be wrong in my criticism because I don’t know if they had access to all the data and also they might have had their best people working on more important issues, which there are many. However, the interpretation of the microseismic that “Prof” Smythe has used looks as though no one has bothered to analyse the polarisation of the first arrivals which considering the geophones were 3C would have meant they wouldn’t have placed the hypercenters on one side of the borehole.

                • Judith you seem to be trying to muddy the waters here. The BGS regard the seismic activity at PNR as “earthquakes”. You can see it on their own website. They do this for their day job. Your statement “none of the people who do this for their day jobs thing that 1.5 is an earthquake” was demonstrably rather silly.

                • Refracktion – I think it’s quite safe to say that I know far more seismologists than you do and I still don’t come across any who think of the little tremors at PNR as earthquakes. It also seems that you think that seismologists at BGS pedantically go through their websites to check that someones hasn’t used the incorrect term. I know pretty much every senior seismologist at BGS and I can assure you they have better things to do – it seems like PNR, or your little house near PNR, is the center of your world but to most people it’s really not very important

                • Judith I am sure you do know more seismologists than I do but yu can’t escape from the fact the BGS site is very clear that they class the activity at PNR as “earthquakes”. If you don’t like it take it up with them not me, but please stop claiming things that are simply not true.

                • Refraktion – are you now claiming that BGS is so low on staff they’re employing seismologists to build their websites? Times are difficult but not so difficult. But lets keep on with your pedantic arguments – we all know how much you like onehobmanship

                • Dear God Judith 😂

                  It’s not hard – the BGS has a whole subdomain given over to Earthquakes ( where they list activity including that at PNR under the heading “Earthquakes around the British Isles in the last 100 days”.

                  Now unless you are trying to pretend that the BGS website has been taken over by some rogue html programmers who deny access to the learned people who do the research, and deliberately mislead the public with incorrect terminology, I think maybe it’s time you stopped digging this hole. But do feel free to carry on as you are at least making me laugh.

  3. Excellent reporting and a damning indictment of Cuadrilla’s incompetence and mendacity. This report is another nail in the coffin of the UK onshore fracking industry – a coffin that now has so many nails in that it is probably impossible to lift.

  4. Oh please tell me , this is an April 1st joke right ? Hahaha Cuadrilla hhahaha some more . So these reports were confidential ? is that all you have Eli ? So that makes it all ok ? Its interesting to the public because ,,,, Doh !!

    • You also said the Kimmeridge wouldn’t flow oil.

      Think I’ll skip the “somewhat more technical blog”.

      • R8 LMX – the interesting thing will be to see how long it takes him to realize that his interpretation of the microseismic has nothing to do with “stress gradients” – maybe then he’ll start to realize that he is very out of touch with this whole subject area.

  5. Cuadrilla doesn’t seem to be able to do its job without stuffing up something. At this rate of competence and progress, it is hard to see their claims of being able to produce gas commercially viable and displace imported gas.

    • TW – I really can’t see what they have “stuffed up”. The completion system that they used was state-of-the-art and it’s not too surprising that it has a couple of mechanical issues. On the positive side, the system will allow them to do a whole range of further interventions, which wouldn’t be possible is they had stuck to the more commonly used methods. In hindsight this was a great call by Cuadrilla – essentially it means they can go in a refrac the well and vary the sequencing of the fracs.

  6. TW. You obviously dont know about drilling. ‘Fishing’ is the process of recovering lost equipment. I have done quite a bit of it, many years ago. Things do get stuck, and opening or closing a slide valve thats 2 miles away underground when all you have are pressure readings or weight readings is complex. These may cost the operator money but are not an indication of incompetence or that there is a risk. All they did when they lost the equipemnt is push it to the bottom of the well. No big deal.

    As for the rest of it, the seismic levels are set lower than any other industry. With the excellent prospects of this formation, and the fact that it could provide a massive benefit to the country (with lower GHG impact than all of the LNG we import from hostole countries). The 100 sites predicted ( 40 wells per pad) for the whole of the N of England would seem to be a no brainer.

    Lets face it, the seismic limit for the exploratory geothermal plant in Cornwall is 4 tho you cant see the risk assesment any more! These Cuadrilla ‘earthquakes’ are undetectable and the experst asay there are no issues with increasing that to 1.5.

    • 2011: 2.3 ML “Bonny Street police station felt the building shaking” “A spokesman for Blackpool Police told the Blackpool Gazette: ‘We started to get calls at around 3.35am.’Some may have thought it was an April Fool prank, but staff here felt the building move.”

      2018 1.5 ML “Fracking earth tremor felt like a car hitting building”

    • I agree. I dont know much about drilling and the mishaps by Cuadrilla is small mistake. And the set limit dor seismic does appear inconsistent against fracking. But why is it so hard to convince the government to see this unfair treatment and inconsistency? Or are miss something Cuadrilla not telling us?
      Can the industry take legal action?

      • TW – there is only one person who is getting in the way of the TLS being changed and looking at the way things are going he won’t be in his job too much longer,

    • [Edited by moderator]

      It’ quite common for offshore rigs to have more than 40 slots and they’ve got a deck size that is way smaller than PNR – that’s the great thing about directional drilling.

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