Scots lost out in UK oil and gas endgame

The white paper Scotland’s Future writes (November 2013)

 

“Westminster governments have also failed to re-invest the proceeds of the North Sea to provide a long-term benefit to future generations. Stabilisation funds and sovereign wealth funds are common among oil and gas producing countries, with the UK being a notable exception”  p 300

 

“Norway began transferring money into its oil fund in 1996. The fund is now worth £470 billion, equivalent to around £90,000 per person in Norway, and is the largest sovereign wealth fund in the world”  p 382

 

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The above white paper Scotland’s Future writes:

 

“Production is expected to extend beyond the middle of the century, with the industry estimating remaining reserves of up to 24 billion barrels of oil and gas that can still be recovered” (p 57)

 

and then

“It is estimated that there could be up to 24 billion barrels of recoverable oil and gas remaining in the North Sea with the potential for production to continue for decades to come” (p 88), based on Oil and Gas UK Economic Report 2013

 

Notice the difference? The report mixes up reserves and ultimately recoverable resources. Note also that oil and gas are added to give barrels of oil equivalent – which is not very helpful.

 

These 24 bn boe  have been taken from the “Oil and Gas Economic Report 2013” which states:

 

“As long as the UKCS continues to be a competitive oil and gas province in which to invest, Oil & Gas UK believes that up to some 24 billion boe of resources remain to be recovered (towards the higher end of these various projections) and the industry will be active beyond 2050.” (p 19)

 

Here is the composition :

7.4 bn boe from existing fields and projects already sanctioned

2.5 bn boe (max 4 bn boe) probable reserves if companies invest

1.5 bn boe possible reserves (max 3 bn boe) which are technically difficult or commercially marginal
________

11.4 bn boe total P3 reserves (max 14.4 bn boe)

These reserves will require investments of £300 bn for the development and operation of brown/green fields, including decommissioning.

1-4 bn boe of potential additional resources (PARs)

3-9 bn boe of yet-to-be-found resources (YTF)

 

One arrives at 24.4 Gboe by adding the P3 reserves of 11.4 Gb boe and the maximum resources of 13 bn boe. The report mentions following caveats:

 

 

 

 

Let’s put that into a graph:

 

So the Scotland’s Future report has been quoting the highest numbers including additional and yet-to-find resources. According to Fig 2 the depletion rate of 3P reserves is 41.8/(41.8+7.4+2.5+1.5) = 79%

 

 

DECC runs this website:

which contains historical production, reserve and resource data.

 

Fig 3: UK oil and gas reserves and resources end 2013 

 

For the most probable central case or P2 the DECC reserves are 8.3 Gboe, compared to 9.9 Gboe in Fig 2, 16% less, but P3 is 6% higher. Not really a big difference.

 

Note that Fig 3 does not contain yet-to-find resources.

 

 

The graph above means, for example, that there is a 20% chance that 2.1 Gboe will be discovered. That would not be a probability on which to base planning more run-ways at London’s airports.

 

 

 

 

The underlying graph of Fig 6 is from this file:

 

The 2P depletion rates (ratio of cumulative production to 2P reserves plus cumulative production) have been added. In the year of peak production the rate was 69% and has increased since then to 83%.  Since 2004, 2P reserves remained at bteween 750 mt and 800 mt, showing how difficult it has become to turn reserves into actual production.

 

 

 

 

How did it come to this double peak? The above graph shows 3 different development periods depending on the start-up year. All fields started before and during 1985 peaked in 1985, 3 years before the Piper Alpha accident.  The 2^nd group starting in 1986 came too late to offset decline of the 1^st group but nevertheless grew until it peaked, too, in 1999, albeit at a lower level because the total amount of oil available was less (cumulative production to 2013 was 8.7 Gb vs. 14.1 Gb). The 3^rd group after 1999 is smaller still and also generated a double peak with the Buzzard field.

 

 

 

Associated gas comes from oil fields so it should be proportional with oil production. But when comparing Fig 11 with Fig 9 there is a noticable difference. The 2^nd phase of start-ups between the 2 oil peaks created a much higher gas peak than the 1^st one.  Gas production which started after 1999 shares the same characteristics as oil production: it’s post boom.

 

 

Statistics of Government revenues from UK oil and gas production.

 

 

Revenue obviously peaked. Notes: Royalties abolished in 2002 but supplementary charge introduced. Ring fence corporation tax (RFCT) of 30% does not permit deduction of losses in other activities and excessive interest payments but makes available a 100% first year allowance of all capital expenditure. Supplementary charge (SC) of 32% (increased from 20% in 2011) on ring fence profits with allowances for small and technically challenging fields. Field based petroleum revenue tax of 50% deductable as expense when calculating RFCT and SC.

 

 

 

Norway also peaked, so imports from there are declining.  African countries inlcude Algeria (peaked) and Nigeria.

 

 

 

 

 

 

 

 

 

 

DECC is using a conversion factor of 7.5 barrels per ton of oil so 44 mt in 2013 is 904 kb/d. And gas is 657 boe/d.

 

 

“The UK relies on oil products to meet a considerable portion of energy needs. Oil demand is expected to stay relatively constant in the UK in the short to medium term, that is at least to 2030, according to the current projection. Over time, technology changes, including electric vehicles and the generation of more heat from renewables, together with Government energy efficiency policies such as seeking to encourage greater use of public transport, should reduce demand for oil. The timing and scale of these demand decreases is uncertain.” (p 55)

 

 

The offshore decommissioning market in the North Sea.

 

 

 

 

Those 24 Gboe (oil and gas) hotly debated during the independence campaign appear to be largely exagerated because half of that includes additional and yet-to-find resources the development of which is uncertain. In terms of proven and probable reserves DECC estimates that there are only 8.3 Gboe. In any case, oil and gas production may at best remain flat for a couple of years, followed by relentless decline. In light of declining revenue from the oil and gas sector the question of how this is spent both by region and sectors of the economy will not go away. It seems the Scots have missed their last chance to get a larger part of the remaining pie because if the next referendum were held in 10 years who knows how much is left.