Monsieur George
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Ron Patterson es un colega que lleva muchos años dirigiendo un grupo de discusión sobre energía llamado "Energy Resources" y está muy vinculado a ASPO USA y a los estudios sobre energía neta y es bastante más serio, mucho mejor documentado y más imparcial que los periodistas de la prensa de gran tirada (los llamados Main Stream Media o MSM) que obedecen a intereses particulares de poder.
Se empieza a entender mejor, en mi modesta opinión, por qué los EE.UU., si como intuyo, son los que dirigen la operación de tirada de los precios del petróleo recientes, utilizando para ello a su país subsidiario, Arabia Saudita, se estén dando teóricamente un tiro en el pie de su propio fracking.
En alguna ocasión he dicho que uno quizá piense en darse un tiro en el pie, si tiene a algún enemigo mortal pisándole la cabeza y quiere eliminarlo. Pero si además, sabe que el pie tiene gangrena y pocas posibilidades de salir adelante a largo plazo, entonces puede darse el tiro hasta con gusto. Es decir, que el sueño del fracking se está acabando y de ahí las prisas de los mercaderes del negocio rápido por comprometer compras de equipo y tecnología a países facilones, con dirigentes capaces de firmar lo que haga falta, con tal de pillar comisión y salir todos corriendo. Alemania acaba de volver a decir no al fracking. Francia ya lo había dicho. Otros, como Polonia o España, aunque también un desesperado Reino Unido, firman lo que se les ponga por delante.
Los datos que ofrece Patterson sobre declinaciones productivas de Bakken son enormemente detallados. Una de las grandes ventajas de EE.UU. y que me produce admiración, es su forma de documentar detalladamente sus acciones, hasta incluso las terroristas de la CIA y la NSA, en cuanto pasan los periodos que consideran de caución. Esto permite a los escudriñadores como Patterson o David Hughes, sacar conclusiones con datos oficiales que jamás se podrían esperar de nuestros llamados "especialistas" nacionales. No imagino ese nivel de detalle y transparencia real en los permisos, contratos y licencias adjudicadas para "explorar" cuencas para fracking, principalmente en la parte norte del país, aunque también en la cuenca del Guadalquivir y otras. Les dejo, pues, con su último artículo titulado "los puntos 'dulces' de Bakken se están agotando" (punto dulce tiene una definición muy precisa en cuanto a productividad diaria por pozo y son los mejorcitos de cada cuenca, pero de esos suele haber pocos. En los gráficos de David Hughes se definen con mucha precisión los mismos y se colorean por productividad.
Patterson los ha clasificado por número de pozos, según el número de permiso concedido.
La Comisión Industrial de Dakota del Norte publica un informe diario (igualito que hará el gobierno vasco o el gobierno central, por poner dos ejemplos) de los pozos productivos completados ese día, así como los pozos que se hacen públicos y pierden su estatus de confidencial. La mayoría de los pozos listados ofrecen la producción de las primeras 24 horas en barriles por día. Lo que hace notar Patterson es que ha habido un declive brutal de la producción en barriles por día a medida que aumenta el número de pozos perforados. Esto es una clara indicación de por dónde van los tiros y los procesos de agotamiento de las cuencas de fracking.
Pedro Prieto.
Bakken Sweet Spots are Petering Out
by Ron Patterson Posted on November 22, 2014
The Bakken, as well as other shale oil areas, is not one homogeneous area where equal amounts of can be found. David Hughes in DRILLING DEEPER puts it this way, though here he is talking about gas wells, the same applies to oil wells:
All shale gas plays invariably have “core” areas or “sweet spots”, where individual well production is highest and hence the economics are best. Sweet spots are targeted and drilled off early in a play’s lifecycle, leaving lesser quality rock to be drilled as the play matures (requiring higher gas prices to be economic); thus the number of wells required to offset field decline inevitably increases with time.
However the Bakken, at least through the September North Dakota Industrial Commission production report, has given no real indication that the Bakken is even close to peaking. But a closer look at the data makes me believe that is all about to change.
The NDIC issues a Daily Activity Report where they list permits issued as well as wells completed and wells released from the tight hole confidential list. These reports usually, but not always, also give the number of barrels of oil per day and barrels of water per day for the first 24 hours of production. I have gone through every day, back to November 1st, 2013 and collected the data on every well listed that gives production numbers and copied that data to Excel. In that one year and three weeks I have gathered the data form every one of the 2,171 wells that give production numbers. Sorting these wells by well number, which is the original permit number, gives some startling results.
To smooth the chart I created a 200 well average of barrels per day per well. The first point on the chart is therefore the average to the 200th well, #23890 and the last point is the 200 well average to the 2171st well, #28971. As you can see there has been a continuous, though erratic, decline in first 24 hour production as the well numbers increase.
Breaking this down according to well numbers we see production peaked with the 2400s and have steady decline since. Every group of well numbers do not contain the same number of wells.
Well Numbers BOPD Number of Wells in Sample
18s – 22s 1,235 81
23000s 1,362 134
24000s 1,497 285
25000s 1,320 676
26000s 1,198 591
27000s 1,016 361
28000s 841 40
The above chart is monthly first 24 hour production per well and first 24 hour percent water per well of all wells that the NDIC listed production numbers. The November 2014 numbers are only through November 21st.
Note: The first 24 hours of production is far from being the average first years production. And though all wells are different I am relatively sure there is an average conversion rate but I have no idea what it is. I would guess it is somewhere between one quarter to one third of the first 24 hours of production. But if anyone has any idea what the average conversion factor is, if one exists, please email me at DarwinianOne at Gmail.com, or post it in the comments section of this post.
North Dakota issues drilling permits in sequential order. But those permits are not drilled in sequence. Drillers will often sit on a permit for two to three years, renewing then as the law requires.
A list of all active drilling rigs, the well number they are working on and the date they started can be found at the NDIC’s Current Active Drilling Rig List They are listed according to their API number but the list can be copied and pasted into Excel and sorted according to your wishes.
Of the 191 rigs working, 39 or 20% are working well numbers below 28000. 76 or 40% of rigs are working well numbers in the 28000s. And 76 or 40% are working well numbers in the 29000s. Permit #28000 was issued on March 26. 2014. So 80% of all rigs are working on recently issued permits.
As of November 21st, the highest well number completed was #28971. The highest number well currently being drilled is #29908. The highest permit number issued is #30076.
Will enhanced oil recovery keep the Bakken going into the future. A simple one word answer is “no”, as this article explains.
Enhanced oil recovery techniques limited in shale
Energy companies currently leave about 95 percent of the crude in the ground at today’s unconventional oil wells, but they face major technological challenges in boosting recovery rates, a Schlumberger scientist said Tuesday…
“Our entire spectrum of secondary recovery methods don’t work,” Kleinberg said, in a sobering talk at the Energy Information Administration’s annual summit in the nation’s capital.
Water flooding — where water can be swept from separate injection and producer wells — isn’t an option because the tight oil formations are too dense to permit those water flows.
And while carbon dioxide can be used to pressure up a conventional oil well, there’s currently a limit on the amount of that gas that is available to pump underground. “The oil industry would like to have more CO2, which is a great way to get more oil out of the ground, but there are limits on affordable, accessible supplies of CO2,” Kleinberg said, quipping: “The oil industry lives in a CO2 constrained world; it is only the oil industry that thinks there is not enough carbon dioxide.”
In conclusion, first 24 hour production per well, when measured by well number, has dropped by 40 percent since peaking in the 24000s. This, to me anyway, clearly indicates that the sweet spots are playing out and companies are now drilling on less productive acreage. I now believe that North Dakota production will peak no later than 2015 with a high probability that 2014 will prove to be the peak year.
Bakken Sweet Spots are Petering Out - Peak Oil BarrelPeak Oil Barrel