The reason producing X amount of oil depends on Pressure difference between reservoir and bottom hole of the well. Bigger the differential pressure, higher the flow rate of the well and depend size reservoirs, thickness, porosity, permeability, deep, pressure, temperature, skin, etc
A good question and one that has a multitude of answers as the type and age of well are determining factors among many other aspects of the geology. Many new new expensive horizontal wells using the latest hydraulic fracture technology with massive amounts of proppant (sand placed in the fractures to keep the oil flowing having a new record of 15 train car loads) can be upwards to 30,000 barrels of oil per day, especially in offshore basins that are under heavy discussion with costs upwards to $100 per barrel in tight sands. This production figure rivals that of the greatest conventional oil finds such as the East Texas Field found by "Dad Joiner, and financed and produced by my extended relative the late great H.L (Haroldson Lafayeatte) Hunt of Hunt OIl starting with the Daisy Bradford 3 in 1929 that went on to produce 5 billion barrels of oil. Other prominent finds include "Spindletop" at the turn of the century. Many of these old wells can still put out one to two barrels per day.
I personally am among the cutting edge pioneers in advanced EOR technology development that has the potential to produce about 2,600 barrels per day from gravity assisted drainage horizontal shallow wells using technology as new and as exciting as non-conventional deep drilling with the advantage that the wells are from 500 feet deep to 2,500 feet deep typically which are exceedingly inexpensive and while horizontal legs are employed no fracking and no sand to hold fractures open is required as the drilling is into high porosity; porous sands and total per barrel costs of drilling and production combined can be less that $10 per barrel that I personally believe is the answer to OPEC in regard to US low cost oil production again employing advanced US technology. An overall output US oil well average production is most likely on the order of 10 barrels per day taking all the different age and type of wells into consideration.
One well producer could be from 20 BOPD to 12000 BOPD, depend size reservoirs, tickness, porosity, permeability
I can't tell what is average production of oil in Texas. But, in other questions, I think I can help you. "What causes a well to produce X amount of barrels per day?" This is physical process. The reason producing X amount of oil depends on Pressure difference between reservoir and bottom hole of the well. Bigger the differential pressure, higher the flow rate of the well. "What factors play in determining the number of barrels per day and why? " The main factor is money. Money includes in itself: Oil price per barrel and cost of one produced oil. The oil production is stopped when cost of one barrel produced oil equals to the price of oil in the market. This terms is called: "Marginal limit".
In General, Oil & Gas is Found in the Sub-surface. Oil is Generated within a Source rock (a rock that is rich in organic Material), Due to the heavy Load of the overlying rock layers, it is squeezed out and migrate through porous & permeable Reservoir rock, until the flowing route is blocked by any geological means. The moving fluid is then trapped and accumulates at this closed Trap, waiting for some one to find it. Here comes the role of the Oil Explorationists. Oil can be associated with Gas and or Water or none. When Production Starts, Rate of production is dependent on so many factors: 1- the subsurface geological Reservoir characteristics (such as Porosity, permeability, volume, Pressure, Temperature,....etc "the higher values the higher rate of production). 2- Fluid Properties (such as Density, viscosity, dissolved gas,...etc, (The lighter the fluid the higher rate of Production per well. So each oilfield well has its own case. An oil well can produce from 10s to thousands of barrels depending on their Subsurface Reservoir conditions and the Oil physical properties. Hope this, answers Yevonne`s Question
The link above is to a previous question that I had posted on OilPro seven months ago regarding the greatest daily output of a single well that you might find interesting and applicable to the current discussion.
Stated within the post is information about Petrobras the State oil company of Brazil in the Pre-Salt layer of the Santos basin in Sapinhoá field offshore Brazil. The wells in this field are producing at an average of 30,000 barrels per day of oil with the largest single well daily output being 36,000 bopd.
Further this former post discusses the estimated BP spill being at an estimated 62,000 bopd, thought to be close to some of the largest strikes in the world that are not well known, especially in the middle East; Alaska and Arctic, etc. with information held by private companies that do which to disclose the information publicly. The point being is that there have been dramatic oil finds in the course of oil's exploration history with enormous daily production output.
The permeability and porosity of the reservoir rock are factors. Some other factors include whether or not there is gas dissolved into the oil, which provides a source of power to the uplift of oil through the wellbore, the volume of oil in the reservoir (which is a function of the size of the reservoir), number of other wells in the field, and type of lift used to produce the oil.
Even more important to the long-term economics of the well is the decline rate. The decline rate is the decrease in production that happens each day that the well is producing. Say a well is producing 1000 barrels per day on Day 1 (IP Rate), then drops to 995 barrels on Day 2, then 991 on Day 3 and so on.. The production decrease is important to know because it is predictive of future production and therefore future revenues from the wells. Once the cost to operate the well is more than the revenue generated from operating it (yes, the wells do have a cost to operate even after the drilling / fracking is over), then the well will likely be shut-in until either a workover can be done (if cost-effective) or the barrel price at the wellhead recovers to make the well profitable again.
All of these economic and physical conditions (and many more!) are important when understanding well productivity.
What might be more pertinent is what kind of conventional flow rates do they see on the North Slope ?
See items at bottom of page.
This gives one an idea of what is required for the well to be economic in this region.
But then things r complicated again by the fact that some of the newer wells r hybrids, that being, the reservoirs have both conventional and unconventional completion techniques applied.
All this being said the thing with conventional wells is their ability to have low decline rates and this is driven by a goodly GOR or gas to oil ratio. We know we have good overpressure and also liquid vapour phase which must exist within the oil fraction. If so, this should also provide drive for the liquids to flow and hopefully also lower viscosity. Another important factor is the permeability and again we know we have much higher permeability than the better producing Lower 48 strata, even the eagle Ford.
As we've talked about many times, the Ice 1 parameters far exceed whats required for a successful well so I guess the expectation is as management have mentioned, the potential to flow like a conventional well.
I'm wondering if they are expecting/hoping for a good flow rate AND slow decline rates mor akin to conventionals. Don't forget this can also be managed/manipulated with gas/water injection as well.
Repsol completes tests of two Alaska North Slope wells
HOUSTON, June 5
06/05/2015
Repsol SA says it has completed testing two wells during its winter exploration campaign in Alaska’s North Slope with better-than-expected yields of good quality crude that, along with positive results from previous campaigns, confirm the development potential of the area.
Including sidetracks, the ANS campaign has resulted in 16 positive wells drilled during four winter exploratory campaigns since Repsol acquired its acreage in 2011 (OGJ Online, Mar. 10, 2011; Apr. 23, 2013).
The current campaign has seen the Qugruk 8 (Q-8) well flow 30° gravity crude at rates of as much as 2,160 bo/d, and Qugruk 301 (Q-301) horizontal well yield rates as high as 4,600 bo/d.
Conoco is already constructing drill sites in the National Petroleum Reserve: one being built this winter, the Greater Mooses Tooth 1 project, is expected to produce about 30,000 barrels per day. But after drilling two test wells nearby, the company announced an oil discovery that could produce much more than that.
“Depending on the development scenario, it could be up to maybe 100,000 barrels a day of production when we actually get it up and running, so I think it’s a pretty big deal,” ConocoPhillips president Joe Marushack said at an industry conference in Anchorage, right after he announced the Willow Discovery.
NOTE: These Conoco numbers r PROJECT numbers so one would think we r talking multiple long horizontal wells from the same pad. So we can probably bring these numbers back down to sub 10,000bbls/day
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