I have been associated with a number of North Louisiana Haynesville Shale wells & have also studied many wells in Mississippi that are productive from sands that are Layered within the Haynesville Shale. I don't know of any of them that have issues related to Carbon Dioxide or Hydrogen Sulfide. Like all other wells, they do produce CO2 & H2S, but they do so in very small concentrations.
The geological characteristics of the Berkley-Phillips Well, along with the way that MNLU designed the well make it very difficult to compare its production rates to the decline curves seen North Louisiana.
Below, I have briefly discussed some characteristics making MNLU's well unique:
Storage Capacity - MNLU's pay-zone is under 2.5 times the pressure that are seen in North Louisiana. This means that the pore-space in the shale will hold far more gas than the pore-space in North Louisiana's Haynesville [PV=znRT]. A lower % water saturation has also left more room for methane to hydrogen bond with the surface of the shale grains. The existence of natural fractures enhances the storage capacity of the reservoir, because those fractures are full of natural gas.
Permeability - Permeability is the ability for methane (in this well) to flow through the formation through a network of pores into a natural or synthetic fracture and then into the well-bore. A shale with a high storage capacity is of no benefit if the natural gas is unable to negotiate passage to the well-bore. The reservoir pressure on the Burkley-Phillips#1 is very high and will drive the small methane molecules through smaller pores that wouldn't be possible with lower pressure differentials. The Natural fractures will also enhance the gas's ability to flow to the well-bore. Also, much like the Deep Bossier fields of East Texas, thin, clean sandstones called turbidites are layered in the 2000' shale body and will serve as highly permeable highways, delivering the gas to the well-bore.
Drainage Basin - increased permeability will result in an increased size of the well's drainage basin. Pushed by the high pressure, gas will be able to flow from deep with the shale that wouldn't be possible with less pressure, or less permeability. This will increase the well's production life and ultimate recoverable resources.
I have stated before that the Burkley-Phillips #1 was capable of IP rates of as much as 50MMCF/D, but later did the math & discovered that wasn't possible using the size tubing that MNLU has ordered. 25 to 30 MMCF/D is the Maximum flow-rate that can be achievable from this well configuration. MNLU's Engineers have determined that a production rate of 19MMCF/D is the ideal rate in order to maximize production over the life of the well. I suspect that, after completion, the well will be capable of producing 19MMCF/D for a prolonged period of time (meaning years).
If anyone has an interest in the capability of this field, I urge you to google for .pdf presentations that discuss the Amorusa or Deep-Bossier Fields of East TX. While doing so, please consider the fact that MNLU's well has a reservoir pressure over 21k psi, while the prolific fields mentioned only see a maximum reservoir pressure 16k psi.
