Last year I blogged a few times on the first Petrohawk-operated, restricted rate well in the Haynesville. How did I know it was the first? Petrohawk said so in one of their conference calls. It has been a while so I feel the need to post an update. This will be short and sweet.
First, let’s set the scene. The border of Red River and De Soto Parish. Below is the map highlighting the 17H, as well as a number of offset wells (all HK operated). I used the nifty Drillinginfo label feature to identify the first prod date, the peak gas production, and the cumulative gas produced thus far.
Next I used a different tool in the Drillinginfo arsenal, HPDI. For those unfamiliar with HPDI, it is widely regarded as the best data set for US oil and gas production (ask the EIA among others). I exported the monthly production data and dropped it into an application called spotfire. I used spotfire to make the charts look pretty but you could use Excel to deliver the same results.
Of the 7 wells depicted, I believe only two were produced at non-restricted rates. This is based on the significantly higher IPs and initial declines. I say “restricted rate” in reference to the reservoir optimization technique as I am aware all wells are produced with some amount of choke control. These two non-restricted rate wells appear to have been choked back around month 3, as there are about 4 months of relatively flat production following the steep initial decline.
Can conclusions be made here? Sure, it took the Matthews 17H 5 months to catch up to the Matthews Trust 7 despite having an initial production rate 30% less. This data shows that reservoir optimization by restricting rates does in fact help the production in the first year. DI-ESP includes a very detailed study of restricted rates in our Unconventional Play Studies which includes the Haynesville. This quick blog does not go too deep into the details, but it does show how DI subscribers could go about performing these analytics themselves. Let me know any thoughts.