The problem mates is not just pressure but "drawdown". From the SONRIS report: 03/19/2010 10 8475 COMPLETED 2/18/10 AS A GAS WELL IN THE SIPH DAVISI; PM F; 400 MCFD; 0 BCPD; 2027 FTP; 3202 SITP; 6/64" CK; 0 BWPD; PERFS: 8372-8384'; (ST:10) The report shows "shut in tubing pressure" (SITP) which is the pressure recorded at the surface with valves closed. Reservoir pressure or bottom hole pressure (BHP) would be SITP plus the weight of fluid in tubing. A Google for normal pressure gradient in S.Louisiana shows .465 psi/ft which would be 3700psi. The "flowing tubing pressure" (FTP) is the back pressure while valve open at whatever choke is being used, the bigger the choke the lower the FTP. Yes the 6/64" is small, but the difference of nearly 1200 psi while flowing is actually very large for the relatively low rate. The operator must have determined that this was the optimal size to achieve a stable rate in the limited time available. Typical sales line pressure is around 1000psi so as the FTP declines with production at that point a compressor is needed or the zone is abandoned. There are several possible explanations for the large drawdown required for the small observed flow rate including near wellbore formation damage, limited permeability or more importantly a small reservoir. Presumably this will become clear in time.
VIL Price at posting:
3.3¢ Sentiment: None Disclosure: Not Held
