American Oil and Gas Reporter - February 2018 - 51

FIGURE 5
Eagle Ford Test Well Data
600

Skid Inlet Pressure (psig)

Primecor Operation

Skid Discharge Pressure (psig)

Skid Flow Rate (Mcf/d)

Compressor Flow Rate (Mcf/d)

Discharge Liquid Flow Rate (bbl/d)

500
400
300
200
100
0
14:00

14:15

14:30

14:45

15:00

15:15

15:30

15:45

change to a different well after only a
few weeks of testing.
Figure 4 shows an example of attempting to run the compressor to unload
the well. After a tumultuous startup, a
large slug of liquid passed through the
compressor (around 21:00). The well began flowing at that point and wellhead
pressure was quickly pulled down. It became apparent that the well was still
loaded, however, as it stopped producing
gas shortly after its pressure was pulled
down (the "skid flow rate" started to
drop while the "compressor flow rate"
remained high, an effect of the compressor
going into an automatic recirculation
mode to avoid starving the machine).
The initial evidence suggests that the
technology is capable of not only keeping
a well unloaded, but potentially has the
ability to help unload a well, in a similar
fashion to blowing a well down to an
open top tank. Figure 5 shows an example.
From 14:45 to 16:00, the compressor
pulled wellhead pressure down to nearly
zero and was in recirculation mode, essentially creating the same effect as opening a well to ambient pressure with an
ANKUSH GUPTA is a production
engineer at Repsol, working as a secondee engineer at Statoil in the Eagle
Ford joint venture asset. He has been in
the Eagle Ford production group since
2013 and has been involved with production optimization of different reservoirs. Prior to production, Gupta spent
five years as a drilling engineer for
shale wells in Canada, Pennsylvania
and Texas. He holds a mechanical engineering with management degree from
McMaster University.
JEREMY PITTS is senior vice president of engineering at Hicor Tech-

16:00 16:15
Time (h)

16:30

16:45

17:00

17:15

17:30

17:45

18:00

open top tank.
At 16:00, the well produced a large
liquid slug and the compressor was able
to process liquids at the rate of several
hundred barrels a day over the course of
the next hour or so, with the well beginning to flow again. After this unloading
process, the well started producing stable
flows without any additional artificial
lift, which it had not been able to do in
some time.
While the initial portions of the second
testing phase have produced positive results, this phase has yet to achieve all of
its goals. The project team is working to
align the compressor's capabilities to the
output of the well to deliquify the well
and provide an attractive economic return.
The results of the first phase, combined
with initial data from the second phase,
give the team a significant amount of
confidence that the test ultimately will
achieve a successful outcome and demonstrate multiphase compression technology's ability to achieve reduced line pressures without the added cost and complexity of building out wellhead liquids
handling facilities.
r
nologies, where he has led the development of the company's multiphase
compression technology since its inception in 2010. He holds four U.S.
and three international patents related
to compression technology. Prior to
Hicor, Pitts led efforts to develop and
launch a variety of new products across
the energy and aerospace sectors. He
holds a B.S. in mechanical engineering
from the California Institute of Technology, an M.S. in mechanical engineering from the Massachusetts Institute
of Technology, and an M.B.A. from
the MIT Sloan School of Management.
FEBRUARY 2018 51


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American Oil and Gas Reporter - February 2018

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