American Oil and Gas Reporter - February 2018 - 50

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The first phase was the initial installation
of the compressor to validate that it could
perform as expected and produce the
highly variable multiphase flows experienced in real-world conditions.
The first phase of testing was from
October 2016 through March 2017. While
there were challenges associated with
commissioning and starting up the test
(primarily associated with how to operate
a compressor package in a heavy liquids
environment), the testing produced favorable results. Figure 3 shows one example
of test data. The skid inlet and discharge
pressures are close approximations of
wellhead and line pressures. In this example, the compressor came on line and
pulled wellhead pressure down, stimulating
liquids flow. The suction pressure flexibility
of the compressor is apparent, pulling
inlet pressure all the way down to 15 psig
while discharge pressures still exceeded
the line pressure of 350 psig.
One challenge encountered was the
compressor's capacity and its ability to

keep up with the flow of the well. This is
evident in Figure 3 as the well appeared
to still load up from liquids despite the
compressor pulling wellhead pressure
down, as the throughput at that point was
only 150 Mcf a day. For much of the first
phase of testing, the compressor was operated on a slip stream, allowing the well
to produce at its full potential. Phase one
testing concluded after verifying that the
technology was able to successfully operate with greater than 90 percent availability over a long period.
A new well was selected for the second
phase of testing that was expected to be
a better fit for the compressor's specifications. The goal was to prove the technology would be capable of achieving
flow rates sufficient to keep a gas well
from experiencing liquid loading and sustain those conditions for an extended
time. This phase of testing began last
May. Early testing was complicated by
issues with the selected well already
being heavily liquid loaded, prompting a

FIGURE 3
Eagle Ford Test Well Data

1902 N. Yellowood Ave.
Broken Arrow, Oklahoma 74012 U.S.A.

500

Skid Inlet Pressure (psig)

450

Primecor Operation

Skid Discharge Pressure (psig)

Gas Flow Rate (Mcf/d)

Discharge Liquid Flow Rate (bbl/d)

400
350

Oilfield Improvements®
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COUPLINGS

300
250
200
150

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Directional and
Horizontal Wells
Used Successfully for Over
27 Years by Over 90% of
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in Over 40 Countries -
Onshore and Offshore
Wheels are
Field-replaceable

Call
800-537-9327
or Your Oilfield
Supply Store
www.rodguides.com
®

1902 N. Yellowood Ave.
Broken Arrow, Oklahoma 74012 U.S.A.
PHO 918-250-5584 * FAX 918-250-4666

50 THE AMERICAN OIL & GAS REPORTER

100
50
0
00:00:00

12:00:00

24:00:00

36:00:00

48:00:00

60:00:00
Time (h)

72:00:00

84:00:00

96:00:00

108:00:00

FIGURE 4
Eagle Ford Test Well Data
500
450

Skid Inlet Pressure (psig)

Primecor Operation 25-Apr-2017 15:03:46 - 23-May-2017 14:11:02

Skid Discharge Pressure (psig)

Skid Flow Rate (Mcf/d)

Compressor Flow Rate (Mcf/d)

Discharge Liquid Flow Rate (bbl/d)

400
350
300
250
200
150
100
50
0

May 06, 22:00

May 07, 00:00

May 07, 02:00
Time (h)

May 07, 04:00

May 07, 06:00

May 07, 08:00


http://www.rodguides.com http://www.rodguides.com

American Oil and Gas Reporter - February 2018

Table of Contents for the Digital Edition of American Oil and Gas Reporter - February 2018

Contents
American Oil and Gas Reporter - February 2018 - 1
American Oil and Gas Reporter - February 2018 - 1
American Oil and Gas Reporter - February 2018 - 2
American Oil and Gas Reporter - February 2018 - Contents
American Oil and Gas Reporter - February 2018 - 4
American Oil and Gas Reporter - February 2018 - 5
American Oil and Gas Reporter - February 2018 - 6
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