American Oil and Gas Reporter - May 2017 - 59

SpecialReport: Gas Compression Technology
beginning to lead to some minor turndown
issues in the amine plants.
In mid-2015, the facility's design was
examined to optimize treating gas based
on a 3 percent inlet CO2 concentration at a
full processing capacity build-out of 900
MMcf/d. The engineering team began pursuing options to increase amine
utilization/gas capacities in the amine plants
by modifying gas contactor internals,
procuring additional gas contactors, or
both. These optimization efforts were intended to eliminate future turndown issues
and eliminate excessive future capital spending through full amine utilization, while
also providing operational flexibility.
By late 2015, the inlet CO2 concentration had declined to approximately 1.5
percent. The operating plant's treating
portion still consisted of 300 MMcf/d of
gas capacity and 1,775 gallon/minute of
total amine capacity, with 300 MMcf/d
of cryogenic processing. An expansion
of the 1,300 gallon/minute amine system
was under way to increase the gas capacity
with an additional 150 MMcf/d contactor
and efforts continued to re-tray the other
contactors to maximize gas capacity
through the amine system.
In addition, a new 1,400 gallon/minute
amine system was under construction,
with a capacity of 300 MMcf/d that could
be increased to 400 MMcf/d. The final
design of the gas treating plant consisted
of 3,175 gallon/minute of amine regeneration and 900 MMcf/d of gas capacity
for the final envisioned build-out of 900

MMcf/d of cryogenic processing capacity,
with the ability to accommodate as much
as 3 percent inlet CO2 and the flexibility
for lower concentrations.
The plant's liquid handling system
was upgraded in 2015 with a 2,000 barrel
harp-style slug catcher, liquids line heater,
low-pressure stabilizer to process the
flashed slug catcher liquids, and a new
condensate tank farm for increased storage
capacity. The LP stabilizer allowed the
condensed inlet liquids to be processed
into a higher-value condensate product
and an off-spec NGL product.
This was a temporary design solution,
and engineering was under way at the
time of the incident to construct an HP
stabilization train to process the liquids
associated with the full build-out of the
plant. This project would eliminate all
trucking and increase the liquids' product
value by creating two on-spec liquid
products that could be sold through
pipelines from the facility. The system
produced an NGL product that would be
blended with the Y-grade product from
the cryogenic plants and a high-gravity
condensate product.
Plant Restart Phases
The four main phases of the Ramsey
plant's re-engineered design and staged
restart coincided with various project
completion dates and allowed volumes
to be ramped according to the systems in
place at each stage (Table 1).
Phase 0 allowed for lean, low-CO2 vol-

umes from a single large Delaware Basin
producer to enter the plant through a temporary inlet for processing in Ramsey III.
The lean gas allowed limited liquids handling
that flashed drain fluids to an off-spec NGL
tank for truck loading. Given the low CO2
concentrations, the plant was able to operate
and meet product specifications without an
operating amine system.
Phase 1 was the primary startup phase
that allowed other producers to send
richer, higher-CO2 gas into the system
up to the Ramsey III capacity limitation.
This startup coincided with the commissioning of the new harp slug catcher, the
1,400 gallon/minute amine system, and
a robust temporary liquids treating system.
The next phases coincided with the startups
of Ramsey IV and V, as well as the
startup of the HP stabilizer and decommissioning of the temporary liquid handling system that had allowed for Ramsey
II's recommissioning.
The new inlet design improved safety
by creating more space between the receiving area and plant equipment, adding
more remote emergency shutdown capabilities and elevating inlet pressure safety
relief. At the same time, incoming pipelines
were rerouted because of the damage.
This allowed the inlet receiving area to
be placed on the east side of the plant
outside the battery limits.
New locations for the inlet slug catcher
and liquids handling unit were scoped
out on the facility's southern portion,
which allowed demolition efforts on the

TABLE 1
Ramsey Plant Commissioning Phases
Gas Quality

Inlet Design

Liquid Handling

Amine Plant

Cryogenic Plant

Phase 0

Lean/Low CO2 Gas

Inlet Separator
w/single pipeline

Bullet Tanks with truck
loading

None

RAM III

Phase 1

All Gas

Harp Slug Catcher
w/all pipelines

Temporary Liquid
Treating

1400 Amine

RAM III

Phase 2

All Gas

Harp Slug Catcher
w/all pipelines

Temporary Liquid
Treating

1400 Amine
w/additional
contactors

RAM III, IV

Phase 3

All Gas

Harp Slug Catcher
w/all pipelines

HP Stabilizer

1400 Amine
w/additional
contactors

RAM III, IV, V, II

MAY 2017 59



American Oil and Gas Reporter - May 2017

Table of Contents for the Digital Edition of American Oil and Gas Reporter - May 2017

Contents
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