Phase Behavior of Highly Waxy Gas Condensate Systems
Phase Behavior of Highly Waxy Gas Condensate Systems
Kai Luo, Shi Li, Xitan Zheng, Henian Liu, Taixian Zhong, Yuxin Zhu, Research Institute of Petroleum Exploration and
Development
Abstract
As still deeper formations are drilled, gas condensates
containing high carbon-number hydrocarbons which may
precipitate during production and in the reservoir, are
encountered. An increasing focus of attention on its phase
behavior has been made worldwide in recent years. The main
purpose of this paper is to investigate experimentally the
characteristics of phase behavior of this new type of gas
condensate systems with high wax content. Therefore, a series
of experiments are carefully made for different GOR fluids,
including constant composition expansions and the
determination of wax deposition points. The separator gas and
liquid are collected from the same producer and recombined in
the laboratory to cover the ranges of GOR encountered in the
field.
The results show that the quality lines of the highest GOR
fluid in two-phase region are parallel to each other and
terminated at the appearance of wax deposition. Thus the fluid
has no convergence point, or critical point. It is also found that
the biphase regions expand with the increase in GOR. In other
words, gas injection may highly increases the saturation
pressure locus contrary to the usual belief that the two-phase
region will become smaller as more gas injected into the
reservoir leads to more leanness of the reservoir fluid. Another
interesting finding is that the more amounts the heavy
hydrocarbons, the lower dew- & bubble- point pressures of the
gas condensate systems used in this study. This is also
contrary to the previous literature results that increasing
amounts of heavy hydrocarbons increase the retrograde dew
point pressure. Thus the deduced conclusion28 that a
compositional gradient in the segregated fluids results in
higher observed dew point pressures at the bottom of the fluid
column, may not be made to the highly waxy gas condensate
systems used in this study.
Additionally we also found the wax deposition temperature
increased with decreasing GOR.
Introduction
A thorough understanding of pore-scale flow mechanism1,
relative permeability2 and phase behavior3 is very important to
predict the performance in gas condensate reservoir.
The search for hydrocarbon accumulations in deep strata
has lead to numerous discoveries at extremely high-pressure
high temperature conditions, for instance, up to about 110MPa
and 200C, which impose specific technical difficulties in the
development4-14. Under these underground conditions, the
reservoir fluids may contain significantly high molecular
weight hydrocarbons. These components may precipitate at
the temperatures and pressures encountered during production
and transport. Therefore, the wax deposition from gas
condensate production facilities and pipelines is very
undesirable, as it often leads to malfunction of equipment and
a large economic loss. It has been reported in an Eni Agip
offshore gas and condensate field15 that the surface processing
system may be plugged by wax deposition and the interruption
of the production lead to a loss in terms of delayed production
of the order of 1.25 million US$.
While wax precipitation from crudes has been extensively
studied, precipitation from gas condensates is not generally
well recognized14. A better understanding of the overall phase
behavior, including the popular gas-liquid equilibria and wax
crystallization characteristic, would help to analyze the
reservoir performance and design the processing facilities.
Recently there is a growing body of worldwide interests4,5,9-22
in the phase behavior of gas condensate with high wax
content, or precisely the heavy normal alkanes with high
melting temperature. One may encounter wax precipitation at
temperatures as high as 65.55C13,14.
In 1995, Ungerer et al.9 reported the multiphase behavior
of two actual reservoir fluids and four synthetic fluids, which
may be the first contribution to the complicated behvior of gas
condensate containing significant amount of high molecular
weight hydrocarbons. In their study two high pressure
equipments were used to investigate the gas-liquid, solid-gas,
solid-liquid-gas envelope curves. In 1998, Ungerer et al.10
SPE 68228
Phase Behavior of Highly Waxy Gas Condensate Systems
Kai Luo, Shi Li, Xitan Zheng, Henian Liu, Taixian Zhong, Yuxin Zhu, Research Institute of Petroleum Exploration and
Development
also briefly described crystallization behavior of heavy
hydrocarbons from three synthetic condensate gases at high
pressure conditions.
Leontaritis12,13 later described in detail the thermodynamic
behavior of asphaltene flocculation (also called Asphaltene
Deposition Envelop, abbreviated as ADE) and paraffin
crystallization (also called Wax Deposition Envelop,
abbreviated as WDE) and pointed out their distinction in
physical nature. He used Near-Infra-Red (NIR) equipment to
measure the WDE of several Mexico gas condensate systems
and projected the results on the calculated gas-liquid phase
diagrams. Based on his introductory studies, a new physical
mechanism of deliverability impairs in gas condensate
reservoirs was suggested conceptually, that is, the productivity
loss may be due to wax-induced formation damage about the
wellbore.
More recently Nichita, Goual and Firoozabadi14 studied
wax precipitation for gas-condensate fluids in detail using a
thermodynamic model. Some basic differences between wax
precipitation from gas condensates and wax precipitation from
crude oil were mentioned. That is to say, the pressure effect on
wax precipitation from petroleum liquids increases wax
appearance temperature or the cloud point temperature (CPT).
For gas condensate systems it may have an opposite effect.
More interesting is that they theoretically found out that the
wax precipitation phase exhibited retrograde phenomena
similar to that in gas condensates. As a result of isothermal
pressure decrease the amount of the precipitated wax may
increase first, then decrease and increase again.
Exprimental
Apparatus.
As in other presentations23,24, the JEFRI PVT
system was used in this work. The apparatus is a mercury-free,
high-pressure windowed PVT system equipped with video
camera-monitor-recorder facilities and computer-controlled
pumps. The maximum working pressure of PVT cell is
103.41MPa, the maximum operating temperature 180.0C and
the maximum volume 100cm3. The windows on the front and
back of PVT system are allowed to observe visually the phase
conditions in the cell. The special design of piston in the cell
aims at measuring accurately the small volume of liquid phase.
The system is calibrated and inspected routinely by the
Authoritative Management.
Fluids.
The laboratory fluids are all recombined with the same
separator gas/liquid according to the producing GOR
encountered in one gas-condensate field in China.
Table 1 shows the physical properties of the separator
condensate. The condensate does not contain resins and
asphaltene, but the content of wax is very high, even up to
14%. The freezing point of the condensate may be high up to
14C which is always higher than the separator temperature,
therefore, to keep the temperature of separator above the
freezing point is very important for sampling the condensate.
The original reservoir pressure and temperature are
56.0MPa and 138C, respectively. According to the GOR
range of the producing wells, four gas condensate fluids are
recombined with the same separator gas and liquid. Table 2
shows the GORs and compositions of the recombined fluids.
The GORs are 1367.4, 900, 800, 750m3/m3, respectively, the
corresponding C7+ content are 6.44, 9.22, 10.18, 10.73
mol.%. These values mean that these fluids are rich and nearcritical
gas condensate systems.
Procedures.
Each fluid sample is first transferred into the
PVT cell and pressurized up to the original reservoir pressure.
A series of isothermal constant composition expansion (CCE)
processes are conducted. At a given temperature, the onset of
dew- or bubble- point was judged visually through the window
of the PVT cell, and determined by the first appearance of a
liquid drop at the bottom / gas bubble at the top of the cell.
The equilibria in the CCE processes in this work are
achieved through gradual and progressive depressurization at
very small interval instead of the usual agitation of rocking the
cell. The good reproducible results are obtained in the
laboratory to check the reliability of this method.
In following sections, we will give the experimental results
of four fluids and discuss the characteristics of the phase
behavior with the changes of GOR and heavy hydrocarbon
contents.
Results
Fluid 1 (GOR=1367.4m3/m3)
. This fluid is subjected to eight
different isothermal CCE processes at temperature ranging
from 25.0 to 138C. The fluid exhibit retrograde dew-point
behavior at all test temperatures. The measured percentage
volume of liquid dropout is presented in figure 1. The results
shows that the dewpoint pressure decreases with increasing
temperature and the retrograde curves almost seems to be
symmetrical with respect to the pressure at which maximum
liquid condensed out of the vapor phase.
Figure 2 demonstrates the phase diagram of this fluid by
cross-plotting the curves shown in figure 1. It is seen that the
quality lines are in parallel to the dewpoint locus and does not
exhibit a converging behavior as reported normally in the open
literature. The dewpoint curve and the quality lines are
terminated due to the appearance of wax. The complicated
phase behavior in the course of isothermal pressure decline at
22.0C is colorfully shown in figure 3. Even the pressure
increased to 70MPa, a large amount of wax deposited in PVT
the cell, that is, a whole system exhibited gas-solid two-phase
equilibria condition. The upper gas shows bright yellow color,
the lower solid shows black-gray color. Surprisingly, when a
litter more pressure declined, the upper gas exhibited the
normal retrograde condensation performance, implying more
liquid accumulation. At the same time, the solid gradually
disappeared when more liquid condensed. At lower pressure,
the system contained in the PVT cell shows a layering
behavior. The observed behavior of wax may be consistent
with the retrograde condensation of wax as reported by
Nichita, Goual and Firoozabadi, however, the safety
consideration due to extremely high pressure did not allow us
to observe the increasing stage of wax deposition during first
depressurization.
Fluid 2 (GOR=900.0m3/m3)
. CCE measurements are
conducted at five different temperatures. During the five CCE
processes, the fluid exhibits retrograde dewpoint behavior.
The liquid dropout curves are shown in figure 4. It is seen
from figure 4 that the dewpoint pressure increases with
decreasing temperature. It should be noted that solid phase
was observed at temperatures of 30.0C and 18.2C and at
high pressure. However, retrograde dewpoint phase change
occurred in the presence of solid phase, thus the retrograde
curve at 30.0C seems to cross the curve at 61.0C.
Comparison with the results of fluid 1 shows that wax
deposition temperature is higher for the lower GOR fluid.
Figure 5 presents the phase diagram of fluid 2. The phase
diagram clearly demonstrates five regions where single phase
or different multi-phases occurred.
Fluid 3 (GOR=800.0m3/m3)
. Three isothermal CCE processes
are performed for this fluid. At one temperature the fluid
exhibits bubble-point behavior and at other two temperature
the fluid exhibits dew-point behavior. Thus the critical point
must lie in the range between 50.0C and 62.0C. The
percentage liquid volumes are plotted in figure 6 and the
subsequent phase diagram is shown in figure 7.
Fluid 4 (GOR=750.0m3/m3)
. This fluid is subjected to eleven
different isothermal CCE processes at temperature ranging
from 55.0 to 138C. Among them, the fluid exhibits bubblepoint
behavior at five temperatures and exhibits dew-point
behavior at other six temperatures. The liquid volume percent
is shown in figure 8, for clarity it is also enlarged in figure 9. It
can be determined from figures 8 and 9 that the critical point
of this fluid must locate in the narrow range of 68.5C to
70.0C.
Discussions
Saturation Pressure Changes with GOR.
Figure 11 shows
the phase envelope locus of the four fluids. It is found out that
the biphase regions expand with the increase in GOR. Herzog25
demonstrated that the two-phase region inside the phase
envelop of the produced gas will become smaller with
reservoir depletion in his figure 4. Thomas et al.26 suggested
that lean gas injection into the reservoir will results in a
suppression in the two-phase region as elucidated in their
figure 4. However, it can be concluded from this study that the
two-phase region may first expand in the process of gas
injection.
Also, the changes of bubble-point and dewpoint pressures
with increasing GOR are plotted in figure 12 which shows that
the saturation pressure increases dramatically with the increase
in GOR when GOR is less that about 900m3/m3, however,
increase gradually when GOR is above about 900m3/m3.
Heavy component effects on the Saturation Pressure.
As
the same separator gas and liquid samples are used to
recombine the above four fluids, we can further investigate
effect of heavy hydrocarbons on the dewpoint and bubblepoint
pressure. The lower GOR fluid contains higher content of
heavy hydrocarbons. Figure 13 clearly shows the influence of
the amounts of C7+ fractions on the saturation pressure, that
is, the increase in C7+ content lead to decrease in saturation
pressure, which is in contrast with the literature reports9, 28,29.
The liquid condensed in the surface separators is usually
light-colored, brown, orange, greenish, water-white or
colorless. This field experience can help the engineers
conveniently classify the reservoir fluid as retrograde gas,
however, this empirical method sometimes lead to erroneous
judgments. In fact, black tank oil may occurred as gaseous
phase in the reservoir condition30-31, which means that the
heavy hydrocarbon fractions may have a more complicated
effect on the phase behavior of the subsurface fluids than the
expected.
Phase Transition Phenomena in PVT Cell.
Although the
dewpoint is usually judged from the emergence of the first
liquid droplet, we observed in our tests that the phase change
first occurred at the top of the PVT cell in the form of fluid
color turning into black as shown in Fig.14. This phenomenon
may be explained as follows.
Heavy hydrocarbons tends to locate at the lower part of
PVT cell due to gravity segregation effect, which leads to the
decrease in the dewpoint of fluid in the lower cell part.
However, the hydrodynamic effect makes the fluid pressure in
the top part lower than that in the lower part. Although the
difference may be very small, from the standpoint of phase
stability the small difference will make the upper fluid beyond
the stability limits. Therefore, it is necessary that the phase
transition first occur at the top part in the PVT cell due to
higher dewpoint pressure and lower fluid pressure in the top of
cell.
Comparison of the calculated phase behavior with the
experimental results.
In order to check the capability of the
cubic EOS prediction, the measurements of fluid 1 is selected
as an example. A popular phase behavior package is first
tuned with the results of the standard phase behavior studies,
the predicted phase diagram is shown in figure 15.
Comparison of the calculated diagram with the experimental
data, in figure 2, shows poor agreement is obtained, this may
be due to wax deposition effect that is not considered in the
package. On the other hand, this implies that a more rigorous
thermodynamic model is needed to reliably predict the overall
thermodynamic states that are very important to the design of
optimum development planning.
Conclusions
1. The waxy gas condensate may have not convergence
behavior, or critical point in pressure-temperature diagram.
2. Wax deposition temperature increased with decreasing
GOR.
3. The higher amounts of heavy hydrocarbon components
may decrease the bubble- and dew-point pressure of the
reservoir fluid.
4. The gas condensate reservoir fluid can exhibit complicated
phase behavior due to the presence of wax, such as the
three-phase wax-liquid-gas equilibria, retrograde dewpoint
phase change in the presence of solid phase. That is to say,
wax may precipitate before liquid formation.
5. Wax may deposit at the wellbore temperature and at the
extreme pressure above the original reservoir pressure. The
amount of precipitated wax shows an interesting
phenomenon. As pressure decreases, the amount of wax
may decrease and dissolve into the gas-liquid system.
6. More rigorous thermodynamic models are needed to
reliably predict the overall thermodynamic states because
the popular cubic EOS package is not capable of reliably
predicting the overall phase behavior of the highly waxy
gas condensate system.
Acknowledgement
The authors would like to gratefully acknowledge the financial
support for this programme provided by Tarim Oil Field
Company and CNPC. The authors would also like to thank
Research Institute of Petroleum Exploration and Development
for permission to publish this work.