| NO. |
Title |
Presented at
&
Date |
Author |
Project Team / Research Division |
| Abstract |
| 10798 |
Asphaltene Precipitation During CO2 Injection in Sandstone
and Carbonate Cores: An Investigative Analysis Through
Laboratory Tests and Compositional Simulation |
24th Annual Workshop & Symposium Collaborative project
on Enhanced Oil Recovery International Energy Agency
2003/9/9 |
Satoru Takahashi (Japan National Oil Corporation) |
Research Division for Petroleum Engineering |
[Abstract] Characteristics and impact of asphaltene precipitation
during CO2 injection were investigated for a Middle East
crude oil in both sandstone and carbonate cores through
phase behavior studies, corefloods and analyses of the
deposition process using a compositional simulator. In
phase behavior studies, a light-scattering technique with
near infrared was used to determine the onset pressure
of asphaltene precipitation. Also investigated were the
effects of CO2 concentration on precipitation, including
the potential for precipitation by CO2 at the current
reservoir pressure.
The coreflood tests were conducted above the minimum miscibility
pressure (MMP) in both carbonate and sandstone cores to
investigate any difference in asphaltene precipitation
characteristics in them. The asphaltene content in the
produced oil decreased after the CO2 breakthrough -- an
indication of its precipitation within the core. A careful
post-test analysis of the flooded cores revealed that
a larger amount of asphaltene was left behind in carbonate
cores than sandstone core.
A compositional simulation study with tuned EoS parameters
was carried out to evaluate coreflood results, followed
by a parametric sensitivity analysis. In addition, the
effects of rock heterogeneities on the oil recovery and
asphaltene precipitation were investigated. A good match
with the oil recovery was obtained. Results indicated
that higher the degree of heterogeneities, the higher
is the asphaltene accumulation in the core. |
|
|
| 10797 |
Evaluation of light oil air injection process by combustion
tube tests |
24th Annual Workshop & Symposium Collaborative project
on Enhanced Oil Recovery International Energy Agency
2003/9/9 |
Katsumo Takabayashi (Japan National Oil Corporation) |
Research Division for Petroleum Engineering |
[Abstract] Light oil air injection (LOAI) is not a new concept
for improving oil recovery, as cheap and abundant air
is very attractive as an alternative to hydrocarbon and
carbon dioxide gases. In the LOAI process, bond scission
reactions play an important role in generating heat in
the reservoir. These reactions for light oils occur in
a lower temperature range in comparison bond scission
reactions for heavy oils. Furthermore, supercritical steam
effects and near-miscibility drive will be expected in
cases where the LOAI process is applied to deep, high
pressure, high temperature reservoirs.
A series of Accelerating Rate Calorimeter (ARC) test at
reservoir pressure and Thermo Gravimetric Pressurized
Differential Scanning Calorimeter (TG/PDSC) tests were
conducted on oil-rock systems from three light oil reservoirs
(Oils A, B and C). Combustion Tube (CT) tests were conducted
on two oils, a Japanese oil (Oil B) and a Middle East
oil (Oil C) at their respective reservoir pressures.
Results of the CT test with Oil C were presented at the
IEA workshop held in Caracas last year. In this paper,
the effect of exothermic reactions observed during the
ARC and TG/PDSC tests on the performance of CT tests with
both oils will be discussed.
Results from the ARC tests and TG/PDSC tests showed that
Oil C was favorable for autoignition and exothermic trends
due to its lower activation energy (Ea). In contrast,
Oil B didnft demonstrate favorable behavior for autoignition.
However, once ignited, Oil B should be capable of sustaining
combustion because of its strong exothermic response.
The CT tests were conducted with stock tank oil and crushed
formation rock materials at the condition of reservoir
pressure. The results of both oils displayed stable combustion
performance in terms of temperature and produced gas compositions.
The combustion front velocity of Oil B was faster than
that of Oil C. Total oil recovery of Oil B was higher
than Oil C. From the effluent profile, oil production
tends to depend on the stabilized combustion front velocity.
The behavior of the CT tests is characterized by the differences
in exothermic reactions observed in the ARC and TG/PDSC
tests. The CT performances were also successfully simulated
using a reservoir simulator by adjusting kinetics parameters
in the Arrhenius equations. |
|
|
| 10786 |
JNOC's GTL Process Development and Feasibility Study
with PERTAMINA |
The Twenty-ninth Annual IPA Convension (IPA=Indonesian
Petroleum Association)
2003/10/14-16 |
Yoshifumi Suehiro, Masaru Ihara, Kazuhito Katakura,
Akira Suzuki, Osamu Matsubara (Japan National Oil Corporation),
Takamasa Ohno, Toshiya Wakatsuki (Japan Petroleum Exploration
Co., Ltd.), Kenichi Kawazuishi, Mitsunori Shimura (Chiyoda
Co., Ltd.), Masahiro Yokoyama, Toshio Shimizu (Cosmo Oil
Co., Ltd.), Akira Uemura, Kenichiro Fujimoto (Nippon Steel
Co., Ltd.), Suhardiman, Kusmiyati, Satya A.Putra, J.H.Simamora,
Budiyono, Musalam L, A.H.Kusnadi, T.Suhartanto, Soewarto,
L.Nainggolan (Pertamina) |
Research Project Team for Emerging Gas Technologies |
[Abstract] Japan National Oil Corporation (JNOC) has been tackling
the technical research development of the natural gas
conversion technology from the year of 1998 till 2003
in collaboration with such five private companies as JAPEX,
CHIYODA, COSMO OIL, NIPPON STEEL and INPEX, in order to
aim at establishing the option technology to explore stranded
gas reserves.
The synthetic gas (Syngas) section of JNOCfs GTL process
applies the steam/CO2 reforming and the Fischer-Tropsche
(FT) section employs the slurry reactor with noble metal
or non-noble metal catalysts. Thus, JNOCfs GTL process
is found to get prominently effective as applied against
the natural gas reserves containing relatively high CO2.
JNOCfs GTL process is capable to utilize CO2 contained
in the natural gas and does not require any O2 supply.
Namely, the characteristics of JNOCfs GTL process in contrast
to those of the existing ones using Auto-thermal Reforming
(ATR) or Non-catalytic Partial Oxidation (POX) are (1)
no use of the O2 plant, (2) no use of the CO2 separation
unit, and (3) no use of the H2 conditioning unit.
Such facility savings will bring about the remarkable
reduction of the plant cost for its election and operation.
The optimal condition for the JNOCfs GTL will meet with
the plant scale of 15,000 BPD and the case of CO2 contents
being 20-40 mol% in the natural gas. The economic evaluation
does indicate that the JNOCfs GTL process is more economical
than the conventional ones when applied under those conditions
mentioned above.
Our challenges conducted until now have produced the promising
Syngas and FT catalysts and attained the efficient total
process.
This paper introduces the outline of the characteristics
of JNOCfs GTL process, the results of Syngas and FT catalysts,
process development, the economic evaluation emphasizing
Feasibility Study with Pertamina, and the operation results
of the Yufutsu GTL pilot plant in Japan. |
|
|
| 10785 |
A Mechanistic Heat Transfer Model for Vertical Two-Phase
Flow |
SPE Annual Technical Conference and Exhibition 2003
2003/10/6-8 |
Ryo Manabe (Japan National Oil Corporation), Qian Wang,
Hong-Quan Zhang, Cem Sarica, James P. Brill (University
of Tulsa) |
Research Division for Petroleum Engineering |
[Abstract] Convective heat transfer for vertical gas-liquid two-phase
flow was investigated experimentally and theoretically.
Experimental data on convective two-phase heat transfer
were acquired with a crude oil-natural gas system at cooling
conditions using a large diameter (2.067-in I.D.), high
pressure (450 psia) test facility. Flow pattern dependencies
of convective heat transfer with changing liquid and gas
velocities were revealed.
A comprehensive mechanistic heat transfer model was developed
by flow pattern dependent approach for bubbly, intermittent
and annular flow in vertical pipes. The model is capable
of predicting flow pattern first and then predicting hydrodynamics
and heat transfer based on the predicted flow-pattern.
Comparing with experimental data, the model is found to
predict two-phase flow heat transfer coefficient within
}26% error for all flow patterns showing a better overall
performance than existing correlations. |
|
|
| 10784 |
Effects of Pressure and Pipe Diameter on Gas-Liquid
Two-Phase Flow Behavior in Pipelines |
SPE Annual Technical Conference and Exhibition 2003
2003/10/6-8 |
Plat Abduvayt (Waseda University), Ryo Manabe (Japan
National Oil Corporation), Norio Arihara (Waseda University) |
Research Division for Petroleum Engineering |
[Abstract] The effects of pressure and pipe diameter on gas-liquid
two-phase flow behaviors were investigated experimentally
and theoretically for horizontal and slightly inclined
pipelines. Experimental data of flow pattern, pressure
drop and liquid holdup were acquired in the wide range
of the gas and liquid flow rates in a large diameter (106.4
mm) pipe for different pressures (592 and 2060 kPa) and
different inclination angles (0, 1, and 3). To evaluate
effects of the pipe diameter, our previous experimental
data of low pressure (490 kPa) and small diameter (54.9
mm), were also used. Based on analysis of the experimental
observations, a flow pattern map was developed for each
pressure, pipe diameter, and inclination.
Major phenomena identified in data analysis include: Pressure
and pipe diameter clearly affect the flow pattern transition
boundaries. The high pressure tends to shift the boundaries
to the lower side of superficial gas velocity in the flow
pattern maps. In the large-diameter-pipe experemints,
stratified flow was observed at higher superficial liquid
velocities than in small diameter. The gas flow rate and
inclination angle showed influences on liquid holdup and
pressure drop behavior. The average pressure did not show
large influences on liquid holdup and pressure drop.
Based on the experimental data, a mechanistic model was
developed incorporating transition criteria for eight
flow patterns, and individual flow models for estimating
liquid holdup and pressure drop. The results predicted
by the individual models demonstrated excellent agreements
with the experimental data for each pressure and each
inclination angle. |
|
|
| 10783 |
Integrated Geostatistical Reservoir Characterization
of Turbidite Sandstone Deposits in Chicontepec Basin,
Gulf of Mexico |
2003 SPE Annual Technical Conference and Exhibition
2003/10/6 |
Maghsood Abbaszadeh (Innovative Petrotech Solutions),
Osamu Takano, Hiroshi Yamamto (Japan Petroleum Exploration
Co.), Tatsuo Shimamoto (Teikoku Oil Corp.), Nintoku Yazawa
(Japan National Oil Corp.), Francisco Sandria, David Zamora,
Fernando Rodriguez (PEMEX Explorationy Production) |
Research Division for Petroleum Engineering |
[Abstract] This paper presents a pixel-based hierarchical geostatistical
modeling of submarine fan turbidite sandstone deposits
in Tajin and Agua Fria fields of Chicontepec basin in
the Gulf of Mexico. Methods are discussed for identifying
and dividing the stack of heterogeneous siliciclastic
sediments in these fields, using sequence stratigraphy,
petrophysical well log characteristics, geological facies
model and 3D seismic data.
An integrated multidisciplinary geostatistical reservoir
characterization is conducted in two main steps. First,
a large-scale reservoir framework of multiple sequence
and subsequence surfaces is constructed based on the integration
of data sources of geologic well markers, petrophysics,
and seismic horizons. Second, high-resolution 3D distributions
of reservoir properties are generated, accounting for
inherent inter-relationship among reservoir property data
and the three main data scales of log, sub-sequence layer
and sequence interval.
At onset, shale volume content in Tajin field and total
porosity in Agua Fria field are modeled. Block kriging,
trend model, and conditional thickness-weighted Bayesian
scheme are presented for the integration of data types
and data scales. Facies distributions in Tajin are modeled
by indicator kriging conditioned to Vsh, and hence to
seismic. Porosity distributions are by sGsim collocated
with Vsh for each facies group, and water saturation distributions
are collocated with porosity. In Agua Fria, effective
porosity and facies are by p-field related methods. Permeability
distributions are function of porosity, water saturation,
facies and sub-sequences. Patterns of sand continuity
and pay sand connectivity are derived and uncertainty
in their prediction is evaluated. |
|
|
| 10754 |
THE EVALUATION OF INSTALLATION OF DPS IN TANDEM OFFLOADING
FPSO |
International Conference on Marine Simulation and Ship
Maneuverability MARSIMf03
2003/8/25-28 |
Ikuo Yamamoto, Masami Matsuura (Mitsubishi Heavy Industries,
Ltd.), Hiroaki Hirayama, Yoshifumi Suehiro, Masaru Ihara
(Japan National Oil Corporation), Eiichi Kobayashi (Kobe
University of Mercantile Marine) |
Research Division for Petroleum Engineering |
| [Abstract] An integrated simulator to conduct a total simulation
of an offshore oil production system is developed based
on discrete event modeling technology. In the paper, an
overview of the developed simulator is described, and
it is shown that the evaluation of installation of DPS
in tandem offloading FPSO is successfully conducted and
specification of designing offshore oil production system
can be determined. Analysis of real offshore oil system
by the simulator is conducted, and its effectiveness is
confirmed. |
|
|
| 10753 |
Development of DPS for an FPSO and a shuttle tanker
by neural networks |
International Conference on Marine Simulation and Ship
Maneuverability MARSIMf03
2003/8/25-28 |
Eiichi Kobayashi (Kobe University of Mercantile Marine),
Masami Matsuura, Katuya Daigo, Ikuo Yamamoto (Mitsubishi
Heavy Industries, Ltd.), Hiroaki Hirayama, Masaru Ihara,
Yoshifumi Suehiro (Japan National Oil Corporation) |
Research Division for Petroleum Engineering |
| [Abstract] Recently, ocean oil field development is tending to
expand to deep sea and/or severe external force areas
in search of new petroleum resources. To maintain a high
operating rate for floating oil production systems, which
are promising in terms of deep-sea areas, it is important
to reduce the relative horizontal distance and hawser
tension between the FSPO and the shuttle tanker in tandem
offloading configurations even in severe sea conditions.
In this study, neural network control technology has been
developed, thus enabling reduction in hawser tension by
controlling the yaw angle of the FPSO. The control algorithm
has been confirmed to raise the wave height limit of work
from 3.5m to 4.5m through computer runs and model tests
in an experimental tank. |
|
|
| 10745 |
New process Development of Natural Gas into Liquid Fuels |
2003 JSAE/SAE International Spring Fuels & Lubricants
Meeting
2003/5/19-22 |
Shinichi Suzuki, Yoshifumi Suehiro, Masaru Ihara (Japan
National Oil Corporation), Toshiya Wakatsuki (Japan Petroleum
Exploration Co., Ltd.), Mitsunori Shimura (Chiyoda Co.,
Ltd.), Toshio Shimizu (Cosmo Oil Co., Ltd)., Kenichiro
Fujimoto (Nippon Steel Co., Ltd.), Atsushi Sakamoto (Inpex
Co., Ltd.) |
Research Project Team for Emerging Gas Technologies |
| [Abstract] Japan National Oil Corporation (JNOC) has been tackling
the technical research and development of natural gas
conversion technology since FY1998 in collaboration with
five Japanese private companies in order to aim at establishing
the option technology to explore stranded gas reserves.
The Syngas section of JNOC's GTL process applies the steam/CO2
reforming and the FT section employs the slurry reactor
with Ru- or Co- catalysts. JNOC's GTL process is capable
of utilizing CO2 contained in the natural gas and does
not require any O2 supply. Namely, the characteristics
of JNOC's GTL process in contrast to those of the existing
ones using ATR or POX are (1) no use of the O2 plant,
(2) no use of the CO2 separation unit, and (3) no use
of the H2 conditioning unit. Such facility savings will
bring about a remarkable reduction of the plant cost for
its election and operation. The optimal condition for
JNOC's GTL will meet the plant scale of 15,000 bbl/d and
the case of CO2 content being 20-40% in the natural gas.
The economic evaluation does indicate that JNOC's GTL
process is more economical than the conventional ones
when applied under those conditions mentioned above. |
|
|
| 10739 |
Development of Highly Durable Materials for Drilling
Hard and Abrasive Rocks |
2003 SPE Asia Pacific Oil & Gas Conference and Exhibition
2003/4/15 |
Yutaka Shioya (Japan National Oil Corporation) |
Research Division for Petroleum Engineering |
| |
|
|
| 10737 |
Origin and Migration of Methane in Gas Hydrate-Bearing
Sediments in the Nankai Trough: Implication for Subsurface
Occurrence of Nature Gas Hydrate |
AAPG (American Association of Petroleum Geologists)
2003
2003/5/14 |
Uchida Takashi (Japan National Oil Corporation), Amane
Waseda (Japan Petroleum Exploration Co., Ltd.) |
Research Project Team, Methane Hydrate |
| |
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