Table of Content

01 February 2014, Volume 36 Issue 1

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Reconstruction of Devonian Lithofacies Palaeogeography in
Hunan and Guangxi Provinces

Yang Huaiyu

2014, 36(1):  1-8.  DOI: 10.11885/j.issn.1674-5086.2013.01.09.02

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The regions of Hunan and Guangxi，which were in the composite position intersected by a variety of Tectonic system
in Devonian，and developed a unique“platform- depression-dome-basin”sedimentary system. Formation of Devonian were
eroded badly in Hunan and Guangxi Provinces，which merely remained in Nanpanjiang depression，Qianxinan depression，middle
and west of the Guizhong depression，Shiwanshan Basin and Xiangzhong depression. Researching on various sedimentary
facies symbol in residual formation，9 types of sedimentary facies were recognized，which dominated in the marine environment.
The followed conclusions were obtained from the difference comparison of sedimentary environment：Nanpanjiang
depression and Guizhong depression are mainly of depression-platform sedimentary system；Xiangzhong depression is mainly
of clastic tidal flat and restricted（open）platform sedimentary system，and Shiwanshan basin is mainly of undercompensation
basin. Sedimentary mode of study area was displays the feature“depression surrounded platform，depression connected”. Facies
differential degree of sedimentary evolution，the tectonic movement and magmatic activity have good sedimentary response
relation.

The Hydrocarbon Accumulation Conditions and Favorable Exploration
Direction of Chuanjiang Block of Hepu Basin

Gong Xiaofeng1，2, Yang Xibing3, Zhu Jitian3, Zhang Jingru1，2, Li Xiaotang1，2

2014, 36(1):  9-18.  DOI: 10.11885/j.issn.1674-5086.2013.03.25.01

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Strata found in Well Le2X in Hepu Basin are mainly off-white，variegated and purple-red，and dark mudstone is
thinner than others，only Jiuxikeng group of the Pliocene is thicker，but its bury is not deep，and belongs to prematurity stage.
The Chuanjiang fault block structural trap of Well Le2X is basically clear，but the traps is without basic hydrocarbon source
conditions and is away from the hydrocarbon source supply system，resulting in the fault block traps becoming empty traps，
which is the main reason for the failure drilling. Therefore，in-depth analysis of the low mature source rocks and hydrocarbon
source supply system，comprehensive prediction and delineation of favorable migration and accumulation of enriched zone
of low mature oil and gas and bio-gas within effective hydrocarbon source supply system，should be the key to oil and gas
exploration research in Hepu Basin.

Study on Interlayer Distribution of I Oil Group in Member 2 of
Zhujiang Formation in A Oilfield

Jiang Ping1，2, Huang Junhui3, Lei Xiao1, Cheng Chao3, Zhang Yongjun4

2014, 36(1):  19-26.  DOI: 10.11885/j.issn.1674-5086.2013.08.11.04

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The I Oil Group in Member 2 of Zhujiang Formation in A Oilfield is the main reservoir. It’s production status shows
that the type，sealing ability and spatial distribution of the interlayer severely affect the reservoir development effect. Through
analyzing the core observation，thin section identification and physical analysis，we consider there widely exist calcareous，
argillaceous and physical inter-layers. The calcareous interlayer most seriously affects the development. Because of the few
well numbers，sparse well network density and limited coring，we cannot study the spatial distribution of interlayer of the
whole district only by distinguishing intercalations from the core and logging. On the basis of finely dividing and correlating
layers，sedimentary microfacies，the research makes full use of horizontal section information，combines well and seismic，
unites geophysical information and successfully predicts the three-dimensional spatial distribution of interlayer by analyzing the
model，which is established due to the innovative application of seismic cooperative sequential Gauss simulation on sedimentary
facies tract conditions. The predicted results are agreed with the dynamic production，it provides a strong basis for oilfield
production and measures for tapping potential of remaining oil.

The Exploration Prospects of T2l1
1，Middle Triassic in
Northwestern Sichuan

Huang Dong1, Li Hongliang2, Jiang Jingping3, Shi Xuewen1, Wang Hua1

2014, 36(1):  27-32.  DOI: 10.11885/j.issn.1674-5086.2012.05.16.01

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Leikoupo Formation has a large amount of resources，but in addition to the previously found Wolonghe，Moxi gas
reservoir，no other reserve of scale has been found. With the progress of exploration of the marine strata in western Sichuan，especially
further degree of exploration，the T2l1
1 gradually exhibits its good exploration prospects. Based on Leikoupo Formation
determination，and according the field profile，debris samples，oil drilling and test data analysis，we think that the sub-section
of the T2l1
1 belongs to the reservoir controlled by shale facies which is similar or equivalent to Moxi and Wolonghe reservoirs.
Structural traps and fault development in the area are conducive to oil and gas migration and accumulation. Comprehensive
analysis reveals that the most favorable exploration zones are the Zhongba—Shuangyushi belt in the front north of Longmen
mountain and the Meishupu—Jiulongshan belt in the front of Micangshan mountain.

A Discussion on Distribution Pattern and Genesis of the Calcareous
Intercalation in Delta Front Reservoir

Yan Ke1，2, Zhao Hongbing1

2014, 36(1):  33-38.  DOI: 10.11885/j.issn.1674-5086.2012.05.16.02

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By using of core and close spacing log information，the lithologic features and log response features of the calcareous
intercalation in delta front reservoir of Shengtuo Oilfield were proposed systematically. on that basis，we recognize
the distribution pattern of calcareous intercalation in high-resolution sequence stratigraphic framework based on the accurate
strata correlation. The biogenesis mechanism was presented to improve the genetic model of calcareous intercalation. The
study shows that the distribution of calcareous intercalations has selectivity，which is always in the top of sandbody formed in
short-term downward base level cycle. The extension scale of calcareous intercalation in strata profile is not big，and always
transits to be muddy or silty depositional interface，which shows the calcareous intercalation as an approved sequence interface
or subdivision interface of composite sandbody in the delta front reservoir. The areal distribution of the calcareous intercalation
is correlated with the depositional microfacies，which is selectively located in the regional debouch bar near the subaqueous
distributary channel in a single depositional unit，and presented as separate lump shape. The intensive tulotomoides terrassa are
found in the calcareous intercalation，and the subsistence and aggregation patterns of tulotomoides terrassa coincided with the
selective distribution pattern of calcareous intercalation，which indicates the biogenesis mechanism.

Formation，Recognition and Analysis of Low-resistivity Annulus

Liao Dongliang1，2

2014, 36(1):  39-44.  DOI: 10.11885/j.issn.1674-5086.2012.07.04.01

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The low-resistivity annulus is the strong evidence of available oil and gas，and the effective means of judgement of
oil and gas layer，especially the low resistivity oil and gas layer. Based on the flow equations of oil and water two phases，the
seepage driving velocity is derived during mud filtrate invaded formation，and the process of forming low-resistivity annulus
was analyzed. The high frequency induction log can get five resistivity curves at one time. From the reaction of the curves，we
can see there are three manifestations for low-resistivity annulus and they are R07 the lowest，R10 the lowest，R11 the lowest，
respectively. The paper analyzed the formation process of low-resistivity annulus and reservoir characteristics through the three
manifestations. Some examples of the three manifestations of low-resistivity annulus and the process result from high frequency
induction log were presented，the results shows that we can quickly tell the reservoir is oil layer，water layer or oil-water layer.

Study on Longmaxi Formation Bottom Boundary in Sichuan Basin

Wang Xingzhi1, Li Yizhen1, Du Yang1，2, Hu Yang2, Li Ye1

2014, 36(1):  45-50.  DOI: 10.11885/j.issn.1674-5086.2013.11.20.04

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In order to solve the partitioning problem on the bottom boundary of lower Silurian Longmaxi Formation，based
on previous researches，with the macroscopic and microscopic observation of outcrops and drilling cores and the analysis of
well logging，mineralogical and geochemical data in Sichuan Basin and its peripheral areas，the differences between Longmaxi
and Wufeng Formation show that there are higher limy content，many brachiopods，low GR and high RT logging values，high
calcite content and lower TOC values in the top of Wufeng Formation，while the bottom of Longmaxi Formation have none
limy content，none brachiopods and abundant graptolites，high GR and low RT logging values，high clay and quartz content，
highest TOC values. The study suggested that the detection of limy content and comparison of log are the fast and accurate
methods of demarcating Longmaxi Formation bottom boundary in practical operation，and it can provide some theoretical basis
for furthermore shale gas exploration in Longmaxi Formation of Sichuan Basin.

Study on Characteristic of the Sand Bodies of Huangliu Formation in DF13
Area，Yinggehai Basin

Chen Zhihong1，2, Chen Dianyuan2, Ying Mingxiong2

2014, 36(1):  51-57.  DOI: 10.11885/j.issn.1674-5086.2013.04.23.02

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The massive fine-grained sandstone developed from the thick mudstone lager powder of late Miocene deposits in
shallow yellow stream group in Yingge Sea Basin is the recent gas exploration hotspot. The reservoir is sand vertically stacked
multi-stage，and changes fast horizontally. Though tectonic evolution and ancient deposition setting control the distribution and
evolution of third-order sequences framework within Huangliu Formation，they do not control the distribution of depositional
systems or reservoir sand bodies. Compared with the classic submarine fan phase，typical deposition characteristics can hardly
be found in this depositional system like obvious fan body sub-phase differentiation，main waterway，levee，etc. It is considered
as a channel sand bodies’ combination of small-scale，fast migration，and thick accumulation. In the article，it is called
non-typical Turbidity current，using different channels + spring current to show this sedimentary characteristic. The studies
suggest that the unstable continental slope setting controls the distribution of sand bodies in four-order sequences by means of
controlling the Palaeogeomorphology and sedimentary source rechargement. According to the hydrodynamic characteristics
and accumulation styles of the channel deposition，the sand bodies are further divided into the sub-erosion channel，migration
channel and filling structure. Among them sub-erosion channel and filling structure have good reservoir conditions，that can
be new gainful exploration targets.

Discission of Oil Shale In-situ Conversion Process in China

Li Jun1，2, Tang Dazhen1, Xue Huaqing3，4, Zheng Dewen3，4, Du Dong2

2014, 36(1):  58-64.  DOI: 10.11885/j.issn.1674-5086.2012.07.25.02

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The oil shale resources，which buried in 500～1 500 m，are about 6 813×108 t tones in China. The in-situ conversion
process（ICP）is still in its infancy in China and were preliminary studied by oil shale pyrolysis，micropores and permeability
experiments in different temperature. The oil shale pyrolysis is classified as 3 stages：dehydration，pyrolysis and mineral
decomposition. During these stages，the physical and chemical reaction occurred in different，micropores and permeability of
oil shale were evolved in different extent，of which the major changed is pyrolysis stage. We studied the temperature distribution
of ICP with the unsteady mathematical model. It shows that the shale oil productions can begin after 5 years heating，the duration
of productions maintains at least 2 years.

Uncertainty Analysis with the Response-surface Proxy for Stochastic
Geological Models

Sun Lichun, Guo Lina, He Juan, Wu Mengyang, Ni Jun′e

2014, 36(1):  65-73.  DOI: 10.11885/j.issn.1674-5086.2013.08.11.06

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To solve the difficulty problems，which the stochastic geological model is uncertain，the paper presented the
response-surface proxy model to carried out the uncertainties method and its research process. The uncertainties with the
geomodel can’t be easily and correctly disclosed with respect to the process of the stochastically modeling that is limited by
computer’s capacity and time consumption. In the whole process，some following crucial things should be considered seriously.
All uncertainties with the geomodeling should be fully taken into account in compliance with the geological characteristics
of reservoirs. Sensitivity analysis would be carried out prior to the generating of proxy model. The sampling algorithms for
generating both the training and the validation models could be different from the predicating of the target through proxy model.
The probabilistic distribution of the target variables（oil in place as an example）can be understood through proxy model to a
great extent. Therefore，these stochastic geomodels can be picked out with respect to the probabilities in terms of the target. In
this sense，risks and potentials for the development of a reservoir can be appraised further based on the uncertainty studies.

CFD Simulation of Proppant Transportation and Settling in Water
Fracture Treatments

Zhang Tao1, Guo Jianchun1, Liu Wei2

2014, 36(1):  74-82.  DOI: 10.11885/j.issn.1674-5086.2013.11.07.06

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Water hydraulic fracture treatments are widely used in of exploitation for tight gas reservoirs such as shale gas because
of its low cost and little damage to formation′s permeability. In the process of fracturing，turbulence effects，particle-particle and
particle-wall interactions are important factors which affect proppant transportation and settling behavior. Because conventional
proppant settlement calculation methods don′t consider the two-way coupling of fluid-solid and solid-solid，Euler-Euler twophase
flow model is established to study the proppant transportation and settling behavior in the process of water-fracturing.
Turbulence effects and friction stress between high concentration particles are taken into consideration to study the particlewall
interaction，and Johnson-Jackson boundary conditions are also considered. By using this model，the two-phase flow of
fracturing fluid and proppant in the slot under different inlet-velocity position，particle density are studied. The simulation
results coincide with experimental results well，which verifies the effectiveness of the model used. In the meanwhile，the effect
of these parameters to proppant transportation and settling law is also discussed in the paper.

Establishment of the Chart of Equivalent Gas Ratio-Recovery Degree for
CO2 Miscible Flooding

Sun Lei1, Feng Qiao1, Chen Guoli2, Zhang Hua2, Jin Meiyu3

2014, 36(1):  83-88.  DOI: 10.11885/j.issn.1674-5086.2013.10.14.06

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Because the dynamic evaluation methods of CO2 miscible drive is not enough comprehensive and systematic，and
also the improved water flooding chart is not suitable for the evaluation of the CO2 miscible drive，we first define the type A
gas flooding characteristic curve. Then on the basis of it，we have derived the relational expression between the equivalent gas
rate and recovery degree，and draw the calibration chart. We use this chart to predict the biggest increased recovery of Y block
after injecting CO2，and by comparing with the scene results，we find that two of them are consistent. So the results that the
chart is a good predictor of the biggest increased recovery after injecting CO2. In general，this method is more significant for
the block’s further development.

New Calculation Methods of Injection-production Ratio for
Water-injecting Development Stage in Closed Reservoirs

Jia Yinglan1，2, Jia Yonglu1, Zhou Xia3, Jing Yang4, Nie Renshi1

2014, 36(1):  89-94.  DOI: 10.11885/j.issn.1674-5086.2013.06.30.01

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At present，the calculation methods of stage injection-production ratio only considered a single factor，such as
formation pressure or water cut；however，the stage injection-production ratio is controlled by many factors，such as formation
pressure，water cut and cumulative water-oil production ratio in real development. To solve the problem，we derived the
relationship formulation of stage injection-production ratio with cumulative oil production，formation pressure and water cut
using the semi-logarithmical curve of cumulative water injection with cumulative oil production，combining the material balance
equation of closed reservoir. Then two calculation formulations of stage injection-production ratio were further derived using
the relationship formulation of cumulative oil production with water saturation and the two relationship formulations of relative
permeability with water saturation. At the end，calculations of stage injection-production ratio using the above two calculation
formulations for an example closed reservoir with water-injection development history showed that the new calculation methods
are applicable and useful.

Study on Mathematical Model and Method of Solving of Pipeline-reservoir
Coupled System

Lin Chunyang1，2, Zhang Xiansong1，2, Gong Bin3, Liu Huiqing4

2014, 36(1):  95-100.  DOI: 10.11885/j.issn.1674-5086.2012.03.12.01

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The pipe flow and reservoir fluid form a coupled system. Therefore，a mathematical model is proposed，which
is capable of solving pipeline flow system and reservoir fluidity system. In pipeline system，Drift-flux model has been used
to elucidate multiphases flow process with consideration of the influence of viscosity increasing of polymer solution. And
Darcy laws have been used to describe reservoir fluidity system. On the basis of that，the decoupled solution has been given，
the decoupled calculation has been completed by exchanging boundary conditions（wellbore pressure，multiphases flux and
polymer concentration on perforations）. As a result，the convergence difficulties of coupled solution have been improved
effectively. And the validity is verified by using business software. Results indicate that Drift-flux model can be effectively
used to study the multiphases flow in pipeline with polymer solution；and the decoupled solution can efficiently solve the
coupled flow process of pipeline and reservoir. Compared with the coupled solution，error is less than 5%. And the computing
speed is 10 to 100 times of the coupled solution.

Study on Interlayer Interference Caused by Commingling Production
and Development Strategy in Sandstone Reservoir

Yu Huajie, Zhu Guojin, Tan Xianhong

2014, 36(1):  101-106.  DOI: 10.11885/j.issn.1674-5086.2012.06.06.01

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There are several vertical reservoirs in A Oilfield，and the greatly different reservoir physical properties，different
fluid properties，and the disperse reserves. Because of these factors，in the cause of commingling water injection or commingling
oil production，some problems caused by reservoir heterogeneity will gradually arise，which include serious injected water
breaking through in single layer，quick increase of water cut，different reserves producing，unequal oil recovery and lower
reservoir oil recovery. So how to improve the recovery is very important in the vertically heterogeneous reservoir. This paper
uses numerical simulation technology to conduct the single and composite factor sensitivity analysis under the condition of
commingling production by A oil field homogeneous model，and reservoir production characteristics，development evaluation
and development index are compared in different development method by the actually heterogeneous model. In the end，we
recommend technology development program practical in Oilfield，and put forward Oilfield development technology strategy
and measures.

Experimental Study of Residual Gas Saturation at DH Gas Reservoir

Li Jiudi1, Hu Ke2

2014, 36(1):  107-112.  DOI: 10.11885/j.issn.1674-5086.2013.08.29.04

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servoir is at the middle-later period of exploitation，calibrating and improving the recovery of the waterdriven
sandstone gas reservoir and adjusting the development plan are very important. Before this，studying the residual gas
can provide an accurate parameter for recovery calibration work. Adopting the co-current spontaneous imbibition experimental
facility we tested the residual gas saturations of the sandstone samples from DH gas reservoir. The results revealed that initial gas
saturation had an important effect on residual gas saturation，and porosity and permeability had a little influence on maximum
residual gas saturation. The experimental results could coincide with Land’s model very well，but not with the Agrawal’s
model. Based on the initial gas saturation of DH gas reservoir to the formula we calculated the residual gas saturation of DH gas
reservoir. And by using the result of residual gas saturation we analyze the countermeasure of enhancing nature gas recovery
of DH gas reservoir in the future.

Study on the Movable Fluid Saturation and its Influencing Factors of
Low Permeability Volcanic Gas Reservoir

Liao Zuocai1，2, Sun Junchang3, Yang Zhengming2，3, Xiong Shengchun3, He Ying3

2014, 36(1):  113-120.  DOI: 10.11885/j.issn.1674-5086.2012.02.16.02

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In view of the factors that the diagenetic mechanism of volcanic reservoir is different from the conventional depositional
sandstone reservoir，the micro-pore structure of the volcanic is more complex than that of sandstone reservoir. The movable
fluid saturation of Xushen，Changling and Dixi volcanic gas reservoirs were systematically studied by using the centrifugal
experiment，NMR，constant-rate mercury injection and CT technology. The experimental results indicate that the suitable centrifugal
force used to obtaining the irreducible water saturation in centrifugal experiment is 2.76 MPa. The micro-distribution
feature of the movable fluid corresponding to different permeability reservoir is different. The larger the permeability，the
greater the proportion of the movable fluid controlled by the larger throat. 0.100 mD is one of the critical permeability values
when the reservoir permeability larger or less than it，the micro-distribution feature of the movable fluid is different. The average
of the movable fluid saturation of the three gas reservoir is 23.62%. The CT image and constant-rate mercury injection
experimental results suggested that the reservoir fracture and pore-to-throat ratio are the main factors affecting the movable
fluid saturation.

Application Research of Fiber Fracturing Technology at Sulige Gas Field

Ren Bin1, Liu Guoliang1, Zhang Mian1, Chi Xiaoming1, Luo Mingliang2

2014, 36(1):  121-128.  DOI: 10.11885/j.issn.1674-5086.2013.04.02.03

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To solve the problem of proppant backflow during the flowback progress in fracturing at Sulige gas field，a kind
of fracturing fiber was prepared. The suitable size and adding concentration in fracturing fluid were also determined in this
paper. By simulating the model of enforced crack closure and the model of proppant sinking rate，we developed the optimization
software of fibers anti-backflow of proppant，which could give useful messages for flowback of fracturing fluid and for
controlling the proppant backflow. The testing results of fiber-added fracturing and controlled discharge show that the prepared
fibers meet the need of anti-backflow of proppant in Sulige area. The use of fracturing fibers not only decreased the backflow
but also increased rate of drain blowout；moreover，it also reduced the damage chance of needle valve and gate valve during
the flowback.

Correction Method for the Dead Volume of Core Exit End Pipeline in
Heavy Oil Relative Permeability Experiment

Gao Wanglai1, Shen Dehuang2, Li Fangfang1

2014, 36(1):  129-133.  DOI: 10.11885/j.issn.1674-5086.2012.05.02.01

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The heavy oil relative permeability curve is an important parameter in heavy oil reservoir performance prediction.
The error in the relative permeability test caused by experimental factors will result in wrong information for reservoir development
analysis. Due to the long exit end pipeline and more dead volume in the high temperature relative permeability test，the
oil-water phases flowing law in the exit end pipeline of core holder and method of dead volume calibration will have important
effect on relative permeability experimental results. The phenomenon of non-piston like displacement and pressure hysteresis
effect have been discovered based on the water flooding experiment of heavy oil in the exit end pipeline. The breakthrough
recovery and ultimate recovery factor decrease with increasing oil viscosity and water drive velocity，and the metering oil volume
is behind the data corresponding to the pressure. The conventional data correction by oil volume deducting space volume
of pipeline may lead to the deviation of experimental results from the actual flow behavior，so a new method of data calibration
is proposed.

Study on the Effect of Solid Particle on Water-flooding Development in
Low Permeability Sandstone Reservoir

Wu Jiazhong1, Meng Hongli2, Xu Jie3, Xie Quan1, Shi Leiting2

2014, 36(1):  134-138.  DOI: 10.11885/j.issn.1674-5086.2013.05.27.01

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The solid particles in the injecting water directly affect injection pressure and the degree of formation damage in
low permeability sandstone reservoir. The paper studied the injection of three different sizes of solid particle，whose D90（the
cumulative particle size distribution of solid particle in the injecting water exceeds 90%）is 1.24，5.05，9.91µm. and we studied
three kinds of injectivity water for the degrees of damage on oil phase permeability，and investigate the impact on the recovery.
The results show there are problems on injectivity in core of permeability less than 1 mD when particle size，D90，is larger than
1 µm. However，when the permeability of core is larger than 1 mD，the problem goes away. As D90 increases，the degrees
of oil permeability damage increases and the water flooding recovery reduces. As the permeability grows，the solid particle of
larger particle size plugs the flowing channel in small and medium-sized pores，reducing water-flood sweeping ability. Seen
from chart of permeability damage，when the core permeability is greater than 10 mD，the particle size，D90，can be 5 µm.

Experimental Study on Factors Affecting the Effect of Barium Sulfate
Scale Inhibition

Li Hongjian1, Meng Xue1, Li Ran1, Tang Xin2, Wang Deyu2

2014, 36(1):  139-144.  DOI: 10.11885/j.issn.1674-5086.2013.06.23.01

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In order to study the factors that affect the effect of barium sulfate scale inhibition，three kinds of scale inhibitors
named ZX–101，TH–1 and TH–607B that resistance barium sulfate（strontium sulfate）were screened out to make experiments
of temperature，salinity，concentration of Ba2+ and SO2-4 impact on barium sulfate separately by static scale inhibition method.
The results show that these three inhibitors have shown great performance for barium sulfate scale，they can prevent scaling
of barium sulfate effectively. Their inhibition efficiency first increase and then decrease with the increasment of temperature
and salinity，and when the inhibitor concentration increases the inhibition efficiency increases. When the temperature is 65 ℃，
SO2-4 concentration is 0.55 g/L，salinity is 73 g/L，inhibitor concentration is 0.1 g/L and the concentration of Ba2+ increases from
0.64 g/L to 1.28 g/L，these three kinds of scale inhibition efficiency gradually decrease，respectively from 96.55%，97.65%，
98.04% down to 82.80%，87.83%，84.49%. While Ba2+ concentration is 0.8 g/L，inhibitor concentration is 0.08g/L and the
concentration of SO2-4 increases from 0.10 g/L to 0.60 g/L，their inhibition efficiency increase from 90.64%，96.49%，93.57%
to 99.79%，99.28%，99.79%，and then begin to decline，eventually drop to 93.72%，91.09%，80.06%.

Influence of Heavy Components on the Heavy Oil Emulsion Stability

Lai Nanjun1，2, Peng Qin1, Ye Zhongbin1，2, Song Xiaohui1, Wen Yiping1

2014, 36(1):  145-149.  DOI: 10.11885/j.issn.1674-5086.2013.07.03.02

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The heavy components of heavy oil have a great influence on the stability of emulsion. In this paper，taking heavy
oil of a Xinjiang reservoir as an example，we assayed its basic properties such as density，viscosity，solidifyig point and acid
value. After separated heavy oil into saturates aromatics，resins and asphaltenes by polarity separation，we tested the basic
properties and element content of the four components，Asphaltenes can stabilize the interfacial film of emulsion，and the water
extraction is at the minimum and stability of emulsion is at maximum when the asphaltene content is 0.5% and resin content
is 4.0%. The small amplitude oscillation experiment tests on simulation oil emulsion interfacial rheological behavior revealed
that in the resin/asphaltene model oil emulsion，complex modulus（E∗）increases first increased and then decreased with the
passage of time. When the asphaltene content is 0.5%，the resin content is 4.0%，after 2 000 s the complex modulus（E∗）is at
the maximum and the emulsion is stable.

Study on Erosion Mechanism of Bending Joint in Blooey Line

Lian Zhanghua1, Chen Xinhai1, Lin Tiejun1, Ming Xin1, Zheng Jianxiang1，2

2014, 36(1):  150-156.  DOI: 10.11885/j.issn.1674-5086.2013.08.11.03

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Blooey line is the one of indispensable ground equipment in gas drilling，which has potential safety hazard in high
pressure and high yield gas well drilling，but it is usually ignored in common. Because of solid particle erosion in high speed
air flow，failure destruction of blooey line occurs mainly in bending joint. Based on erosion destruction of bending joint，we
launch the study of erosion destruction mechanism and mathematical model，and carry on the theory discussion on erosion
angle of attack，erosion function，erosion coefficient of particle shape and the stress of the solid particle. At the same time，
this paper established the CFD finite element model and the angle of bending joint can change arbitrarily，which quantitatively
simulates erosion rate of multiphase flow containing solid particles to blooey line bending joint under different conditions and
do erosion mechanism research，and there is a series of CFD simulation study under the limitation flow rate（100×104 m3/d
and 50×104 m3/d）in different sand content. Finally，obtained quantitative relation curves between erosion rate and the angle
of joint，it provides the theoretical basis for the blooey line bending joint structure optimization in this paper.

Application Research on A New Technology of Shifting Sleeves

Shi Lei

2014, 36(1):  157-162.  DOI: 10.11885/j.issn.1674-5086.2013.09.11.01

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With the rapid development of horizontal well drilling technology，the staged reservoir stimulation technology and
supporting tools of horizontal wells has become increasingly popular. As a component of the staged reservoir stimulation tool
to communicating reservoir and wellbore，shiftable sliding sleeves are used to stimulate reservoir and to improve oil，gas and
water management throughout the life of the well. Because of the large shifting force and extended reach required to operate
sliding sleeves in horizontals，the coiled tubing（CT）is typically used for sleeve management. But there is some uncertainty to
ensure sleeve shifted successfully by observing the change of surface load and there is a possibility of misuse. At the same time，
this method can’t determine the sleeve position，so if the operation is not fully in place，CT operation was needed again. To
solve this problem，this paper introduces a new shifting tool which is connected by CT with fiber. This tool can shifting sleeve
by locating sleeve position precisely and monitoring string load，pressure and temperature in the downhole；by processing and
interpreting the measurement data on the ground，the operators can judge the situation downhole accurately and switch sleeves
reliably. It also can determine sleeve position by the change of CCL curve to save a lot of cost and time caused by operational
errors.

Deformation Calculation and Technical Measure to the Pipe String of
Ultra-deep Open Hole Separate Zone Water Injection in Tahe Oilfield

Wang Shijie1, Yang Zhi2, Zhao Jinzhou2, Wang Lei3, Zhang Jianjun3

2014, 36(1):  163-169.  DOI: 10.11885/j.issn.1674-5086.2013.04.15.02

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The particularity of the deep separate flood layer，the formation high temperature and the open hole completion in
Tahe Oilfield’s Ordovician carbonate reservoir，the failure of open hole packer K341 in pre-injection test well cause the injection
test failure. To analyze the reasons for the failure，the paper established the mechanical model of the ultra-deep pipe string of
separate zone water injection and calculated the K341’s creeping quantitative relative to the casing packer with hydraulic anchor
in different working conditions of the injection test pipe string and under the combined action of the mechanical effects. The
results show that the K341 will produce 0.3∼0.6 m creep variable when the Y241 packer is in the process of setting after the
K431 packer is worked and this directly causes the damage of the K341 packer. To solve the problem，we draw up the creep
preventing technical measure of the ultra-deep open hole separate zone water injection pipe string and optimize structure of
injection string. That is installation of bumper sub，optimization structure of packer K341 to keep the working pressure with
packer Y241，installation of centralizers at both end of packer K341 to protect element when down to the wellbore.

Feasibility Study on Non-repeating Acquired Time-lapse
Seismic Reservoir Monitoring

Yin Cheng1, Ge Zijian1, Rui Yongjun2, Zhao Shengtian2, Cui Qinghui2

2014, 36(1):  170-180.  DOI: 10.11885/j.issn.1674-5086.2013.10.28.01

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To study the feasibility of non-repeating acquired time-lapse seismic reservoir monitoring，this paper uses 3-D
Gaussian ray-beam forward simulation to simulate and analyze illumination of reservoir，quantifies the impact of different
geometry parameters on bin-received energy of reservoir，and finds that the main factors affecting the magnitude and uniformity
of bin-received energy of reservoir are distribution of offset and azimuth，namely the magnitude of max-offset and the number
of receiver-line. When velocity variation of reservoir has less effect than geometry parameters variation on the magnitude of
cell-received energy，it is more necessary to conduct the conforming matching for geometry of time-lapse seismic datasets. The
key point in this step should be rebinning and matching of distribution of offset and azimuth in bins. It has proved to be able to
efficiently reduce the seismic respond deviation in non-reservoir and amplify it in reservoir by geometry-matching for a set of
non-repeating acquired real data from block S56.