ISSN 0207-2351
Scientific-technical
journal
OILFIELD ENGINEERING
published
since 1965
April
2020
¹
4 (616)
12 issues per year
CONTENÒS
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DEVELOPMENT OF OIL
AND GAS-OIL FIELDS
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Ponomareva
I.N., Galkin V.I. Application
of a multilevel statistical modeling for evaluating the interaction between
injection and production wells (p. 6‑9)
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Alekina E.V.,
Olkhovskaya V.A., Ovchinnikov K.A. Substantiation of the efficiency of using carbon dioxide
in the supercritical state for high-viscous oil production by the thermodynamic
modeling data (p. 10‑16)
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METHODS OF PRODUCING
EFFECT ON A DEPOSIT AND RAISING OIL RECOVERY
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Zinoviev A.M.,
Ptichkin P.A., Kotlyarov S.O., Gavryushin A.S. Geological-technological substantiation for conducting
hydraulic fracturing of a formation in production wells (p. 17‑22)
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Ganiev Sh.R.,
Lysenkov A.V., Mikhailov A.L. Complications arising due to hydrochloric acid effects on carbonate
rocks and their elimination (p. 23‑26)
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RESEARCH OF FORMATIONS
AND WELLS
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Gribennikov
O.A., Melnikov A.A. Monitoring
of reservoir characteristics by the data of bringing on the well to stable
production (p. 27‑31)
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Shakshin V.P.,
Mokrev A.A., Kapustin A.I. Approbation
of the compositional hydraulic "engine" (on the example of one
deposit in Siberia) (p. 32‑36)
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Iktisanov V.À., Yartiev À.F. Determination of optimal number of wells for rate
transient analysis from economic point of view (p. 37‑40)
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TECHNIQUE AND
TECHNOLOGY OF OIL PRODUCTION
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Kharitonov
A.N., Pospelova T.A., Loznyuk O.A., Arkhipov Yu.A., Skorobogach M.A., Yushkov
A.Yu., Strekalov A.V., Zavorina A.S., Pavlov V.P., Nazarov A.L. Procedure for justifying process
conditions of gas and gas condensate wells using integrated models (p. 41‑47)
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Grishagin
A.V., Kashaev D.V., Gladunov O.V. Some specific features of scenario conditions formation for technical-economic
estimates when comparing oilfield separation equipment of different types (p. 48‑53)
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Isaev A.A.,
Malykhin V.I., Sharifullin A.A. Experimental studies of oil viscosity in field conditions to assess
the error of the measurement when using hoppler viscosity gage (p. 54‑59)
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Ulyanova Z.V.,
Kulyshev Yu.A. The
necessity and possibilities of control of cation polymers content in the
flushing fluid during drilling (p. 60‑63)
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PREVENTION OF
PARAFFIN SEDIMENTATION, SALTS AND HIDRATES
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Nikulin V.Yu.,
Zeigman Yu.V. Increase of
the temperature forecast accuracy along the wellbore with account of the
products movement and degassing specific features (p. 64‑68)
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Information
on the articles
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UDC
622.276.43.004.58 DOI:
10.30713/0207-2351-2020-4(616)-6-9
APPLICATION OF A MULTILEVEL STATISTICAL MODELING
FOR EVALUATING
THE INTERACTION BETWEEN INJECTION AND PRODUCTION WELLS (p. 6)
Inna Nikolaevna Ponomareva, Cand. of tech. sci.,
Vladislav Ignatievich Galkin, Dr. of geol.-mineral. sci.
Perm National Research Polytechnic University
29, Komsomolsky prosp., Perm, 614990, Russian
Federation,
e-mail: PonomarevaIN@pstu.ru
The quantitative estimation of the interaction
between production and injection wells is the most important task of
effective monitoring of oil fields development. The widespread use of one of
the most reliable methods for solving this problem, namely, tracer studies,
is difficult due to economic reasons. However, the experience of conducting
tracer studies allows studying and improving indirect methods for assessing
the interaction among wells. This paper presents the results of studies on
the development of a methodology for assessing the interaction among
production and injection wells of the Tournaisian-Fammenian deposit of the
Gagarinskoye field, where large-scale tracer studies were conducted. It is
established that the techniques based on the correlation of flow rate and
injectivity provide no reliable solution of the set problem. This fact caused
the necessity of developing a technique based on a multi-level statistical
analysis of the accumulated injection and fluid production. Comparison of the
results of applying this technique with the materials of tracer studies
confirms its high reliability when assessing the distribution of injection
volumes if the reservoir pressure maintenance system is fully formed.
Keywords: monitoring
of oil field development; reservoir pressure maintenance system; injection
distribution; interaction between production and injection wells; tracer studies;
methods for assessing the distribution of injection volumes; correlation;
multi-level statistical modeling.
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UDC
622.276.41 DOI:
10.30713/0207-2351-2020-4(616)-10-16
SUBSTANTIATION OF THE EFFICIENCY OF USING CARBON
DIOXIDE IN THE SUPERCRITICAL STATE FOR HIGH-VISCOUS OIL PRODUCTION BY THE
THERMODYNAMIC MODELING DATA (p. 10)
Elena Viktorovna Alekina,
Valeriya Aleksandrovna
Olkhovskaya, Cand. of tech. sci.,
Kirill Aleksandrovich
Ovchinnikov, Cand. of chem. sci.
Samara State Technical University
244, Molodogvardeyskaya str., Samara, 443100,
Russian Federation,
e-mail: alekina-samgtu@mail.ru;
valeriaolh@mail.ru; ovchinnikov.ka@samgtu.ru
The paper investigates the mechanism of exposure
of carbon dioxide CO2 in a supercritical state on an oil
reservoir. The results of modeling the thermodynamic behavior of the carbon
dioxide – high viscosity oil under varying thermobaric conditions are
presented. The presence of three phases in the reservoir was diagnosed: oil
in CO2 – vapor phase; CO2 dissolved in oil – heavy
liquid phase; mutually dissolved CO2 and oil – light liquid phase.
The exothermic effect when mixing carbon dioxide and oil in the near-critical
and critical areas of pure CO2 is revealed. The dependence of the
studied oil viscosity on the carbon dioxide content in was obtained and their
optimal ratio was determined when CO2 injection into the well
bottom zone of the producing well will increase the mobility of the oil in
the radius of processing and its flow rate.
Keywords: high viscosity oil; carbon dioxide;
supercritical state; thermobaric conditions; phase transition; flow rate
increase.
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UDC 622.276.66 ÊÃ DOI:
10.30713/0207-2351-2020-4(616)-17-22
GEOLOGICAL-TECHNOLOGICAL SUBSTANTIATION FOR
CONDUCTING HYDRAULIC FRACTURING
OF A FORMATION IN PRODUCTION WELLS (p. 17)
Alexey Mikhailovich Zinoviev, Cand. of tech. sci.,
Pavel Anatolievich Ptichkin,
Sergey Olegovich Kotlyarov,
Alexander Sergeevich Gavryushin
Samara State Technical University
244, Molodogvardeyskaya str., Samara, 443100,
Russian Federation,
e-mail: lekso1988@yandex.ru; ptichkin.pa@mail.ru;
serega.notell@gmail.com; gavryushinAS@gmail.com
The paper presents a geological-technological
substantiation of using acid hydraulic fracturing of a formation (AHFF) for
the production fund of oil fields as well as the prospects of its conducting
in producing wells. The experience of carrying out an acid hydraulic
fracturing of a formation in the oil fields of Russia is considered. The ways
of improving the technology of acid hydraulic fracturing of a formation for
low-permeability and weakly drained carbonate reservoirs are studied. The
main criteria for selecting wells for hydraulic fracturing are highlighted.
To achieve this goal and solve the set problems,
theoretical and empirical research methods were used.
Keywords: acid
hydraulic fracturing of a formation; enhancement of oil recovery;
geological-technical measures; proppant; permeability; reservoir.
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UDC
622.276.63 DOI:
10.30713/0207-2351-2020-4(616)-23-26
COMPLICATIONS ARISING DUE TO HYDROCHLORIC ACID
EFFECTS ON CARBONATE ROCKS
AND THEIR ELIMINATION (p. 23)
Shamil Ramilevich Ganiev,
Alexey Vladimirovich Lysenkov, Cand. of tech. sci.,
Alexey Leonidovich Mikhailov
Ufa State Petroleum Technology University
1, Kosmonavtov str., Ufa, 450064, Republic of
Bashkortostan, Russian Federation,
e-mail: ganiev.shml@rambler.ru;
rusoil.aleksey@mail.ru; alexsij_mixajlov_95@bk.ru
It is known that the main method of oil
production enhancement from the carbonate reservoirs of the Republic of
Bashkortostan is hydrochloric acid treatment (HCAT) of wells. When conducting
hydrochloric acid treatment (HCAT) of wells, there occur various
complications. Moreover, complications arise comprehensively, worsening the
effectiveness of treatments and decreasing the intensity of oil reservoirs
development. In this regard, it is necessary to search for the methods that
will prevent the arising complications. The paper discusses the complications
of technological and geological nature that occur during the hydrochloric
acid treatment of wells in the fields of the Republic of Bashkortostan, the
causes of their occurrence and analyzes the main methods and ways of
preventing complications.
Keywords: carbonate
rocks; hydrochloric acid treatment; well; oil; complications.
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UDC
622.276.2.001.57 DOI:
10.30713/0207-2351-2020-4(616)-27-31
MONITORING OF RESERVOIR CHARACTERISTICS BY THE
DATA OF BRINGING ON THE WELL
TO STABLE PRODUCTION (p. 27)
Oleg Alekseevich Gribennikov, Cand. of tech. sci.,
Arseny Alekseevich Melnikov
Samara State Technical University
244,
Molodogvardeyskaya str., Samara, 443100, Russian Federation,
e-mail: gribennikov.oa@samgtu.ru
The article presents an additional research tool
that allows getting reservoir filtration characteristics. A mathematical
model is briefly presented, on the basis of which the least squares method is
applied to obtain and interpret output data of bringing the well on to stable
production. The proposed approach has significant advantages compared to the
classical approach (conducting of hydrodynamic tests by shutting down a well
to read the pressure recovery curve), namely: there is no need to shut down
the well for research. In addition, taking into account the huge number of
technological operations carried out to bring wells on to stable production
will allow increasing the research coverage of the production wells stock. A
calculation was performed according to the proposed interpretation algorithm,
and a comparison with the field data was made. The comparison showed that the
calculation error when using such parameters as permeability and reservoir
pressure was less than 5 %, due to the sensitivity to the process and
possible inaccuracy of the data, the inaccuracy by the skin factor made 17 %.
Keywords: bring
wells on to stable production; reservoir characteristics; mathematical model;
oil production; units of electrical centrifugal pumps; least squares method;
data interpretation.
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UDC
622.276+622.692.4.01:532.5 DOI:
10.30713/0207-2351-2020-4(616)-32-36
APPROBATION OF THE COMPOSITIONAL HYDRAULIC
"ENGINE" (ON THE EXAMPLE
OF ONE DEPOSIT IN SIBERIA) (p. 32)
Vadim Petrovich Shakshin,
Alexey Aleksandrovich Mokrev,
Artem Igorevich Kapustin
SamaraNIPIneft LLC
18, Vilonovskaya str., Samara, 443010, Russian
Federation,
e-mail: kirjanovaEV@samnipi.rosneft.ru
Gas-oil mixture PVT properties are calculated by
a compositional model application. An algorithm for solving the phase
equilibrium problem for a three-phase system is presented. A comparison of
the calculated linear pressures at the wells with the real data obtained from
one of the fields in Siberia as well as a comparison with the data of the
model calculation using PIPESIM 2017.2 simulator (manufacturer – Schlumberger
company) are given.
Keywords: fluid
model; compositional model; equation of state; phase equilibrium; calculation
of PVT properties.
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UDC
622.276.5.001.5:622.276.5.003 DOI:
10.30713/0207-2351-2020-4(616)-37-40
DETERMINATION OF OPTIMAL NUMBER OF WELLS FOR
RATE TRANSIENT ANALYSIS
FROM ECONOMIC POINT OF VIEW (p. 37)
Valeriy Askhatovich Iktisanov, Dr. of tech. sci., Professor,
Amur Fizyusovich Yartiev, Dr. of economic sci.
TatNIPIneft Institute – PJSC TATNEFT
32, M. Jalil str., Bugulma, 423236, Republic of
Tatarstan, Russian Federation,
e-mail: iktissanov@tatnipi.ru;
yartiev@tatnipi.ru
Method for determination of optimal number of
wells for rate and pressure transient analysis is proposed. This method is
based on probabilistic economic assessment of success rate losses during
various formation and bottomhole treatment operations and evaluation of
expenses associated with rate and pressure buildup tests and interpretations
with account of the oil left behind. The resultant estimates suggest that
transient tests should be conducted in 50 % of wells, on the average, under
conditions specific to TATNEFT.
Keywords: rate
transient analysis; flowing build-up curves; pressure build-up curves; oil
production; expenses; success rate.
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UDC 622.691.12 DOI:
10.30713/0207-2351-2020-4(616)-41-47
PROCEDURE FOR JUSTIFYING PROCESS CONDITIONS OF
GAS AND GAS CONDENSATE
WELLS USING INTEGRATED MODELS (p. 41)
Andrey Nikolaevich Kharitonov, Cand. of fiz.-mat. sci.,
Tatiyana Anatolievna Pospelova, Cand. of tech. sci.,
Anton Yurievich Yushkov, Cand. of tech. sci.,
Alexander Vladimirovich
Strekalov, Dr. of tech. sci.,
Anna Sergeevna Zavorina,
Vasily Pavlovich Pavlov
LLC "Tyumen Petroleum Research
Center"
42, Maxim Gorky str., Tyumen, 625048, Tyumen
region, Russian Federation;
Oleg Anatolievich Loznyuk,
Yury Aleksandrovich Arkhipov, Cand. of tech. sci.,
Rosneft Oil Company
26/1, Sofiyskaya naberezhnaya, Moscow, 115035,
Russian Federation;
Mikhail Aleksandrovich
Skorobogach, Cand. of tech. sci.,
Alexey Leonidovich Nazarov
Sibneftegaz
78à, Taezhnaya str.,
Novy Urengoy, 629305, Yamal-Nenets autonomous region, Russian Federation.
The wells of gas and gas condensate fields are
operated in accordance with the assigned operation conditions which are set
on the basis of information obtained during the exploration, completion, and
development of hydrocarbon reservoirs.
The operation conditions of wells should ensure
uniform recovery of gas over the area, as well as maintain the parameters for
stable and safe operation, taking into account all the subsurface and
engineering limitations, including the maximum allowable drawdown and the
absence of erosion of casing walls and hydrate formation. In case of
significant water cuts in wells, it is also necessary to take into account
the limitations on the throughput of a gas treatment unit and an industrial
waste injection site.
The strong mutual influence of individual field
elements requires a systematic approach to designing. An aquifer, a
reservoir, wells, gas collection networks, gas treatment facilities and a
booster complex should be regarded as a single thermo-hydrodynamic system in
which all subsystems are interconnected. The optimal conditions for the joint
operation of wells and field facilities that ensure gas recovery in
accordance with the business plan at the maximum inlet pressure of a
compressor station or a gas treatment plant, as well as the maximum possible
condensate production must be justified.
This approach is implemented through the use of
integrated geological and technological models which include all elements of
a gas production and treatment system and provide a flow-through calculation
from a reservoir to a trunk gas pipeline. The field is divided into two
subsystems, i. e. a reservoir – wells – a gas buster station and a booster
compressor station – a gas treatment unit; the functions of gas pressure vs
recoveries at the junction of these subsystems at a gas buster station outlet
before a booster compressor station are built, which determine the field
working area. The field operation conditions are selected within this area,
while maintaining the planned gas recoveries and ensuring the maximum
economic performance of the field, which, as a rule, corresponds to the
maximum pressure at a compressor station inlet which ensures lower
compression ratios and fuel gas consumption.
A case study of Pyreiny gas condensate field is
described with the estimated operation conditions of wells using the
developed method. The estimates are in good agreement with the actual
operation conditions as of September 2019.
The developed method for justifying the
operation conditions of gas and gas condensate wells makes it possible to
optimize the operation schedule of the entire field to achieve its maximum
performance and safety.
Keywords: well
operation conditions; gas gathering networks; booster compressor station;
complex gas treatment unit; integrated model; maximum allowable drawdown;
erosion wear.
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UDC
622.276.8:338.512 DOI:
10.30713/0207-2351-2020-4(616)-48-53
SOME SPECIFIC FEATURES OF SCENARIO CONDITIONS
FORMATION FOR TECHNICAL-ECONOMIC ESTIMATES WHEN COMPARING OILFIELD SEPARATION
EQUIPMENT OF DIFFERENT TYPES (p. 48)
Alexander Vladimirovich Grishagin,
Denis Vyacheslavovich Kashaev
SamaraNIPIneft LLC
18, Vilonovskaya str., Samara, 443010, Russian
Federation,
e-mail: GrishaginAV@samnipi.rosneft.ru
Oleg Vladimirovich Gladunov
Samaraneftegaz JSC
50, Volzhsky prosp., Samara, 443071, Russian
Federation,
å-mail: sng@samng.ru
The article considers the main parameters and characteristics
taken into account when forming scenario conditions for technical-economic
assessments of the use of oil field separation equipment of various types
during oil wells dehydration. The examples of the results of comparison of
the variants of assemblies of preliminary water disposal units by oil
separation equipment, manufactured in Russia and abroad providing for their
practical efficiency evaluation at the territory of Samara region, are
presented. The authors of the paper proposed an enlarged matrix for the
selection of oil separation equipment for the processes of gravitational
thermochemical dewatering of oil during oil field preparation.
Keywords: oil
emulsion dehydration; innovative oil separation equipment; feasibility
calculations.
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UDC
622.276:532.137 DOI:
10.30713/0207-2351-2020-4(616)-54-59
EXPERIMENTAL STUDIES OF OIL VISCOSITY IN FIELD
CONDITIONS TO ASSESS THE ERROR
OF THE MEASUREMENT WHEN USING HOPPLER VISCOSITY GAGE (p. 54)
Anatoliy Andreevich Isaev, Cand. of tech. sci.,
Vladimir Ivanovich Malykhin,
Almaz Amirzyanovich Sharifullin, Cand. of tech. sci.
Sheshmaoil Management company LLC
a/ya 192, P.O. No. 8, Almetyevsk, 423458,
Republic of Tatarstan, Russian Federation,
e-mail: isaeff-oil@yandex.ru
Verification of the accuracy of oil viscosity
measurement results using a new GNP viscometer based on the Höppler
method developed by Sheshmaoil Management company LLC was found to be
satisfactory. The results of dynamic viscosity measurements were obtained
during the experimental studies on error and uncertainty evaluation, as well
as the results of determination of metrological characteristics. The
viscometer’s constant, ball falling time and the tool's reduced error in
viscosity measurement were determined for various mixtures. The equations
provided in the article make it possible to determine the dynamic viscosity,
error and uncertainty of measurements.
Keywords: viscosity; water-in-oil emulsion; viscometer; measurement
technique; the Höppler method; ball falling time; calibrated tube;
measurement error.
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UDC 622.244.442.063.2 DOI:
10.30713/0207-2351-2020-4(616)-60-63
THE NECESSITY AND POSSIBILITIES OF CONTROL OF CATION
POLYMERS CONTENT
IN THE FLUSHING FLUID DURING DRILLING (p. 60)
Zoya Valerievna Ulyanova
Perm National Research Polytechnic University
29, Komsomolsky prosp., Perm, 614990, Russian
Federation,
e-mail: z.v.uljanova@pstu.ru
Yury Aleksandrovich Kulyshev
SIC "Energoresurs" JSC
42a, Gazety Zvezda str., Perm, 614039, Russian
Federation,
e-mail: sic_er@mail.ru
As part of the efficiency monitoring task of a
drilling fluid which contains cationic polymers, the objective necessity of
controlling their quantity is shown. Given the low informativeness of the
total cationic polymer concentration due to the rapid inactivation of its
molecules caused by irreversible adsorption on drill cuttings, the need of
monitoring the active polymer molecules quantity is emphasized. An approach
allowing to make such assessment and to choose the supplementary treatments
degree of the circulating solution with a cationic polymer at each time point
of drilling is proposed. Taking into account the necessary informativeness, as
well as the ease of implementation, the proposed approach practical value is
quite obvious.
Keywords: clay
rock; wellbore stability; mud quality management; cationic polymers; reagent
content control techniques.
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UDC
622.276.72 DOI:
10.30713/0207-2351-2020-4(616)-64-68
INCREASE OF THE TEMPERATURE FORECAST ACCURACY
ALONG THE WELLBORE
WITH ACCOUNT OF THE PRODUCTS MOVEMENT AND DEGASSING
SPECIFIC FEATURES (p. 64)
Vladislav Yurievich Nikulin,
Yury Veniaminovich Zeigman, Dr. of tech. sci., Professor
Ufa State Petroleum Technology University
1, Kosmonavtov str., Ufa, 450062, Republic of
Bashkortostan, Russian Federation,
e-mail: NikulinVY@mail.ru; JVZeigman@yandex.ru
The article is devoted to the problems of
improving the accuracy of predicting the temperature of borehole products in
a producing well. The authors reveal the importance of the accurate
determination of temperature distribution from the well bottom to the well
head for solving a number of field tasks, including the efficiency increase
of complicating factors prevention. Particular attention is paid to the
specific features of widely used techniques, which are often either
non-linear or difficult to use, or linear and do not take into account such
important parameters as water cut and gas saturation of the produced
products, which is important in conditions of changing the wells operating
mode. Based on the conducted study, an algorithm is proposed that allows
increase of the temperature calculation accuracy for any operation object
using the Alves method. The main advantage of the adapted model is its easy
application, accounting of products water cut and gas saturation effects. On
the example of one of the deposits located in the Far North, an adapted model
for calculating the temperature with a deviation from the actual values from
the thermograms of not more than 4 °C is obtained.
Keywords:
temperature; production well; model; prediction; degassing; algorithm; wax.
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MANAGEMENT AND ECONOMICS OF OIL AND GAS INDUSTRY"
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