scholarly journals Prediction of Current Production Rates, Cumulative Production and Recoverable Reserves of Hydrocarbon Fields

2021 ◽  
Author(s):  
Sudad H AL-Obaidi ◽  
Hofmann M
Keyword(s):  
Production Rates ◽  
Field Development ◽  
Development History ◽  
Recoverable Reserves ◽  
Proposed Model ◽  
Oil Flow ◽  
Hydrocarbon Fields ◽  
Current Production ◽  
Cumulative Production ◽  
Hydrocarbon Field

Modeling in the process of oil production has been used almost since the beginning of hydrocarbon field development, when there were ideas about the conditions of formation occurrence and oil flow to wells. An empirical model is proposed to calculate the current production rate of wells in the hydrocarbon field by year. Based on this model, an equation for calculating cumulative production was constructed. The proposed model is compared with known models and actual development history data. The resulting models of current production rates, cumulative production and recoverable reserves most accurately describe the actual results and have a high correlation parameter compared to other models.

scholarly journals Economic prerequisites for the development of low-energy based on the development of unclaimed hydrocarbon deposits

2019 ◽  
Vol 124 ◽  
pp. 05006
Author(s):  
E.S. Melekhin ◽  
A.A. Pelmeneva ◽  
E.S. Kuzina
Keyword(s):  
Mineral Resource ◽  
Distributed Generation ◽  
Raw Materials ◽  
The State ◽  
Low Energy ◽  
Resource Base ◽  
Field Development ◽  
Hydrocarbon Fields ◽  
Hydrocarbon Deposits ◽  
Hydrocarbon Field

The article assesses the state of the mineral resource base of hydrocarbon raw materials, provides estimates of the commercial efficiency of hydrocarbon field development, examines and substantiates the main economic prerequisites for the development of distributed generation based on the development of unclaimed small hydrocarbon fields.

scholarly journals Hydrocarbon field development forecast based on an integrated approach

2020 ◽  
Author(s):  
Dmitry Zavyalov
Keyword(s):  
Development Strategy ◽  
Economic Assessment ◽  
Integrated Approach ◽  
Capital Investments ◽  
Production Forecast ◽  
Field Development ◽  
Hydrocarbon Fields ◽  
System Functioning ◽  
Hydrocarbon Deposits ◽  
Hydrocarbon Field

A hydrocarbon field is a large and complex system, which functioning is possible only in accordance with a project document that defines the main characteristics for the entire period of field development. Therefore, the quality of the project document largely determines the efficiency of the field system functioning. The last stage in creating a project document for the development of a field is an economic assessment. According to the experience of designing the development of hydrocarbon fields, up to 50% of capital investments are the costs of drilling new wells of various types. Thus, the economic efficiency of field development is largely determined by the volume of drilling new wells. The article presents an integrated approach to modeling the development of hydrocarbon deposits in making a production forecast. Such an integrated approach involves performing a rapid economic assessment using Economics software which allows you to calculate the main economic indicators of field development. Thus, it reduces the total number of iterations for setting the forecast for field development strategy by an average of 25% as well as improves the economic characteristics of the whole project.

Expending Corporate Knowledge and Staff Capabilities to Address Complex Gas and Contaminated Hydrocarbon Field Development Challenges in the Sultanate of Oman

2017 ◽  
Author(s):  
Jean-Christophe Noirot ◽  
Walid Hamed ◽  
Junaid Ghulam ◽  
Robert Svec ◽  
Mustafa Cobanoglu
Keyword(s):  
Sultanate Of Oman ◽  
Field Development ◽  
Hydrocarbon Field

The geosolitonic concept of high output hydrocarbon deposits formation

2021 ◽  
pp. 13-22
Author(s):  
R. M. Bembel ◽  
S. R. Bembel ◽  
M. I. Zaboeva ◽  
E. E. Levitina
Keyword(s):  
Western Siberia ◽  
Oil And Gas ◽  
Chemical Elements ◽  
Seismic Exploration ◽  
Oil And Gas Fields ◽  
Recoverable Reserves ◽  
Production Wells ◽  
Cumulative Production ◽  
Gas Fields ◽  
Hydrocarbon Deposits

Based on the well-known results of studies of the ether-geosoliton concept of the growing Earth, the article presents the conclusions that made it possible to propose a model of thermonuclear synthesis of chemical elements that form renewable reserves of developed oil and gas fields. It was revealed that local zones of abnormally high production rates of production wells and, accordingly, large cumulative production at developed fields in Western Siberia are due to the restoration of recoverable reserves due to geosoliton degassing. Therefore, when interpreting the results of geological and geophysical studies, it is necessary to pay attention to the identified geosoliton degassing channels, since in the works of R. M. Bembel and others found that they contributed to the formation of a number of hydrocarbon deposits in Western Siberia. When interpreting the results of geological-geophysical and physicochemical studies of the fields being developed, it is recommended to study the data of the ring high-resolution seismic exploration technology in order to identify unique areas of renewable reserves, which can significantly increase the component yield of hydrocarbon deposits.

The Clipper Field, Blocks 48/19a, 48/19c, UK North Sea

2003 ◽  
Vol 20 (1) ◽  
pp. 691-698
Author(s):  
M. J. Sarginson
Keyword(s):  
North Sea ◽  
Upper Permian ◽  
Lower Permian ◽  
Reservoir Properties ◽  
Gas Field ◽  
Field Development ◽  
Matrix Permeability ◽  
Recoverable Reserves ◽  
Reservoir Permeability ◽  
Sandstone Formation

AbstractThe Clipper Gas Field is a moderate-sized faulted anticlinal trap located in Blocks 48/19a, 48/19c and 48/20a within the Sole Pit area of the southern North Sea Gas Basin. The reservoir is formed by the Lower Permian Leman Sandstone Formation, lying between truncated Westphalian Coal Measures and the Upper Permian evaporitic Zechstein Group which form source and seal respectively. Reservoir permeability is very low, mainly as a result of compaction and diagenesis which accompanied deep burial of the Sole Pit Trough, a sub basin within the main gas basin. The Leman Sandstone Formation is on average about 715 ft thick, laterally heterogeneous and zoned vertically with the best reservoir properties located in the middle of the formation. Porosity is fair with a field average of 11.1%. Matrix permeability, however, is less than one millidarcy on average. Well productivity depends on intersecting open natural fractures or permeable streaks within aeolian dune slipface sandstones. Field development started in 1988. 24 development wells have been drilled to date. Expected recoverable reserves are 753 BCF.

scholarly journals Seismicity and development of Romashkino hydrocarbon field’s Almetyevskaya area

Georesursy ◽  
2021 ◽  
Vol 23 (4) ◽  
pp. 51-57
Author(s):  
Igor Ognev ◽  
Alexey Stepanov
Keyword(s):  
Human Activities ◽  
Active Zone ◽  
Seismic Activity ◽  
The South ◽  
South Eastern ◽  
Hydrocarbon Fields ◽  
The Relationship ◽  
Hydrocarbon Field

The relationship between the various human activities and seismic activity has become more evident in the last several decades. One of the important domains where such a relationship manifests itself is hydrocarbon fields’ development. South East Tatarstan (Russia) is a region where the link between seismicity and the development of the giant Romashkino hydrocarbon field has been established. The goal of the current study is to conduct the causative analysis between the seismic activity and the development of the Romashkino hydrocarbon field’s Almetyevskaya area which is located in the most seismically active zone of the south-eastern Tatarstan.

scholarly journals METHODS FOR INCREASING EFFICIENCY OF HYDRAULIC RIGGING IN THE OIL PRODUCTION PROCESSES

2020 ◽  
pp. 32-38
Author(s):  
М. А. Куразов ◽  
З. Х. Газабиева ◽  
Р. Х. Моллаев ◽  
А. Ш. Халадов
Keyword(s):  
High Efficiency ◽  
Essential Elements ◽  
Oil Field ◽  
Hydraulic Pressure ◽  
Field Equipment ◽  
Field Development ◽  
Bottom Hole ◽  
Oil Flow ◽  
Complex Technology ◽  
Pumping Equipment

Гидравлический разрыв пласта (ГРП) представляет собой комплексную технологию обработок скважин. При этом его следует рассматривать не только как средство воздействия на призабойную зону пласта (ПЗП), но и как один из существенных элементов системы разработки месторождения в целом. Технологические схемы ГРП, в том числе с последующим химическим воздействием, различаются в зависимости от коллекторских свойств обрабатываемых объектов. Их эффективность определяется условиями, связанными с фильтрационными характеристиками пластов, то есть коэффициентами проницаемости близлежащих и удаленных зон объекта. При этом подход к проектированию обработок ГРП будет различным в низко- и высокопроницаемых пластах, и в этой связи грамотный выбор скважин имеет существенное значение. Для исключения смыкания трещин после ГРП и снятия давления в призабойной зоне пласта (ПЗП) в скважины закачиваются различные расклинивающие агенты. Расклинивающие агенты (проппанты) должны противостоять напряжениям горной породы, удерживая трещину раскрытой после снятия гидравлического давления жидкости разрыва и обеспечивая, таким образом, высокую фильтрационную способность призабойной зоны пласта и дебиты нефти скважин. Обработки скважин проводятся с использованием стандартного нефтепромыслового оборудования и насосной техники. Промысловый опыт ГРП в условиях Верхне-Салымского месторождения (Западная Сибирь) показал его достаточно высокую эффективность. Hydraulic fracturing is a complex technology of well treatment. At the same time it should be considered not only as a means of impact on the bottom-hole zone of the formation, but also as one of the essential elements of the field development system as a whole. Technological schemes of MPG, including with subsequent chemical impact, differ depending on collector properties of processed objects. Their effectiveness is determined by conditions related to filtration characteristics of formations, i. e. permeability coefficients of nearby and remote zones of the object. At the same time, the approach to the design of GRP treatments will be different in low and highly permeable formations and in this regard, competent selection of wells is essential. Various proppantsare pumped into wells to prevent closing of cracks after MPG and to relieve pressure in bottom-hole zone of formation. Proppants (proppants) must withstand rock stresses by holding the fracture open after the hydraulic pressure of the fracturing fluid has been removed, and thus ensuring high filtration capacity of the bottom-hole formation zone and well oil flow rate. Well treatments are carried out using standard oil field equipment and pumping equipment. The field experience of GRP in the conditions of Verkhne-Salymsky field (Western Siberia) showed its rather high efficiency.

Artificial Lift Optimization for Shallow Carbonate Magwa and Ostracod Formations with Massive Propped Fractures

2021 ◽  
Author(s):  
Nasser AlAskari ◽  
Muhamad Zaki ◽  
Ahmed AlJanahi ◽  
Hamed AlGhadhban ◽  
Eyad Ali ◽  
...  
Keyword(s):  
Production Performance ◽  
Shallow Depth ◽  
Production Rates ◽  
Field Development ◽  
Artificial Lift ◽  
Geological Conditions ◽  
Fracture Fluid ◽  
Reservoir Potential ◽  
Gas Lift

Abstract Objectives/Scope: The Magwa and Ostracod formations are tight and highly fractured carbonate reservoirs. At shallow depth (1600-1800 ft) and low stresses, wide, long and conductive propped fracture has proven to be the most effective stimulation technique for production enhancement. However, optimizing flow of the medium viscosity oil (17-27 API gravity) was a challenge both at initial phase (fracture fluid recovery and proppant flowback risks) and long-term (depletion, increasing water cut, emulsion tendency). Methods, Procedures, Process: Historically, due to shallow depth, low reservoir pressure and low GOR, the optimum artificial lift method for the wells completed in the Magwa and Ostracod reservoirs was always sucker-rod pumps (SRP) with more than 300 wells completed to date. In 2019 a pilot re-development project was initiated to unlock reservoir potential and enhance productivity by introducing a massive high-volume propped fracturing stimulation that increased production rates by several folds. Consequently, initial production rates and drawdown had to be modelled to ensure proppant pack stability. Long-term artificial lift (AL) design was optimized using developed workflow based on reservoir modelling, available post-fracturing well testing data and production history match. Results, Observations, Conclusions: Initial production results, in 16 vertical and slanted wells, were encouraging with an average 90 days production 4 to 8 times higher than of existing wells. However, the initial high gas volume and pressure is not favourable for SRP. In order to manage this, flexible AL approach was taken. Gas lift was preferred in the beginning and once the production falls below pre-defined PI and GOR, a conversion to SRP was done. Gas lift proved advantageous in handling solids such as residual proppant and in making sure that the well is free of solids before installing the pump. Continuous gas lift regime adjustments were taken to maximize drawdown. Periodical FBHP surveys were performed to calibrate the single well model for nodal analysis. However, there limitations were present in terms of maximizing the drawdown on one side and the high potential of forming GL induced emulsion on the other side. Horizontal wells with multi-stage fracturing are common field development method for such tight formations. However, in geological conditions of shallow and low temperature environment it represented a significant challenge to achieve fast and sufficient fracture fluid recovery by volume from multiple fractures without deteriorating the proppant pack stability. This paper outlines local solutions and a tailored workflow that were taken to optimize the production performance and give the brown field a second chance. Novel/Additive Information: Overcoming the different production challenges through AL is one of the keys to unlock the reservoir potential for full field re-development. The Magwa and Ostracod formations are unique for stimulation applications for shallow depth and range of reservoirs and fracture related uncertainties. An agile and flexible approach to AL allowed achieving the full technical potential of the wells and converted the project to a field development phase. The lessons learnt and resulting workflow demonstrate significant value in growing AL projects in tight and shallow formations globally.

A Semianalytical Model for Simulating Combined Electromagnetic Heating and Solvent-Assisted Gravity Drainage

SPE Journal ◽  
2018 ◽  
Vol 23 (04) ◽  
pp. 1248-1270 ◽  
Author(s):  
Lanxiao Hu ◽  
Huazhou Andy Li ◽  
Tayfun Babadagli ◽  
Majid Ahmadloo
Keyword(s):  
Flow Rate ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Influential Factors ◽  
Sensitivity Analyses ◽  
Gravity Drainage ◽  
Hybrid Technique ◽  
Solvent Injection ◽  
Proposed Model ◽  
Oil Flow

Summary Solvent/thermal hybrid methods have been proposed recently to enhance heavy-oil recovery and to overcome the shortcomings that are encountered when either method is solely applied. One of the methods for this hybridization is to combine electromagnetic (EM) heating and solvent injection to facilitate heavy-oil production by gravity drainage. This approach has several advantages including reduced CO2 emissions, decreased water consumption, and appropriateness for water-hostile reservoirs. We are currently lacking any mathematical model for better understanding, designing, and optimizing this hybrid technique, which is partly attributed to this technique still being in its infancy. We propose a semianalytical model to predict the oil-flow rate resulting from the combined EM heating and solvent-assisted gravity drainage. The model first calculates the temperature distribution within the EM-excited zone caused by the radiation-dominated EM heating. Using different attenuation coefficients within and beyond the vapor chamber, the model can properly describe the corresponding temperature responses in these regions. Next, an average temperature of the chamber edge contributed by EM heating is used to estimate the temperature-dependent properties, such as vapor/liquid equilibrium ratios (K-values), heavy-oil/solvent-mixture viscosity, and solvent diffusivity. Subsequently, a 1D diffusion equation is used to calculate the solvent-concentration distribution ahead of the chamber edge. Eventually, the oil-flow rate is evaluated with the calculated temperature and solvent distributions ahead of the chamber edge. The proposed model is validated against the experimental results obtained in our previous study, and the predicted oil-flow rate agrees reasonably well with the experimental data. The proposed model can efficiently predict the oil-flow rate of this hybrid process. We conduct sensitivity analyses to examine the effect of major influential factors on the performance of this hybrid technique, including EM heating powers, solvent types, solvent-injection pressures, and initial reservoir temperatures. The modeling results demonstrate that a higher EM heating power, a heavier solvent, and a higher solvent-injection pressure could accelerate the oil-recovery rate, but tend to lower the net present value (NPV) and increase the energy consumption. In summary, the newly proposed model provides an efficient tool to understand, design, and optimize the combined technique of EM heating and solvent-assisted gravity drainage.

V̇o2, V̇co2, and RQ in a respiratory chamber: accurate estimation based on a new mathematical model using the Kalman-Bucy method

2004 ◽  
Vol 96 (3) ◽  
pp. 1045-1054 ◽  
Author(s):  
L. Granato ◽  
A. Brandes ◽  
C. Bruni ◽  
A. V. Greco ◽  
G. Mingrone
Keyword(s):  
Mathematical Model ◽  
Measurement Errors ◽  
Estimation Method ◽  
Accurate Estimation ◽  
Production Rates ◽  
Estimation Errors ◽  
Respiratory Chamber ◽  
Residual Noise ◽  
Proposed Model

A respiratory chamber is used for monitoring O2 consumption (V̇o2), CO2 production (V̇co2), and respiratory quotient (RQ) in humans, enabling long term (24-h) observation under free-living conditions. Computation of V̇o2 and V̇co2 is currently done by inversion of a mass balance equation, with no consideration of measurement errors and other uncertainties. To improve the accuracy of the results, a new mathematical model is suggested in the present study explicitly accounting for the presence of such uncertainties and error sources and enabling the use of optimal filtering methods. Experiments have been realized, injecting known gas quantities and estimating them using the proposed mathematical model and the Kalman-Bucy (KB) estimation method. The estimates obtained reproduce the known production rates much better than standard methods; in particular, the mean error when fitting the known production rates is 15.6 ± 0.9 vs. 186 ± 36 ml/min obtained using a conventional method. Experiments with 11 humans were carried out as well, where V̇o2 and V̇co2 were estimated. The variance of the estimation errors, produced by the KB method, appears relatively small and rapidly convergent. Spectral analysis is performed to assess the residual noise content in the estimates, revealing large improvement: 2.9 ± 0.8 vs. 3,440 ± 824 (ml/min)2 and 1.8 ± 0.5 vs. 2,057 ± 532 (ml/min)2, respectively, for V̇o2 and V̇co2 estimates. Consequently, the accuracy of the computed RQ is also highly improved (0.3 × 10-4 vs. 800 × 10-4). The presented study demonstrates the validity of the proposed model and the improvement in the results when using a KB estimation method to resolve it.

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