scholarly journals Comparative Study of Oil Recovery Factor Determination for Edge and Bottom Water Drive Mechanism Using Water Influx Models

2021 ◽  
Vol 6 (5) ◽  
pp. 1-9
Author(s):  
C. G. J. Nmegbu ◽  
Orisa F. Ebube ◽  
Emmanuel Aniedi Edet
Keyword(s):  
Oil Recovery ◽  
History Matching ◽  
Bottom Water ◽  
Research Work ◽  
Relative Size ◽  
Material Balance ◽  
Recovery Factor ◽  
Production Data ◽  
Percentage Increase ◽  
Average Percentage

The purpose of this research work is to comparatively study the oil recovery factor from two major aquifer geometry (Bottom and Edge water aquifer) using water aquifer model owing to the fact that most if not every reservoir is bounded by a water aquifer with relative size content (Most Large). These aquifers are pivotal in oil recovery factor (percent%), Cumulative oil produced (MMSTB) as well as overall reservoir performance the methodology utilized in this study involves; Identification of appropriate influx models were utilized for aquifer characterization. The characterizes of the Niger Delta reservoir aquifer considered include aquifer permeability, aquifer porosity etc. Estimation of aquifer properties is achieved by using regressed method in Material Balance Software (MBAL). This approach involves History Matching of average reservoir pressure with computed pressure of the reservoir utilizing production data and PVT data. The computed pressure from model is history matched by regressing most uncertain parameters in aquifer such as aquifer size, permeability, and porosity. Historic production data was imputed into the MBAL Tank Model, the production data was matched with the model simulation by regressing on rock and fluid parameters with high uncertainty. The match parameters were recorded as the base parameter and other sensitivity on aquifer parameters using the Fetkovich model for the bottom and edge water drive. The average percentage increase in oil cumulative volume was 0.40% in fovour of bottom water drive. Further sensitivity on cumulative oil recovered showed the increase in reservoir size with increasing aquifer volumes increases oil production exponentially in bottom water drive whereas edge water drive increased linearly. Aquifer volume, aquifer permeability showed linear relationship with bottom and edge water drive.

Improved Understanding of Reservoir Fluid Dynamics in the North Sea Snorre Field by Combining Tracers, 4D Seismic, and Production Data

2008 ◽  
Vol 11 (04) ◽  
pp. 768-777 ◽  
Author(s):  
Olaf K. Huseby ◽  
Mona Andersen ◽  
Idar Svorstol ◽  
Oyvind Dugstad
Keyword(s):  
Fluid Dynamics ◽  
Fluid Flow ◽  
North Sea ◽  
Oil Recovery ◽  
History Matching ◽  
Production Data ◽  
The North ◽  
Fault Block ◽  
The North Sea ◽  
4D Seismic

Summary To obtain improved oil recovery (IOR), it is crucial to have a best-possible description of the reservoir and the reservoir dynamics. In addition to production data, information can be obtained from 4D seismic and from tracer monitoring. Interwell tracer testing (IWTT) has been established as a proven and efficient technology to obtain information on well-to-well communication, heterogeneities, and fluid dynamics. During such tests, chemical or radioactive tracers are used to label water or gas from specific wells. The tracers then are used to trace the fluids as they move through the reservoir together with the injection phase. At first tracer breakthrough, IWTT yields immediate and unambiguous information on injector/producer communication. Nevertheless, IWTT is still underused in the petroleum industry, and data may not be used to their full capacity--most tracer data are used in a qualitative manner (Du and Guan 2005). To improve this situation, we combine tracer-data evaluation, 4D seismic, and available production data in an integrated process. The integration is demonstrated using data from the Snorre field in the North Sea. In addition to production data, extensive tracer data (dating back to 1993) and results from three seismic surveys acquired in 1983, 1997, and 2001 were considered. Briefly this study shows thatSeismic and tracer data applied in combination can reduce the uncertainties in interpretations of the drainage patterns.Waterfronts interpreted independently by tracer response and seismic dimming compare well.Seismic brightening interpreted as gas accumulation is supported by the gas-tracer responses. Introduction The Snorre field is located in the Tampen Spur area on the Norwegian continental shelf and is a system of rotated fault blocks with beds dipping 4 to 10° toward the northwest. The reservoir sections are truncated by the Base Cretaceous unconformity. The reservoir sections consist of fluvial deposits of the Statfjord and Lunde formations. The reservoir units contain thin sand layers with alternating shale in a complex fault pattern. A challenge regarding optimization of the reservoir drainage, as well as oil production, is to understand how the different sand layers communicate and to what degree the faults act as barriers or not. The present work concentrates on the integration of 4D-seismic and tracer methods to obtain information on fluid flow in the Upper Statfjord (US) and Lower Statfjord (LS) formations in the Central Fault Block (CFB). The outline of this fault block is indicated in Fig. 1. The net/gross ratio is higher and the reservoir quality is generally better in the US than the LS formation. The CFB is produced by water-alternating-gas (WAG) injection as the drive mechanism, where the injectors are placed downdip and the producers updip. The average reservoir pressure in the CFB is 300 bar, and the reservoir temperature is 90°C. Tracer data are used to understand fluid flow in the reservoir. The data give valuable information about the dynamic behavior and well communication, but in some cases the interpretation may be complicated by reinjection of produced gas and water. Tracer studies in the Snorre field have been presented previously in several papers (Dugstad et al. 1999; Ali et al. 2000; Aurdal et al. 2001). To use the data fully, however, integration with other types of reservoir data is important. The main objectives of the seismic monitoring of Snorre are to contribute to increased oil recovery and to optimize placement of new wells. 4D analysis, together with tracers, should potentially increase the multidisciplinary understanding of the drainage pattern in the reservoirs. The results should, in addition to all the reservoir and production data, be used actively in target-remaining-oil processes and in well planning. In addition, the 4D data can give input to update the geological model and simulation model (history matching) and to identify possible well interventions. There is also a potential to include the data in workflows to identify lithology changes.

An Integrated Model for History Matching and Predicting Reservoir Performance of Gas/Condensate Wells

2013 ◽  
Vol 16 (04) ◽  
pp. 412-422
Author(s):  
A.M.. M. Farid ◽  
Ahmed H. El-Banbi ◽  
A.A.. A. Abdelwaly
Keyword(s):  
History Matching ◽  
Material Balance ◽  
Integrated Model ◽  
Gas Condensate ◽  
Production Performance ◽  
Productivity Index ◽  
Production Data ◽  
Fluid Composition ◽  
Two Phase ◽  
Reservoir Simulator

Summary The depletion performance of gas/condensate reservoirs is highly influenced by changes in fluid composition below the dewpoint. The long-term prediction of condensate/gas reservoir behavior is therefore difficult because of the complexity of both composition variation and two-phase-flow effects. In this paper, an integrated model was developed to simulate gas-condensate reservoir/well behavior. The model couples the compositional material balance or the generalized material-balance equations for reservoir behavior, the two-phase pseudo integral pressure for near-wellbore behavior, and outflow correlations for wellbore behavior. An optimization algorithm was also used with the integrated model so it can be used in history-matching mode to estimate original gas in place (OGIP), original oil in place (OOIP), and productivity-index (PI) parameters for gas/condensate wells. The model also can be used to predict the production performance for variable tubinghead pressure (THP) and variable production rate. The model runs fast and requires minimal input. The developed model was validated by use of different simulation cases generated with a commercial compositional reservoir simulator for a variety of reservoir and well conditions. The results show a good agreement between the simulation cases and the integrated model. After validating the integrated model against the simulated cases, the model was used to analyze production data for a rich-gas/condensate field (initial condensate/gas ratio of 180 bbl/ MMscf). THP data for four wells were used along with basic reservoir and production data to obtain original fluids in place and PIs of the wells. The estimated parameters were then used to forecast the gas and condensate production above and below the dewpoint. The model is also capable of predicting reservoir pressure, bottomhole flowing pressure, and THP and can account for completion changes when they occur.

IOR/EOR Methods Adapted to High Water Production Zones of Heavy and Extra-Heavy Oil Reservoirs in La Faja Petrolifera Del Orinoco-Venezuela: State of the Art

2021 ◽  
Author(s):  
Fernancelys Rodriguez M.
Keyword(s):  
Crude Oil ◽  
Oil Recovery ◽  
New Technologies ◽  
Research Work ◽  
Steam Injection ◽  
High Water ◽  
Recovery Factor ◽  
Production Methods ◽  
Chemical Eor ◽  
Bodies Of Water

Abstract Venezuela is well known for its immense reserves of heavy and extra heavy crude oils located in La Faja Petrolífera Del Orinoco (La FPO), in the east of the country, with certified reserves of up to 235 billion barrels. The main production methods that have been applied in La FPO are Cold Production with sand through vertical and horizontal wells, and the application of Thermal IOR/EOR methods (e.g. steam injection, In-situ Combustion, SAGD, etc.) and Chemical EOR methods (e.g. polymer flooding). One of the main challenges in La FPO is the increase in the recovery factor (with < 10% of recovery factor to date), due to the low mobility of crude oil at reservoir conditions, and the presence of local and regional bodies of water (flushed zones and aquifers) where conventional cold production methods are not efficient. The presence of these bodies of water negatively affects the production profiles and the quality of crude oil, observing high water cuts due to the adverse mobility ratio and the formation of complex emulsions that affect the crude lifting and separation systems. Due to the current dramatic decline in production of conventional reservoirs in Venezuela and the vital role of La FPO to support Venezuelan oil production, it is important to identify methods and new technologies that allow for the increase in recovery factors in these complex reservoirs. This paper presents a literature review of the applied production methods and those that could be envisaged, including horizontal and dewatering wells as well as reported research work (e.g. Chemical EOR methods), to increase the oil recovery in flushed zones and/or reservoir zones with high water cuts in La FPO.

The Study on Oil Recovery of Matrix System in Fractured Bottom-Water Oil Reservoirs

2013 ◽  
Vol 295-298 ◽  
pp. 3232-3236
Author(s):  
Guo Qing Feng ◽  
Yang Zhao
Keyword(s):  
Oil Recovery ◽  
Bottom Water ◽  
Material Balance ◽  
Water Reservoir ◽  
Oil Reservoirs ◽  
Balance Theory ◽  
Fracture System ◽  
Matrix System ◽  
Matrix Porosity

Fracture and matrix porosity are two porosity systems in fractured bottom-water reservoir. Knowing the oil recovery in matrix system provides guidance for the later development of the reservoir. Using material balance theory, and combining with Leverett function, oil recovery of matrix and fracture system are calculated respectively, and the ultimate oil recovery of matrix system is predicted.

IMPROVING THE EFFICIENCY OF OPERATING AN OIL WELL WITH BOTTOM WATER

2021 ◽  
Author(s):  
Ильяс Азаматович Ишбулатов
Keyword(s):  
Oil Recovery ◽  
Bottom Water ◽  
Recovery Factor ◽  
Oil Well ◽  
Well Production ◽  
Oil Water ◽  
Water Cut

При разработке водонефтяных зон наблюдается образование конусов подошвенной воды, что ведет к увеличению обводненности скважинной продукции и снижению коэффициента извлечения нефти (КИН). В качестве одного из методов борьбы с данным явлением возможно применение технологии, описанной в патенте RU 2 730 163 C1. В данной статье представлены результаты моделирования данной технологии в гидроди-намическом симуляторе. During the development of oil-water zones, the formation of bottom water cones is observed, which leads to an increase in the water cut of the well production and a decrease in the oil recovery factor. As one of the methods to combat this phenomenon, it is possible to use the technology described in patent RU 2 730 163 C1. This article presents the results of modeling this technology in a hydrodynamic simulator.

Immiscible CO2-Assisted Gravity Drainage Process for Enhancing Oil Recovery in Bottom Water Drive reservoir

2020 ◽  
Vol 27 (2) ◽  
pp. 60-66
Author(s):  
Dahlia A. Al-Obaidi ◽  
Mohammed S. Al-Jawad
Keyword(s):  
Oil Recovery ◽  
Bottom Water ◽  
Physical Models ◽  
Recovery Factor ◽  
Gravity Drainage ◽  
Ambient Conditions ◽  
Water Contact ◽  
3D Simulation Model ◽  
Water Cut ◽  
Enhance Oil Recovery

The CO2-Assisted Gravity Drainage process (GAGD) has been introduced to become one of the mostinfluential process to enhance oil recovery (EOR) methods in both secondary and tertiary recovery through immiscibleand miscible mode. Its advantages came from the ability of this process to provide gravity-stable oil displacement forenhancing oil recovery. Vertical injectors for CO2 gas have been placed at the crest of the pay zone to form a gas capwhich drain the oil towards the horizontal producing oil wells located above the oil-water-contact. The advantage ofhorizontal well is to provide big drainage area and small pressure drawdown due to the long penetration. Manysimulation and physical models of CO2-AGD process have been implemented at reservoir and ambient conditions tostudy the effect of this method to improve oil recovery and to examine the most parameters that control the CO2-AGDprocess. The CO2-AGD process has been developed and tested to increase oil recovery in reservoirs with bottom waterdrive and strong water coning tendencies. In this study, a scaled prototype 3D simulation model with bottom waterdrive was used for CO2-assisted gravity drainage. The CO2-AGD process performance was studied. Also the effects ofbottom water drive on the performance of immiscible CO2 assisted gravity drainage (enhanced oil recovery and watercut) was investigated. Four different statements scenarios through CO2-AGD process were implemented. Resultsrevealed that: ultimate oil recovery factor increases considerably when implemented CO2-AGD process (from 13.5%to 84.3%). Recovery factor rises with increasing the activity of bottom water drive (from 77.5% to 84.3%). Also,GAGD process provides better reservoir pressure maintenance to keep water cut near 0% limit until gas flood frontreaches the production well if the aquifer is active, and stays near 0% limit at all prediction period for limited waterdrive.

Investigation of Well Production Mechanism in Heavy Oil Reservoirs Underlain by Strong Bottom Water

2016 ◽  
Author(s):  
Wenting Qin ◽  
Andrew K. Wojtanowicz ◽  
Pingya Luo
Keyword(s):  
Analytical Solution ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Bottom Water ◽  
Oil Reservoirs ◽  
Recovery Factor ◽  
Recovery Efficiency ◽  
Drainage Radius ◽  
Heavy Oil Reservoirs ◽  
Water Coning

Low recovery factor is identified as the main problem encountered in the heavy oil production from a strong bottom-water-drive reservoir. Unlike for conventional oils, where the expected recovery from such reservoirs could be very high — in excess of 50 percent, the expected recovery factor in heavy oil water-driven reservoirs is less than 20 percent. In this study, a qualitative analysis of the well productivity mechanisms specific for heavy oil reservoirs with bottom water is provided. The objective is to understand what make the production of heavy oil different to that of lighter oils, identify the mechanism that mostly hamper the well’s productivity and recovery efficiency. Many believe the by-passed oil due to water coning is the major cause of low ultimate oil recovery in heavy oils underlain by strong bottom water. However, in this paper, we identify another important parameter affecting recovery efficiency in such reservoirs, which hasn’t been recognized by others and its effect on recovery process is significant. The mathematic modeling and numerical study lead to a new finding: due to the aquifer’s influence on pressure response in reservoir, a no-flow boundary at xi is established, where xi is often much smaller than that of the actual reservoir size xe. The oil out to the distance xi is immobile and become bypassed oil, which accounts for large amount of the OOIP. Even the water coning can be effective controlled; the ultimate oil recovery factor will not be improved significantly if the small mobilized oil zone can’t be enlarged. An analytical solution is derived in this paper to calculate the actual drainage radius. The validity of this analytical solution is confirmed by numerical simulation runs.

scholarly journals Pengembangan Lapangan “Y” Menggunakan Simulasi Reservoir

2017 ◽  
Vol 1 (1) ◽  
pp. 31
Author(s):  
Lia Yunita
Keyword(s):  
Data Collection ◽  
History Matching ◽  
Computer Modelling ◽  
Data Entry ◽  
Recovery Factor ◽  
Production Data ◽  
Base Case ◽  
Case Scenario ◽  
Base Case Scenario ◽  
Cumulative Production

<p>Lapangan “Y” ditemukan melalui sumur pengeboran eksplorasi PMS 01 yang dibor pada 18 April 1980 dan diselesaikan pada 31 Juli 1980.Hal ini menyebabkan timbulnya pemikiran bagaimana strategi untuk mengembangkan lapangan guna meningkatkan <em>recovery factor.</em>Dalam menyelesaikan permasalahan ini dilakukan simulasi reservoir. Simulator yang digunakan adalah <em>CMG-GEM </em>yang dibuat oleh <em>Computer Modelling Group Ltd., Calgary, Canada</em>. Simulator tersebut adalah simulator jenis komposisional.Langkah awal dalam tahap simulasi adalah pengumpulan, persiapan, dan pengolahan data. Pengumpulan data meliputi data geologi, batuan, fluida, ekuilibrium  dan data produksi. Proses inisialisasi merupakan tahapan setelah pemasukkan data yaitu proses pengkondisian model supaya selaras dengan kondisi awal reservoir yaitu dengan menyelaraskan OGIP hasil perhitungan simulator dengan perhitungan volumetrik. Proses inisialisasi menghasilkan harga OGIP simulasi sebesar 23.03 Bscf dan untuk perhitungan volumetrik adalah 23.07 Bcsf, hal ini menunjukan perbedaan kurang dari 1 %. Perbedaan yang sangat kecil tersebut memperlihatkan bahwa hasil simulasi sudah sangat memadai. Validasi data juga dilakukan dengan proses <em>history matching</em> (penyelarasan). Proses penyelarasan data produksi (laju produksi terhadap waktu dan kumulatif produksi terhadap waktu) dan tekanan menghasilkan kurva yang selaras.Peramalan perilaku produksi reservoir dilakukan dengan membuat beberapa skenario produksi. Ada usulan tiga skenario, yaitu Skenario A, reservoir diproduksikan oleh satu sumur PMS 01 dengan membuka perforasi pada zona 12 dan zona 15 (<em>base case</em>), Skenario B, reservoir diproduksikan oleh PMS 01 dengan membuka perforasi pada zona 12, zona 15 dan zona 16. Skenario C, reservoir diproduksikan oleh dua sumur yaitu sumur PMS 01 (zona 12, zona 15 dan zona16) dan sumur PMS 03 (zona 12, zona 15 dan zona 16). Berdasarkan skenario yang dilakukan diperoleh kumulatif produksi terbesar pada skenario C sebesar 16.2 Bscf atau dengan <em>recovery factor</em> sebesar 70.22 %.</p><p><em>The "Y" field was discovered through an exploration drilling well PMS 01 which was drilled on April 18, 1980 and completed on July 31, 1980. This led to the emergence of ideas on how to develop a field to improve recovery factors. In solving this problem reservoir simulations were carried out. The simulator used is the CMG-GEM made by Computer Modeling Group Ltd., Calgary, Canada. The simulator is a compositional type simulator. The first step in the simulation stage is data collection, preparation, and processing. Data collection includes geological, rock, fluid, equilibrium and production data. The initialization process is the stage after data entry, namely the model conditioning process so that it is aligned with the initial reservoir conditions by aligning the OGIP results of the simulator calculation with the volumetric calculation. The initialization process produces a simulation OGIP price of 23.03 Bscf and for volumetric calculations is 23.07 Bcsf, this shows a difference of less than 1%. The small difference shows that the simulation results are very adequate. Data validation is also carried out with the history matching process. The process of aligning production data (production rate with respect to time and cumulative production with respect to time) and pressure produces a harmonious curve. Forecasting of reservoir production behavior is carried out by creating several production scenarios. There are three proposed scenarios, namely Scenario A, the reservoir is produced by one well PMS 01 by opening perforation in zone 12 and zone 15 (base case), Scenario B, the reservoir is produced by PMS 01 by opening the perforation in zone 12, zone 15 and zone 16 Scenario C, the reservoir is produced by two wells namely PMS 01 wells (zone 12, zone 15 and zone16) and PMS 03 wells (zone 12, zone 15 and zone 16). Based on the scenario, the largest cumulative production obtained in scenario C is 16.2 Bscf or with a recovery factor of 70.22%.</em></p>

Mass Transport and Exchange Inside Tight Matrix-Fracture Systems During CO2 Huff-n-Puff and Flooding Processes

2021 ◽  
Author(s):  
Bing Wei ◽  
Mengying Zhong ◽  
Haoran Tang ◽  
Lele Wang ◽  
Ke Gao ◽  
...  
Keyword(s):  
Mass Transport ◽  
Oil Recovery ◽  
History Matching ◽  
Open Fracture ◽  
Recovery Factor ◽  
Co2 Injection ◽  
Co2 Flooding ◽  
Cycle Number ◽  
Matrix Fracture ◽  
Recovery Dynamics

Abstract The potential of CO2 injection in stimulating tight oil recovery after primary production has been extensively demonstrated previously. However, the processes of mass transport and exchange inside dual-permeability matrix-facture system driven by CO2 remain unclear. To improve our understanding and supplement the existing knowledge, three types of matrix-fracture models were designed and employed to mimic CO2 injection processes (huff-n-puff and flooding modes), named fully open fracture (FOF), partially open fracture (POF), and crossed open fracture (COF) models, respectively. CO2 huff-n-puff and flooding experiments were conducted on these three models to observe the dynamics of pressure and oil recovery factor. Core-scale models were built up by history-matching the oil recovery dynamics through modifying the relative permeability curves based on Corey correlations. The mass transport and exchange processes with the proceeding of CO2 injection were delineated. The results showed that either CO2 huff-n-puff or CO2 flooding was capable of extracting the oil from tight matrix substantially but the increase in oil recovery factor became insignificant with the increase in cycle number or injection time. The oil resided in the proximity of injector, fracture and producer were primarily recovered during CO2 flooding. In the FOF and COF models, the matrix oil near the injector and producer was mainly mobilized. As for CO2 huff-n-puff, the oil saturation of the three models was reduced uniformly throughout the cores with cycles. The high sweep efficiency of CO2 largely mobilized the oil near the injector. It can be generally concluded that injecting CO2 by huff-n-puff protocol might be more beneficial than flooding mode for unconventionals. The results of this paper can provide insights into the oil recovery dynamics and mass transport and exchange induced by CO2 injection in tight reservoirs.

PENERAPAN MODEL QUANTUM TEACHING UNTUK MENINGKATKAN HASIL BELAJAR PKn SISWA KELAS IV SD NEGERI 19 BALIK ALAM KECAMATAN MANDAU

2017 ◽  
Vol 6 (2) ◽  
pp. 461
Author(s):  
Eltrizar Eltrizar
Keyword(s):  
Learning Outcomes ◽  
Fourth Grade ◽  
Student Learning Outcomes ◽  
Class Action ◽  
Teaching Model ◽  
Percentage Increase ◽  
Average Percentage ◽  
Average Grade ◽  
Fourth Grade Students ◽  
Teaching Learning

The problem in this research is the low of Civics learning outcomes in fourth grade (IV) SD Negeri 19 Balik Alam, this can be seen from the average grade, that is 66,23 (with KKM 70). The purpose of this study is to improve the results of learning Civics fourth grade students SD Negeri 19 Balik Alam with the application of quantum teaching learning model. This research is a class action research (PTK) with 2 cycles. Based on data analysis of research results after applying quantum teaching model, the average percentage of teacher activity in cycle I 66.66% increased to 85.4% in cycle II. The average percentage of student activity also increased by 56.25% in the first cycle increased to 87.49% in cycle II. Student learning outcomes on the basic score with the average class 66,23 and in the first cycle has increased with the average grade grade 71.11 with the percentage increase in learning outcomes 8.87% and the percentage of students who complete 73.07%, and on the second cycle increased again with the average class of 77.60 with the percentage increase in learning outcomes 17.16% and the percentage of students who complete 84.61%. The results of this study showed that the application of quantum teaching model can improve the learning outcomes of fourth grade students of SD Negeri 19 Balik Alam.

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