Pre-Pilot Project (Field Test) Chemical EOR Injection Huff & Puff Surfactant to Improve Oil Production in the Meruap Field

2018 ◽  
Author(s):  
Zulfikar Zulfikar
Keyword(s):  
Field Test ◽  
Oil Production ◽  
Pilot Project ◽  
Test Chemical ◽  
Chemical Eor

Pilot Project Evaluating WAG Efficiency for Carbonate Reservoir in Eastern Siberia

2021 ◽  
Author(s):  
Valentina Zharko ◽  
Dmitriy Burdakov
Keyword(s):  
Oil Recovery ◽  
Gas Injection ◽  
Oil Production ◽  
Pilot Project ◽  
Carbonate Reservoir ◽  
Recovery Factor ◽  
Eastern Siberia ◽  
Water Cut ◽  
Wag Injection ◽  
Injection Rates

Abstract The paper presents the results of a pilot project implementing WAG injection at the oilfield with carbonate reservoir, characterized by low efficiency of traditional waterflooding. The objective of the pilot project was to evaluate the efficiency of this enhanced oil recovery method for conditions of the specific oil field. For the initial introduction of WAG, an area of the reservoir with minimal potential risks has been identified. During the test injections of water and gas, production parameters were monitored, including the oil production rates of the reacting wells and the water and gas injection rates of injection wells, the change in the density and composition of the produced fluids. With first positive results, the pilot area of the reservoir was expanded. In accordance with the responses of the producing wells to the injection of displacing agents, the injection rates were adjusted, and the production intensified, with the aim of maximizing the effect of WAG. The results obtained in practice were reproduced in the simulation model sector in order to obtain a project curve characterizing an increase in oil recovery due to water-alternating gas injection. Practical results obtained during pilot testing of the technology show that the injection of gas and water alternately can reduce the water cut of the reacting wells and increase overall oil production, providing more efficient displacement compared to traditional waterflooding. The use of WAG after the waterflooding provides an increase in oil recovery and a decrease in residual oil saturation. The water cut of the produced liquid decreased from 98% to 80%, an increase in oil production rate of 100 tons/day was obtained. The increase in the oil recovery factor is estimated at approximately 7.5% at gas injection of 1.5 hydrocarbon pore volumes. Based on the received results, the displacement characteristic was constructed. Methods for monitoring the effectiveness of WAG have been determined, and studies are planned to be carried out when designing a full-scale WAG project at the field. This project is the first pilot project in Russia implementing WAG injection in a field with a carbonate reservoir. During the pilot project, the technical feasibility of implementing this EOR method was confirmed, as well as its efficiency in terms of increasing the oil recovery factor for the conditions of the carbonate reservoir of Eastern Siberia, characterized by high water cut and low values of oil displacement coefficients during waterflooding.

First Successful Autonomous ICD Pilot for GOR Management Across ADNOC Offshore

2021 ◽  
Author(s):  
Fazeel Ahmad ◽  
Zohaib Channa ◽  
Fahad Al Hosni ◽  
Salman Farhan Nofal ◽  
Ziad Talat Libdi ◽  
...  
Keyword(s):  
Oil Production ◽  
Pilot Project ◽  
Gas Production ◽  
Simulation Software ◽  
Production Performance ◽  
Production Operation ◽  
Open Hole ◽  
Early Production ◽  
Horizontal Wellbore ◽  
Selection Factors

Abstract The paper discusses the pilot project in ADNOC Offshore to assess the Autonomous Inflow Control Device (AICD) technology as an effective solution for increasing oil production over the life of the field. High rate of water and gas production in horizontal wells is one of the key problems from the commencement of operation due to the high cost of produced water and gas treatment including several other factors. Early Gas breakthrough in wells can result in shut-in to conserve reservoir energy and to meet the set GOR guidelines. The pilot well was shut-in due to high GOR resulted from the gas breakthrough. A pilot project was implemented to evaluate the ability of autonomous inflow control technology to manage gas break through early in the life of the well spanned across horizontal wellbore. And also to balance the production influx profile across the entire lateral length and to compensate for the permeability variation and therefore the productivity of each zone. Each compartment in the pilot well was equipped with AICD Screens and Swell-able Packers across horizontal open hole wellbore to evaluate oil production and defer gas breakthrough. Some AICDs were equipped with treatment valve for the compartments that needed acid simulation to enhance the effectiveness of the zone. The selection factors for installing number of production valves in the pilot well per each AICD was based on reservoir and field data. Pre-modeling of the horizontal wellbore section with AICD was performed using commercial simulation software (NETool). After the first pilot was completed, a detailed technical analysis was conducted and based on the early production results from the pilot well showed that AICD completions effectively managed gas production by delaying the gas break through and restricting gas inflow from the reservoir with significant GOR reduction ±40% compared to baseline production performance data from the open hole without AICD thus increasing oil production. The pilot well performed positively to the AICD completion allowing to produce healthy oil and meeting the guidelines. The early production results are in line with NETool simulation modelling, thereby increasing assurance in the methods employed in designing the AICD completion for the well and candidate selection. This paper discusses the successful AICD completion installation and production operation in pilot well in ADNOC Offshore to manage GOR and produced the well with healthy oil under the set guidelines. This will enable to re-activate wells shut-in due to GOR constraint to help meeting the sustainable field production target.

EOR Techniques Tailored to Venezuelan Conventional and Unconventional Oils: Critical Review

2020 ◽  
Author(s):  
Fernancelys Rodriguez M.
Keyword(s):  
Oil Production ◽  
Mobility Control ◽  
Heavy Oils ◽  
The North ◽  
Viscous Oil ◽  
Fluid Systems ◽  
Producer Country ◽  
Chemical Eor ◽  
Gas Flooding ◽  
Compositional Gradients

Abstract Venezuela has been ranked as a potential oil producer country thanks to its huge reserves of conventional and unconventional oils. Conventional reservoirs with complex fluid systems, located in the North of Monagas state, where it is possible to observe thick fluid columns with significant compositional gradients (showing changes from gas condensate to non-mobile oil-Tar mat). In these types of reservoirs EOR methods such as miscible gas flooding have been successfully applied to compensate pressure decline and avoid asphaltene deposition issues. Production of unconventional oils, the largest highly-viscous oil reservoir of La Faja Petrolifera del Orinoco (La FPO), demands great challenges. Discovered in the 1930’s, the first rigorous evaluations of this reservoir started in the 1980s [1]; those huge deposits of highly viscous oils were considered technically and economically unattractive at that time. Due to production decline of conventional oil reservoirs, efforts are being done by the Venezuelan National Oil Company and collaborators to develop EOR projects to achieve increasing oil production in unconventional (heavy and extra-heavy) reservoirs, being the most promising options thermal and chemical EOR methods. Some authors agree that in the FPO, only 40–65% (depending on the site) of the oil-bearing formations is suitable for thermal EOR methods. Recent works have been showing the potential of chemical EOR for extra-heavy oils in La FPO [2, 3, 4, 5, 6, 7, 8, 9], mostly for mobility control and mobilization of residual oil. This work presents a literature review of the EOR projects in Venezuela for conventional and highly viscous oils, based on both lab and field experiences, and the perspectives for applications to increase Venezuelan oil production.

scholarly journals Thermodynamic mechanism evaluate the feasibility of oil shale pyrolysis by topochemical heat

2021 ◽  
Vol 11 (1) ◽  
Author(s):  
Shuai Zhao ◽  
Xiaoshu Lü ◽  
Youhong Sun ◽  
Jiandong Huang
Keyword(s):  
Transition State ◽  
Oil Shale ◽  
Oil And Gas ◽  
Early Stage ◽  
Oil Production ◽  
Pilot Project ◽  
Main Stage ◽  
Oil Shale Pyrolysis ◽  
Heat Method

AbstractTopochemical heat in-situ pyrolysis of oil shale is achieved by injecting high temperature nitrogen to promote oil shale pyrolysis and release heat, and then injecting air to trigger oil shale combustion in the early stage of oil shale pyrolysis, and then by injecting normal temperature air continuously to promote local oxidation of oil shale in the later stage. In order to verify the oil and gas recovery by topochemical heat method, Jilin University has chosen Fuyu City, Jilin Province, to carry out pilot project of oil shale in-situ pyrolysis by topochemical heat method. Besides, in order to infer the spontaneity, feasibility and difficulty of continuous pyrolysis of oil shale based on topochemical heat, this paper, the mechanism of solid-state pyrolysis and the thermodynamic analysis of transition state of oil shale in Fuyu area are discussed. Because the second stage of oil shale pyrolysis is the main stage of oil production. Therefore, the characteristics of Gibbs free energy, free enthalpy and free entropy of transition state in the main oil production stage of oil shale pyrolysis are obtained by calculation. The results show that in situ pyrolysis of oil shale topochemical heat can be carried out spontaneously and continuously, and the release characteristics of volatiles during pyrolysis of oil shale are described.

scholarly journals Status Quo of a CO2-Assisted Steam-Flooding Pilot Test in China

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-13
Author(s):  
Zongyao Qi ◽  
Tong Liu ◽  
Changfeng Xi ◽  
Yunjun Zhang ◽  
Dehuang Shen ◽  
...  
Keyword(s):  
Field Test ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Oil Production ◽  
Oil Field ◽  
Drainage Pattern ◽  
Steam Flooding ◽  
Production Wells ◽  
Water Cut ◽  
Production Dynamics

It is challenging to enhance heavy oil recovery in the late stages of steam flooding. This challenge is due to reduced residual oil saturation, high steam-oil ratio, and lower profitability. A field test of the CO2-assisted steam flooding technique was carried out in the steam-flooded heavy oil reservoir in the J6 block of the Xinjiang oil field (China). In the field test, a positive response to the CO2-assisted steam flooding treatment was observed, including a gradually increasing heavy oil production, an increase in the formation pressure, and a decrease in the water cut. The production wells in the test area mainly exhibited four types of production dynamics, and some of the production wells exhibited production dynamics that were completely different from those during steam flooding. After being flooded via CO2-assisted steam flooding, these wells exhibited a gravity drainage pattern without steam channeling issues, and hence, they yielded stable oil production. In addition, emulsified oil and CO2 foam were produced from the production well, which agreed well with the results of laboratory-scale tests. The reservoir-simulation-based prediction for the test reservoir shows that the CO2-assisted steam flooding technique can reduce the steam-oil ratio from 12 m3 (CWE)/t to 6 m3 (CWE)/t and can yield a final recovery factor of 70%.

Managing limited subsurface data in a mature oil field case study: extending the production lifetime of a 50-year-old oil field in Indonesia: Rantau oil field Waterflood Pilot Project

2013 ◽  
Vol 53 (2) ◽  
pp. 489
Author(s):  
Reza Ardianto
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Oil Production ◽  
Pilot Project ◽  
Oil Field ◽  
Oil Fields ◽  
Water Flooding ◽  
Peak Oil ◽  
Screening Criteria ◽  
The Government

Business management of oil and gas in Pertamina State Oil enterprises was handed to one of its subsidiaries: Pertamina EP (PEP). With a vast working area of 140,000 km2, it consists of 214 fields where 80% is an old field (mature field or brown field). Most of these oil fields were discovered during Dutch colonialism. One of these fields was Rantau oil field, discovered in 1928; it is considered one of potential structure at the time. Peak oil production was achieved at 31,711 barrels of oil per day (BOPD) (wc 17.2%) in 1969, and it is still producing 2,500 BOPD from primary stage.To get better recovery from the Rantau oil field, it is necessary to identify the potential of secondary recovery water-flooding. Some screening criteria had been completed to select an appropriate method that could be applied in the Rantau field. PEP is preparing an Enhanced Oil Recovery (EOR) program to be applied in some oil fields with subsurface and surface potential consideration. The implementation was initiated by the EOR Department at PEP. The issue of the national oil production increasing program from the government has to be realised by the EOR Department at Pertamina EP. Following the national oil increasing program, management of PEP urged to increase oil production in a rapid and realistic way. As a result, the program of secondary and tertiary recovery pilot project should be conducted simultaneously by the EOR Department on some of the fields that have passed their peak. On the other hand, PEP has only limited geology, geophysics, reservoir, and production (GGRP) data, and most of the oil fields have been producing since 1930s. The conditions that have to be dealt with are as follows: production from the existing field is declining, data is collected and interpreted during a long period, huge amounts of production data, and reservoir model and simulation do not exist and are not frequently updated. Based on this, the planning of EOR struggled due to length of time needed versus the need for quick development. It has become much more of a challenge for the team consisting of integrated geophysics, geology, reservoir, production, process facility, project management and economic evaluation. This extended abstract presents the term of managing limited GGRP data that contributes to the successful pilot waterflood project in the Rantau field. It also explains the uses of limited subsurface GGRP data to overcome the uncertainty for planning of the waterflood pilot project in the Rantau field, as a part of planning using limited data.

scholarly journals EVALUASI FORMATIF PADA VIDEO PEMBELAJARAN MAJOE DJAYA PRODUKSI EDUARTION

2014 ◽  
Vol 1 (1) ◽  
pp. 40-48 ◽  
Author(s):  
Erika Oktarini ◽  
Abdul Gafur
Keyword(s):  
Small Group ◽  
Field Test ◽  
Pilot Project ◽  
Gain Score ◽  
One To One

Tujuan dari evaluasi formatif ini adalah untuk menentukan validitas dari pilot project Video Majoe Djaya dalam aspek instruksional dan media. Selayaknya sebuah evaluasi formatif, hasil lain yang diharapkan adalah daftar revisi untuk diajukan kepada para pembuat keputusan dalam memperbaiki dan meningkatkan seri video ini. Studi menggunakan Model Evaluasi Formatif Ogle yang untuk mengevaluasi tiga dari seri video, berjudul Bilangan Bulat, Badar dan Barung I, dan Logaritma. Masing-masing video secara berurutan diperuntukan bagi siswa kelas 4, 7, dan 10. Prosedur evaluasi melibatkan review dari ahli, sesi one-to one, small group, dan field test bagi pengguna, serta review dari guru. Hasil dari penentuan validitas dalam aspek instruksional adalah baik, ditunjukkan dari modusnya yang bernilai 4. Sedangkan dari aspek media, kualitas video adalah baik, ditunjukkan dari modusnya bernilai 4 dari 5. Video juga dapat meningkatkan outcome pembelajaran sebesar 44.36% seperti yang ditunjukkan oleh hasil rerata gain score. Seri video ini dapat untuk digunakan setelah dilakukan revisi. Revisi penting yang perlu dilakukan dalam pengembangan video fase kedua adalah: 1) membagi video ke dalam bagian-bagian yang lebih pendek berisi sub bab dari materi, 2) menyediakan penjelasan yang berisi tujuan dari video untuk mengatasi kesalahpahaman dalam penggunaan video, 3) menyediakan penjelasan bagaimana menggunakan video bagi siswa maupun bagi guru, 4) menuliskan standar kompetensi ke dalam video untuk meningkatkan kejelasan bagi siswa dan guru, dan 5) memperbarui strategi instruksional supaya sesuai dan seimbang antara unsur ketepatan dan hiburan.Kata kunci: Video Pembelajaran, Evaluasi Formatif

Numerical simulation and field test of grouting in Nong'an pilot project of in-situ conversion of oil shale

2020 ◽  
Vol 184 ◽  
pp. 106477 ◽  
Author(s):  
Wei Guo ◽  
Miao Zhang ◽  
Youhong Sun ◽  
Qiang Li ◽  
Shuai Zhao ◽  
...  
Keyword(s):  
Numerical Simulation ◽  
Field Test ◽  
Oil Shale ◽  
Pilot Project

Combined Oil Displacment System and Field Test of Composite Surfactant

2013 ◽  
Vol 641-642 ◽  
pp. 77-81
Author(s):  
Xiao Lin Wu ◽  
Jian Jun Le ◽  
Ming Jun Wang ◽  
Wei Li ◽  
Meng Hua Guo ◽  
...  
Keyword(s):  
Field Test ◽  
Oil Recovery ◽  
Oil Production ◽  
Water Flooding ◽  
Laboratory Evaluation ◽  
Reservoir Permeability ◽  
Single Well ◽  
Average Water ◽  
Displacement System ◽  
Water Cut

Laboratory evaluation showed that rhamnolipid combined displacement system with low and wide effective concentration (0.125%~1.0%) can reduce interfacial tension with Pubei oil and water to 10-2mN/m. Injection of 0.5PV of rhamnolipid combined displacement system in natural core simulating reservoir permeability can increase recovery by 7.9%~9.3% more than water flooding. Field test for rhamnolipid combined displacement system was carried out with 2 injectors and 9 producers. Alternating injection is performed with two slugs with total volume of 19895.5m3, containing 250.9t of dosage. During 13 months of field test, stageous cumulative incremental oil production was 2014t, with 224t of average single well incremental oil. Daily oil production increased from 1.5t/d to 1.85t/d, average water cut decreased by1.5%, and input-output ratio was 1:2.4. This study provided a new way to improve oil recovery for other similar water flooded reservoirs.

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