An Australian first initiative to re-develop the first commercial onshore oilfield into a CO2 miscible-EOR project

2019 ◽  
Vol 59 (1) ◽  
pp. 179
Author(s):  
Stephanie Barakat ◽  
Bob Cook ◽  
Karine D'Amore ◽  
Alberto Diaz ◽  
Andres Bracho
Keyword(s):  
Oil Recovery ◽  
Dynamic Modelling ◽  
Oil Production ◽  
Simulation Modelling ◽  
Oil Field ◽  
Optimal Time ◽  
Successful Implementation ◽  
Full Field ◽  
Execution Phase ◽  
Reservoir Simulator

The Moonie onshore oil field discovered in 1961, was the first commercial oil discovery in Australia. The field was purchased by Bridgeport Energy Limited (BEL) from Santos in late 2015. An Australian first initiative by BEL is to enhance oil production from the field using tertiary recovery CO2 miscible flood to maximise field oil recovery. The process involves an evaluation of well injection strategies for a miscible displacement process using reservoir simulation modelling. In addition, the project jointly addresses community concerns regarding the rise in greenhouse gas emissions by sourcing 60000–120000 tonnes/annum of CO2 from a nearby power station and/or an ethanol plant. Justified by laboratory experiments and reservoir compositional simulations, BEL’s project timeline to implement a CO2-enhanced oil recovery (EOR) pilot could start from 2020 followed by a 2–3-year full field oil production acceleration project if additional CO2 can be sourced. Based on incremental recovery and operational consideration, an injection well in the southern end of the field surrounded by six existing producers has been selected as a pilot flood. Positive indicative economics are achieved by the efficient displacement with CO2 of 8000 scf/bbl of incremental oil. Full field dynamic modelling predicts a further 8% oil recovery factor by injecting 60 Bcf of CO2 over five years, which could store in excess of three million tonnes of CO2. For the pilot, more than 90% of the injected CO2 will remain in the Precipice sandstone reservoir. However, the efficiency and viability of a CO2-EOR project is subject to successful implementation of the miscibility modelling, logistics and injection strategy and uncertainty quantification. To propel the project into the execution phase a fast-multiphase reservoir simulator has been implemented to complete a probabilistic range of results in optimal time.

Expansion of Data Analytics for Optimizing Steamflood In Mukhaizna Heavy Oil Field

2021 ◽  
Author(s):  
Mohammed Al Asimi ◽  
Nasar Al Qasabi ◽  
Duc Le ◽  
Yuchen Zhang ◽  
Di Zhu ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Data Analytics ◽  
Oil Production ◽  
Steam Injection ◽  
Lessons Learned ◽  
Oil Field ◽  
Production Performance ◽  
Optimization Process ◽  
Successful Implementation ◽  
Full Field

Abstract After successful implementation of data analytics for steamflood optimization at the Mukhaizna heavy oil field in Oman late 2018, Occidental expanded the project to two additional areas with a total of 626 wells in 2019, followed by full field coverage of more than 3,200 wells in 2020. In 2019, two separate low-fidelity proxy models were built to model the two pilot areas. The models were updated with more features to account for additional reservoir phenomena and a larger scope. On the proxy engine side, speed and robustness were improved, resulting in reduced CPU processing time and lower cost. Because of advancements in software programing and the pilots’ encouraging production performance, full-field coverage was accelerated so the model could support the efforts in optimizing steam injection during the 2020 OPEC+ production cut, not only to comply with allotted quotas, but also to allocate the resources optimally, especially the costly steam. Good improvements have been observed in overall steamflood performance, the models’ capabilities, and the optimization workflow. The steam/oil ratio has been reduced through the increase in oil production in both expanded study areas while keeping the total steam injection volume constant. Overall field steam utilization was improved both during the 2020 OPEC+ production cuts and during the production ramp-up stage afterward. With the continuous improvement in supporting tools and scripts, most of the steam optimization process steps were automated, from preparing, checking, and formatting input data to analyzing, validating, and visualizing the model outputs. Another result of these improvements was the development of a user-friendly web application to manage the model workflow efficiently. This web app greatly improved the process of case submittals, including data preparation and QC, running models (history matching and forecasting), as well as visualization of the entire workflow. In terms of optimization workflow, these improvements resulted in less time spent by the field optimization engineer in updating, refreshing, and generating new model recommendations. It also helped reduce the time spent by the reservoir management team (RMT) to test and validate the new ideas before field implementation. This paper will describe the improvements in the proxy model and the overall optimization process, show the observed oil production increases, and discuss the challenges faced and the lessons learned.

scholarly journals Application of Systematic Approach for Fast Oil Production Enhancement-Case Studies

2014 ◽  
Vol 5 (1) ◽  
pp. 182-204
Author(s):  
Seyed Mahdia Motahari ◽  
Mahdi Nadri Pari
Keyword(s):  
Economic Analysis ◽  
Oil Recovery ◽  
Oil Production ◽  
Oil Field ◽  
Time To Failure ◽  
Production Network ◽  
Improved Oil Recovery ◽  
Recovery Method ◽  
Full Field ◽  
Artificial Lift

   Full field studies and master development plans are time consuming and expensive tasks for any company to find optimum improved oil recovery method. Fast oil production enhancement is a method applied over existing assets resulting in fast increase in oil production in less expensive way. This approach consists of five steps as identification of source of production decline problem through evaluation of diagnostic tests, prioritizing different solutions for treating the problem, conceptual integrated modeling of reservoir and wells, production network optimization and economic analysis.    In this paper we elaborate and implement these five steps in an Iranian Oil Field with twenty wells. Firstly; we found that the production decline is due to poor well cleaning after stimulation and work over operation and also reservoir pressure decline leading to not having sufficient energy to push oil to the surface. Secondly; based on specifications of each well and pre-determined screening criteria; artificial lift methods were prioritized followed thirdly by conceptual modeling of first ranked artificial lift method which was electric submersible pump for first ranked wells. The fourth step was optimization of production network through sequential quadratic programming and lastly probabilistic economic analysis based on different ESP time to failure. The result of this study shows viability of application of ESP in this field in fast way.  

Oil Production Cost Function and Oil Recovery Implementation- Evidence from an Iranian Oil Field

2015 ◽  
Vol 33 (4) ◽  
pp. 459-470 ◽  
Author(s):  
Vahid Ghorbani Pashakolaie ◽  
Shahla Khaleghi ◽  
Teymor Mohammadi ◽  
Morteza Khorsandi
Keyword(s):  
Cost Function ◽  
Oil Recovery ◽  
Production Cost ◽  
Oil Production ◽  
Oil Field

scholarly journals Optimization of reinjection treatment technology for oilfield wastewater in Longdong area

2020 ◽  
Vol 194 ◽  
pp. 04046
Author(s):  
Xiulan Zhu ◽  
Yanlong Ran ◽  
Wenjie Guo ◽  
Ke Gai ◽  
Yanju Li ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Solid Phase ◽  
Sewage Treatment ◽  
Water Injection ◽  
Oil Production ◽  
High Water ◽  
Oil Field ◽  
Treatment Technology ◽  
Water Separation ◽  
High Water Cut

With the long-term water injection development of Longdong oilfields, most of the oilfield blocks have been fully in the mid-high water cut period, and the amount of oil production wastewater is increasing year by year. In order to prevent the waste of resources and energy of oil production sewage, the oil production sewage after reaching the standard is treated for reinjection, which will ensure the sustainable development of the oil field. Oil production wastewater contains crude oil, solid-phase suspended solids and other pollutants, with high salinity, and problems such as difficulty in oil-water separation, sludge, scaling and corrosion. The sewage treatment system uses a multifunctional water treatment device to effectively remove oil and filter through the “special microorganism + air flotation + filtration” process, and build a sludge sewage tank for sludge discharge and backwashing. The reformed oil recovery wastewater reinjection treatment technology turns “sewage” into “clear flow”, reduces operating costs, improves wastewater treatment efficiency, and meets the water quality requirements of oilfield reinjection water.

scholarly journals Application of an Oil-Displacing Composition for Increasing Flow Rate of Low Producing High-Viscosity Oil Wells of the Usinskoye Oil Field

2016 ◽  
Vol 18 (2) ◽  
pp. 133
Author(s):  
L.K. Altunina ◽  
I.V. Kuvshinov ◽  
V.A. Kuvshinov ◽  
V.S. Ovsyannikova ◽  
D.I. Chuykina ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Oil Production ◽  
High Viscosity ◽  
Oil Field ◽  
Thermal Methods ◽  
Cold Stimulation ◽  
Well Production ◽  
Well Stimulation ◽  
High Viscosity Oil ◽  
Stimulation Of

The results of a pilot application of a chemical composition for enhanced oil recovery developed at the IPC SB RAS are presented. The EOR-composition was tested in 2014 at the Permian-Carboniferous heavy oil deposit at the Usinskoye oil field. It is very effective for an increase in oil production rate and decrease in water cuttings of well production. In terms of the additionally produced oil, the resulting effect is up to 800 tons per well and its duration is up to 6 months. The application of technologies of low-productivity-well stimulation using the oil-displacing IKhNPRO system with controlled viscosity and alkalinity is thought to be promising. This composition is proposed for the cold’ stimulation of high-viscosity oil production as an alternative to thermal methods.

scholarly journals Enhanced oil recovery efficiency of low-salinity water flooding in oil reservoirs including Fe2+ ions

2018 ◽  
Vol 37 (1) ◽  
pp. 355-374 ◽  
Author(s):  
Yeonkyeong Lee ◽  
Hyemin Park ◽  
Jeonghwan Lee ◽  
Wonmo Sung
Keyword(s):  
Oil Recovery ◽  
Oil Production ◽  
Water Flooding ◽  
Sulfate Ion ◽  
Low Salinity ◽  
Low Salinity Water ◽  
Low Salinity Waterflooding ◽  
Injection Water ◽  
Salinity Water ◽  
Reservoir Simulator

The low-salinity waterflooding is an attractive eco-friendly producing method, recently, for carbonate reservoirs. When ferrous ion is present in the formation water, that is, acidic water, the injection of low-salinity water generally with neutral pH can yield precipitation or dissolution of Fe-minerals by pH mixing effect. FeSO4 and pyrite can be precipitated and re-dissolved, or vice versa, while siderite and Fe(OH)2 are insoluble which are precipitated, causing permeability reduction. Particularly, pyrite chemically reacts with low-salinity water and release sulfate ion, altering the wettability, favorably, to water-wet. In this aspect, we analyzed oil production focusing on dissolution of Fe-minerals and Fe-precipitation using a commercial compositional reservoir simulator. From the simulation results, the quantities of precipitation and dissolution were enormously large regardless of the type of Fe-minerals and there was almost no difference in terms of total volume in this system. However, among Fe-minerals, Fe(OH)2 precipitation and pyrite dissolution were noticeably large compared to troilite, FeSO4, and siderite. Therefore, it is essential to analyze precipitation or dissolution for each Fe-mineral, individually. Meanwhile, in dissolving process of pyrite, sulfate ions were released differently depending on the content of pyrite. Here, the magnitude of the generated sulfate ion was limited at certain level of pyrite content. Thus, it is necessary to pay attention for determining the concentration of sulfate ion in designing the composition of injection water. Ultimately, in the investigation of the efficiency of oil production, it was found that the oil production was enhanced due to an additional sulfate ion generated from FeS2 dissolution.

scholarly journals Modelling of continuous surfactant flooding application for marginal oilfields: a case study of Bentiu reservoir

2021 ◽  
Author(s):  
Azza Hashim Abbas ◽  
Hani Hago Elhag ◽  
Wan Rosli Wan Sulaiman ◽  
Afeez Gbadamosi ◽  
Peyman Pourafshary ◽  
...  
Keyword(s):  
Numerical Simulation ◽  
Oil Recovery ◽  
Oil Production ◽  
Simulation Modelling ◽  
Sensitivity Study ◽  
Surfactant Flooding ◽  
Oil Saturation ◽  
Proxy Model ◽  
Proven Method

AbstractEnhanced oil recovery (EOR) is a proven method to increase oil production from the brown fields. One of the efficient EOR methods is injecting surfactants to release the trapped oil. However, few unconsolidated behaviours were observed in both field and laboratory practice. In this study, a new framework was adapted to evaluate the continuous surfactant flooding (CSF) in Bentiu reservoir. The study aims to quantify the expected range of the oil production, recovery factor and residual oil saturation (Sor). The motivation came from the oil demand in Sudan and the insufficient cores. The framework adopted in the study includes numerical simulation modelling and proxy modelling. Thirty-six cores obtained from the field were revised and grouped into five main groups. The interfacial tension (IFT) data were obtained experimentally. The CSF sensitivity study was developed by combining different experimental design sets to generate the proxy model. The CSF numerical simulation results showed around 30% additional oil recovery compared to waterflooding and approximately oil production between (20–30) cm3. The generated proxy model extrapolated the results with concerning lower ranges of the input and showed an average P50 of oil production and recovery of 74% and 17 cm3, respectively. Overall, the performance of CSF remained beneficial in vast range of input. Moreover, the generated proxy model gave an insight on the complexity of the interrelationship between the input factors and the observants with a qualitative prospective factors. Yet, the results confirmed the applicability of CSF in core scale with an insight for field scale application.

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%.

scholarly journals Half a century of continuous oil production by in-situ combustion in Romania – case study Suplacu de Barcau field

2021 ◽  
Vol 343 ◽  
pp. 09009
Author(s):  
Gheorghe Branoiu ◽  
Florinel Dinu ◽  
Maria Stoicescu ◽  
Iuliana Ghetiu ◽  
Doru Stoianovici
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Oil Production ◽  
Oil Field ◽  
Oil Reservoir ◽  
In Situ Combustion ◽  
Cyclic Steam Stimulation ◽  
The Impact ◽  
Steam Stimulation

Thermal oil recovery is a special technique belonging to Enhanced Oil Recovery (EOR) methods and includes steam flooding, cyclic steam stimulation, and in-situ combustion (fire flooding) applied especially in the heavy oil reservoirs. Starting 1970 in-situ combustion (ISC) process has been successfully applied continuously in the Suplacu de Barcau oil field, currently this one representing the most important reservoir operated by ISC in the world. Suplacu de Barcau field is a shallow clastic Pliocene, heavy oil reservoir, located in the North-Western Romania and geologically belonging to Eastern Pannonian Basin. The ISC process are operated using a linear combustion front propagated downstructure. The maximum oil production was recorded in 1985 when the total air injection rate has reached maximum values. Cyclic steam stimulation has been continuously applied as support for the ISC process and it had a significant contribution in the oil production rates. Nowadays the oil recovery factor it’s over 55 percent but significant potential has left. In the paper are presented the important moments in the life-time production of the oil field, such as production history, monitoring of the combustion process, technical challenges and their solving solutions, and scientific achievements revealed by many studies performed on the impact of the ISC process in the oil reservoir.

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.

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