Application of Enhanced RPB Tool in Malaysian Oilfields for Gas Injection RF Benchmarking and Analogue Identification

2021 ◽  
Author(s):  
Ankaj Kumar Sinha ◽  
Shlok Jalan ◽  
Rakesh Ranjan ◽  
Rahim Masoudi
Keyword(s):  
Development Strategy ◽  
Phase Ii ◽  
Asset Management ◽  
Gas Injection ◽  
Water Injection ◽  
Development Plan ◽  
Recovery Factor ◽  
Recovery Processes ◽  
Recovery Potential ◽  
Secondary Recovery

Abstract Identification of an optimal field development plan is one of the most critical decisions for oil asset management. In the new norm of low oil prices, this assumes even more relevance for mature oilfields to maximize overall recovery. In greenfield developments and oilfields in early production life, the absence of a clear roadmap detailing their future development strategy can often lead to missed opportunities and sub-optimal recovery. To bridge this gap, Petroliam Nasional Berhad (PETRONAS) began identifying new improved oil recovery (IOR) opportunities in mature fields and started formulating an optimal development plan in greenfields. In 2019, PETRONAS embarked on implementing the Reservoir Performance Benchmarking (RPB) tool to evaluate reservoir recovery potential with waterflood. This paper will detail the Phase-II development of this data-analytics based tool which focuses on delivering a comprehensive roadmap, which includes other recovery mechanisms such as gas injection and reservoir under primary recovery. Phase-I of RPB tool (SPE-196443) had considered water injection as a key secondary recovery process to evaluate the benchmark recovery factor for an oil reservoir. As part of Phase-II development, this has been further enhanced to evaluate field recovery potential and provide the benchmark recovery factor for primary recovery and gas injection processes. For fields under primary recovery, a comparative assessment between volumetric depletion and varying aquifer/gas-cap drive is conducted to ascertain the recovery potential. Assessment for incremental secondary recovery gains considers both gas injection and water injection scenarios in the enhanced benchmarking methodology. In addition, the benchmarking calibration methodology has also focused on incorporating additional reservoir parameters specific to each of the recovery processes for overall estimation of the benchmark value. The benchmarking tool also identifies analogue reservoirs to enable replication of best development practices and optimization of the development strategy. With the deployment of this enhanced RPB tool, a comprehensive 5-year roadmap has been developed to improve Malaysian oilfields recovery. This has enabled PETRONAS to augment its resource funnel inventory, streamline its opportunity ranking and integrate project maturation tracking with existing digital platforms of its entire portfolio. This is a novel benchmarking tool to assess reservoir potential recovery factor for primary and secondary recovery processes (both water and gas injection) along with analogue identification for replication of best development practices

Incorporating Uncertainties in Well-Count Optimization With Experimental Design for the Deepwater Agbami Field

2005 ◽  
Vol 8 (06) ◽  
pp. 548-560 ◽  
Author(s):  
Gene M. Narahara ◽  
John J. Spokes ◽  
David D. Brennan ◽  
Gregor Maxwell ◽  
Michael S. Bast
Keyword(s):  
Experimental Design ◽  
Development Process ◽  
Gas Injection ◽  
Water Injection ◽  
Development Plan ◽  
Field Development ◽  
Wide Range ◽  
Geologic Model ◽  
Reservoir Description ◽  
Phase Phase

Summary This paper describes a methodology for incorporating uncertainties in the optimization of well count for the deepwater Agbami field development. The lack of substantial reservoir-description data is common in many deepwater discoveries. Therefore, the development plan must be optimized and proven to berobust for a wide range of uncertainties. In the Agbami project, the design of experiments, or experimental design (ED) technique, was incorporated to optimize the well count across a wide range of subsurface uncertainties. The lack of substantial reservoir-description data is common for many deepwater discoveries. In the Agbami project, the uncertainty in oil in place was significant (greater than a factor of 2). This uncertainty was captured in a range of earth (geologic) models. Additional uncertainty variables, including permeability, fault seals, and injection conformance, were studied concurrently. Multiple well-count development plans (high, mid, and low) were developed and used as a variable in ED. The ED technique allowed multiple well counts to be tested quickly against multiple geologic models. With the net present value (NPV) calculated for each case, not only was the well count for the overall highest NPV determined, but discrete testing of each geologic model determined the optimum well count for each model. The process allowed for testing the robustness of any well count vs. any uncertainty (or set of uncertainties). A method was demonstrated quantifying the difference between perfect and imperfect knowledge of the reservoir description (geologic model) as it pertains to well locations. Introduction The Agbami structure is a northwest/southeast-trending four-way closure anticline and is located on the Niger delta front approximately 65 miles offshore Nigeria in the Gulf of Guinea (see the map in Fig. 1). The structure spans an area of 45,000 acres at spill point and is located in 4,800 ft of water. The Agbami No. 1 discovery well was drilled in late 1998. The appraisal program was completed in 2001 and included five wells and one sidetrack drilled on the structure, with each encountering oil pay. These five wells and a sidetrack penetrated an average of approximately 350 ft of oil. In this phase (Phase 3) of the development process, the key objectives are to construct a field-development plan and to obtain sanctioning. With drilling depths of up to 10,000 ft below mudline in 4,800 ft of water, well costs at Agbami will be at the high end of typical deepwater costs. Therefore, an important optimization parameter in the field development is the total well count. Agbami is typical of many deepwater developments in that the seismic is less than perfect and the appraisal well data are sparse relative to the area coverage. Therefore, subsurface uncertainty is high. In fact, the 5% probable oil in place is more than two times the oil in place at the 95% probability. As a result, the development process is challenged with determining the optimum well count for the field development across the wide range of subsurface uncertainty. Several key development decisions were determined in the previous phase(Phase 2) of the development process. These decisions were taken as givens in this study and are listed as follows:• The recommended pressure-maintenance scheme and gas-disposition strategy for the 17 million-year (MY) units is a combination of crestal gas injection with peripheral water injection.• The recommended pressure-maintenance scheme and gas-disposition strategy for the 14MY/16MY units is crestal gas injection only.• The facility design capacity recommendations are:- 250,000 stock-tank bbl per day (STB/D) oil.- 450,000 thousand cubic ft per day (Mcf/D) gas production.- 250,000 STB/D water production.- 450,000 STB/D liquid production.- 450,000 STB/D water injection.

Thermal Recovery Potential of Shallow Sandstone Reservoir for Optimized Unconventional Development Strategy in Kuwait

2012 ◽  
Author(s):  
Khalid Ahmad ◽  
Hasan Ferdous ◽  
Javier Llerena ◽  
Fatma Ahmad ◽  
Pradeep Chaudhary ◽  
...  
Keyword(s):  
Development Strategy ◽  
Thermal Recovery ◽  
Recovery Potential ◽  
Sandstone Reservoir

scholarly journals Biomarkers of Angiogenesis and Neuroplasticity as Promising Clinical Tools for Stroke Recovery Evaluation

2021 ◽  
Vol 22 (8) ◽  
pp. 3949
Author(s):  
Lidia Wlodarczyk ◽  
Rafal Szelenberger ◽  
Natalia Cichon ◽  
Joanna Saluk-Bijak ◽  
Michal Bijak ◽  
...  
Keyword(s):  
Clinical Practice ◽  
Stroke Recovery ◽  
Clinical Scales ◽  
Recovery Processes ◽  
Recovery Potential ◽  
Current State ◽  
Standard Procedures ◽  
Key Issues ◽  
Clinical Tools ◽  
Selection Of

Several key issues impact the clinical practice of stroke rehabilitation including a patient’s medical history, stroke experience, the potential for recovery, and the selection of the most effective type of therapy. Until clinicians have answers to these concerns, the treatment and rehabilitation are rather intuitive, with standard procedures carried out based on subjective estimations using clinical scales. Therefore, there is a need to find biomarkers that could predict brain recovery potential in stroke patients. This review aims to present the current state-of-the-art stroke recovery biomarkers that could be used in clinical practice. The revision of biochemical biomarkers has been developed based on stroke recovery processes: angiogenesis and neuroplasticity. This paper provides an overview of the biomarkers that are considered to be ready-to-use in clinical practice and others, considered as future tools. Furthermore, this review shows the utility of biomarkers in the development of the concept of personalized medicine. Enhancing brain neuroplasticity and rehabilitation facilitation are crucial concerns not only after stroke, but in all central nervous system diseases.

Solvent-Loaded Microspheres for Permeability Enhancement in Heavy Crude Oil Reservoirs

2021 ◽  
Author(s):  
Cengiz Yegin ◽  
Cenk Temizel ◽  
Mustafa Akbulut
Keyword(s):  
Energy Demand ◽  
Fossil Fuels ◽  
Analytical Techniques ◽  
Recovery Factor ◽  
Low Permeability ◽  
Sand Column ◽  
Permeability Enhancement ◽  
Recovery Potential ◽  
Novel Approach ◽  
Vis Spectroscopy

ABSTRACT With their abundancy and high-quality, it is predicted that fossil fuels will remain as the main resource that will meet the global energy demand in the several upcoming decades. Developments in hydrocarbon recovery technologies, both from conventional and unconventional reservoirs, have substantially contributed to the overall production levels in recent years. However, recovery factors obtained by using the current methods are still considered to be insufficient, and the companies have been looking for new materials and methods to enhance the efficiency and amount of recovery. One of the major issues related to low recovery factors is low permeability of reservoirs. Existence of blockages in pore throats and high level of heterogeneity lowers the mobility of hydrocarbons. In this study, we discuss development of an innovative material to be used as an additive in reservoir injection fluids to remove pore blockages in order to enhance the recovery levels. This additive material is made of pressure-sensitive microspheres loaded with solvents, which can (i) easily disperse in the injection fluid and travel to the low-permeability regions, (ii) break under pressure and confinement to release solvents, and (iii) remove blockages by targeting surroundings, especially asphalt-based particles and grains. This approach relies on the breakage of microcapsules in the confined region and release of the solvents to target blockages in porous media. In other words, the developed microspheres improve permeability of reservoirs as a result of pressure- and confinement-dependent breakage and release of solvents. Preparation of these microspheres was achieved by the encapsulation of solvent (toluene) emulsions in silica-based solid shells. Structure and stability of the solvent-loaded microspheres were examined using a variety of analytical techniques including UV-vis spectroscopy, optical microscopy, scanning electron microscope (SEM) and dynamic light scattering (DLS). It was found that the prepared microspheres possessed smooth surfaces with shell thicknesses in the range of 100-150 nm. Additionally, sand column tests were performed to evaluate the recovery potential of injection fluids in presence of solvent-loaded microspheres. It was shown that the use of solvent encapsulated in microspheres doubled the recovery factor of heavy oil compared to that of free solvent dispersed in the injection fluid. Such enhancement in the recovery factor was related to the release of solvents in localized areas, i.e., confined regions, as a consequence of breakage of microspheres. This novel approach of delivering solvents to low-permeability regions provides a significant driving force to eliminate pore blockages to facilitate mobilization of hydrocarbons trapped in confined spaces.

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.

scholarly journals Investigation of Oil Recovery in Fractured Carbonate Rock by

2016 ◽  
Vol 6 (1) ◽  
pp. 14
Author(s):  
H. Karimaie ◽  
O. Torsæter
Keyword(s):  
Oil Recovery ◽  
Gas Injection ◽  
Water Injection ◽  
Co2 Injection ◽  
Recovery Method ◽  
Asmari Limestone ◽  
Fractured Carbonate ◽  
Efficient Recovery ◽  
Live Oil ◽  
Non Equilibrium

The purpose of the three experiments described in this paper is to investigate the efficiency of secondary andtertiary gas injection in fractured carbonate reservoirs, focusing on the effect of equilibrium gas,re-pressurization and non-equilibrium gas. A weakly water-wet sample from Asmari limestone which is the mainoil producing formation in Iran, was placed vertically in a specially designed core holder surrounded withfracture. The unique feature of the apparatus used in the experiment, is the capability of initializing the samplewith live oil to obtain a homogeneous saturation and create the fracture around it by using a special alloy whichis easily meltable. After initializing the sample, the alloy can be drained from the bottom of the modified coreholder and create the fracture which is filled with live oil and surrounded the sample. Pressure and temperaturewere selected in the experiments to give proper interfacial tensions which have been measured experimentally.Series of secondary and tertiary gas injection were carried out using equilibrium and non-equilibrium gas.Experiments have been performed at different pressures and effect of reduction of interfacial tension werechecked by re-pressurization process. The experiments showed little oil recovery due to water injection whilesignificant amount of oil has been produced due to equilibrium gas injection and re-pressurization. Results alsoreveal that CO2 injection is a very efficient recovery method while injection of C1 can also improve the oilrecovery.

scholarly journals Polymer gels for controlling water thief zones in injection wells

2012 ◽  
Vol 5 (1) ◽  
pp. 37-44 ◽  
Author(s):  
Gustavo-Adolfo Maya-Toro ◽  
Rubén-Hernán Castro-García ◽  
Zarith del Pilar Pachón-Contreras. ◽  
Jose-Francisco Zapata-Arango
Keyword(s):  
Oil Recovery ◽  
Water Injection ◽  
Injection Wells ◽  
Recovery Processes ◽  
Injection Water ◽  
Secondary Oil Recovery ◽  
High Concentrations ◽  
Low Efficiency ◽  
Hydrolyzed Polyacrylamide ◽  
Positive Results

Oil recovery by water injection is the most extended technology in the world for additional recovery, however, formation heterogeneity can turn it into highly inefficient and expensive by channeling injected water. This work presents a chemical option that allows controlling the channeling of important amounts of injection water in specific layers, or portions of layers, which is the main explanation for low efficiency in many secondary oil recovery processes. The core of the stages presented here is using partially hydrolyzed polyacrylamide (HPAM) cross linked with a metallic ion (Cr+3), which, at high concentrations in the injection water (5000 – 20000 ppm), generates a rigid gel in the reservoir that forces the injected water to enter into the formation through upswept zones. The use of the stages presented here is a process that involves from experimental evaluation for the specific reservoir to the field monitoring, and going through a strict control during the well intervention, being this last step an innovation for this kind of treatments. This paper presents field cases that show positive results, besides the details of design, application and monitoring.

Improving Water Injectivity Through Lateral Radial Drilling into the Reservoir

2021 ◽  
Author(s):  
Effiong Essien ◽  
Uchenna Onyejiaka ◽  
Stanley Onwukwe ◽  
Nnaemeka Uwaezuoke
Keyword(s):  
Oil Recovery ◽  
Damage Zone ◽  
Water Injection ◽  
Progressive Increase ◽  
Recovery Factor ◽  
Water Flooding ◽  
Increase With Increase ◽  
Drilling Technology ◽  
Water Cut ◽  
Radial Drilling

Abstract Poor formation permeability and near well bore damage may limit water injectivity into the reservoir in a water injection project. This paper seeks to evaluate the effect of radial drilling technique on water injectivity and oil recovery in water flooding operation. Radial drilling technology utilizes hydraulic energy to create lateral perpendicular small holes through the casing into the reservoir. The holes may extend to 100 m (330 ft) into the reservoir to access fresh formations beyond the near wellbore, and damage zone. A black oil simulator (Eclipse 100) was used to modeling a lateral radial drill from the borehole into the reservoir, and that of a conventional perforation of the wellbore respectively. A simulation study was carried out using various presumed radial drill configurations in determining injectivity index, displacement efficiencies, recovery factor and water cut of the process. The determined results were further compared with that of the conventional perforation process case respectively. The results show a significant improvement in water injectivity in radial drill case with the increasing length and number of radials as compared to the conventional wellbore perforation case. The determined Recovery factor shows a progressive increase with increase in the numbers of radials drilled, irrespective of the radial length. However, it was observed that, the more the number and length of the radials drilled in to the reservoir, the higher the water cut from producer wells. Radial Drilling Technology, therefore, has a promising potential to improving water injectivity into the reservoir and thereby optimizing oil recovery in a water flooding operation.

ORGANIZATION OF TERRITORIAL DEVELOPMENT PLANNING IN THE CONTEXT OF DECENTRALIZATION OF PUBLIC ADMINISTRATION: COMBINATION OF INTEGRATED, SPATIAL AND ECONOMIC APPROACHES

2021 ◽  
Vol 2021 (11) ◽  
pp. 23-38
Author(s):  
Hanna OLEKSYUK ◽  
◽  
Stepan KUIBIDA ◽  
Nataliya LYSYAK ◽  
Nazariy POPADYNETS ◽  
...  
Keyword(s):  
Community Development ◽  
Development Strategy ◽  
Time Perspective ◽  
Local Level ◽  
Spatial Development ◽  
Development Planning ◽  
Economic Planning ◽  
Development Plan ◽  
Territorial Development ◽  
Integrated Development

The complex spatial and economic planning of development of territorial communities on the conditions of their combination which will promote effective management of territories and ensure integrated sustainable development of territories for the future generations is investigated. The peculiarities of the legislation on new provisions of spatial and economic planning of territorial communities are covered, the main approaches to the development of the Comprehensive Spatial Development Plan of the Territory of Territorial Community, the Concept of Integrated Development of the Territorial Community and the Territorial Community Development Strategy are compared. The scheme of connections of elements at formation of the specified Comprehensive Plan, Concept and Strategy is constructed. The legislative level acceptance of the provisions on joint approaches to the formation of key documents of spatial and economic planning of territorial communities, the unity of land management documentation and urban planning documentation at the local level is established. It is shown that the Concept of Integrated Development of the Territorial Community is the basis and a certain “bridge” for combining the principles and indicators in the formation of the Comprehensive Spatial Development Plan of the Territory of Territorial Community and the Territorial Community Development Strategy. The formation of the Concept is proposed to be carried out on the basis of preliminary conceptual and structural modeling of endogenous potential of territorial communities that will establish the features of the existing potential by its elements (natural resources, production and infrastructure, labor, socio-cultural, etc.) that have a place in each community depending on its specific and general characteristics. It is proved that the modeling of the potential of territorial communities is carried out on the basis of establishing, integrating, uniting, combining, interpenetrating of connections and dependencies in the present time and their interpretation (design, transfer) to the appropriate time perspective (five, ten and more years).

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