Designing a Robust Surfactant Based SP Formulation in High Clay Containing Low Permeability Indonesian Field

2021 ◽  
Author(s):  
Andi Bachtiar ◽  
Octaviani Octaviani ◽  
Iqbal Fauzi ◽  
Sayak Roy ◽  
Roberto Company ◽  
...  
Keyword(s):  
Oil Recovery ◽  
High Throughput Screening ◽  
Lessons Learned ◽  
Oil Field ◽  
Reservoir Rock ◽  
Low Permeability ◽  
Screening Experiments ◽  
Main Challenge ◽  
Chemical Eor ◽  
Rock Characterization

Abstract Indonesian oil and gas reserves have been depleting since 2000 with no major addition of new oil reserves. Therefore, it is imperative to increase national oil production by optimizing the mature fields through the implementation of successful EOR technology. Out of this approach, a comprehensive study has been carried out on the targeted field by exploring the potential of surfactant-polymer (SP) flooding. This article describes the formulation design, optimization, and lessons learned leading up to a successful and robust chemical EOR formulation designing for a low permeability and high clay (>20% clay) containing Indonesian oil field. The detailed workflow consists of analysis of fluid and rock characterization, tailor-made SP formulation designing, optimization and coreflood validation as presented in previous papers (Bazin, 2010). A series of surfactant formulation were designed and screened synthetically through a validated High Throughput Screening (HTS) methodology using a robotic platform combined with microfluidic tools for ultra-low interfacial tension (IFT), solubility, compatibility with brine and polymer. Rock mineralogy has played an important role due to heterogeneity and very high (>20%) clay content. Surfactants retention through adsorption on reservoir rocks was the main constraint to achieve high performance and economical chemical EOR for the targeted field. Specific strategies by optimizing the surfactant formulation and by injecting adsorption inhibitor thus needed to be deployed to mitigate high surfactant retention. The detailed laboratory screening experiments conclude that the designed robust SP formulation is able to induce ultra-low IFT, excellent solubility and compatibility at the injection water salinity. The dynamic coreflood experiment using reservoir rock shows high incremental oil recovery (>60% ROIP) in short SP slug injection. As expected from the nature of rock, adsorption was the main challenge encountered during the course of this study, which resulted in a very promising oil recovery in economically realistic conditions.

Laboratory studies of oil-washing characteristics of surfactants in the pore space of reservoir rocks

2021 ◽  
pp. 86-98
Author(s):  
V. Yu. Ogoreltsev ◽  
S. A. Leontiev ◽  
A. S. Drozdov
Keyword(s):  
Oil Recovery ◽  
Pore Space ◽  
Oil Field ◽  
Oil Fields ◽  
Molecular Surface ◽  
Laboratory Studies ◽  
Reservoir Rocks ◽  
Technological Efficiency ◽  
Chemical Eor ◽  
Physical And Chemical

When developing hard-to-recover reserves of oil fields, methods of enhanced oil recovery, used from chemical ones, are massively used. To establish the actual oil-washing characteristics of surfactant grades accepted for testing in the pore space of oil-containing reservoir rocks, a set of laboratory studies was carried out, including the study of molecular-surface properties upon contact of oil from the BS10 formation of the West Surgutskoye field and model water types with the addition of surfactants of various concentrations, as well as filtration tests of surfactant technology compositions on core models of the VK1 reservoir of the Rogozhnikovskoye oil field. On the basis of the performed laboratory studies of rocks, it has been established that conducting pilot operations with the use of Neonol RHP-20 will lead to higher technological efficiency than from the currently used at the company's fields in the compositions of the technologies of physical and chemical EOR Neonol BS-1 and proposed for application of Neftenol VKS, Aldinol-50 and Betanol.

Experimental Design and Evaluation of Surfactant Polymer for a Heavy Oil Field in South of Sultanate of Oman

2021 ◽  
Author(s):  
Ali Reham Al-Jabri ◽  
Rouhollah Farajzadeh ◽  
Abdullah Alkindi ◽  
Rifaat Al-Mjeni ◽  
David Rousseau ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
History Matching ◽  
Oil Field ◽  
Reservoir Rock ◽  
Sultanate Of Oman ◽  
Industrial Chemicals ◽  
Oil Viscosity ◽  
Injection Strategy ◽  
Operational Conditions

Abstract Heavy oil reservoirs remain challenging for surfactant-based EOR. In particular, selecting fine-tuned and cost effective chemical formulations requires extensive laboratory work and a solid methodology. This paper reports a laboratory feasibility study, aiming at designing a surfactant-polymer pilot for a heavy oil field with an oil viscosity of ~500cP in the South of Sultanate of Oman, where polymer flooding has already been successfully trialed. A major driver was to design a simple chemical EOR method, to minimize the risk of operational issues (e.g. scaling) and ensure smooth logistics on the field. To that end, a dedicated alkaline-free and solvent-free surfactant polymer (SP) formulation has been designed, with its sole three components, polymer, surfactant and co-surfactant, being readily available industrial chemicals. This part of the work has been reported in a previous paper. A comprehensive set of oil recovery coreflood tests has then been carried out with two objectives: validate the intrinsic performances of the SP formulation in terms of residual oil mobilization and establish an optimal injection strategy to maximize oil recovery with minimal surfactant dosage. The 10 coreflood tests performed involved: Bentheimer sandstone, for baseline assessments on large plugs with minimized experimental uncertainties; homogeneous artificial sand and clays granular packs built to have representative mineralogical composition, for tuning of the injection parameters; native reservoir rock plugs, unstacked in order to avoid any bias, to validate the injection strategy in fully representative conditions. All surfactant injections were performed after long polymer injections, to mimic the operational conditions in the field. Under injection of "infinite" slugs of the SP formulation, all tests have led to tertiary recoveries of more than 88% of the remaining oil after waterflood with final oil saturations of less than 5%. When short slugs of SP formulation were injected, tertiary recoveries were larger than 70% ROIP with final oil saturations less than 10%. The final optimized test on a reservoir rock plug, which was selected after an extensive review of the petrophysical and mineralogical properties of the available reservoir cores, led to a tertiary recovery of 90% ROIP with a final oil saturation of 2%, after injection of 0.35 PV of SP formulation at 6 g/L total surfactant concentration, with surfactant losses of 0.14 mg-surfactant/g(rock). Further optimization will allow accelerating oil bank arrival and reducing the large PV of chase polymer needed to mobilize the liberated oil. An additional part of the work consisted in generating the parameters needed for reservoir scale simulation. This required dedicated laboratory assays and history matching simulations of which the results are presented and discussed. These outcomes validate, at lab scale, the feasibility of a surfactant polymer process for the heavy oil field investigated. As there has been no published field test of SP injection in heavy oil, this work may also open the way to a new range of field applications.

Implementation of Chemical EOR as Huff and Puff to Improve Oil Recovery for Heavy Oil Field by Chemical Treatment SEMAR Cast Study Bamboo Oil Field

2016 ◽  
Author(s):  
Ali Farog ◽  
Haytham A.Mustafa ◽  
Enas Mukhtar ◽  
Husham Elblaoula ◽  
Badreldin A. Yassin ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Chemical Treatment ◽  
Oil Field ◽  
Chemical Eor

scholarly journals RESEARCH OF THE MECHANISM OF OIL RECOVERY FROM HYDROCARBON DEPOSITS WITH LOW PERMEABILITY RESERVOIRS

2020 ◽  
Vol 17 (34) ◽  
pp. 892-904
Author(s):  
Zinon A KUANGALIEV ◽  
Gulsin S DOSKASIYEVA ◽  
Altynbek S MARDANOV
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
New Technologies ◽  
High Viscosity ◽  
Economic Feasibility ◽  
Oil Field ◽  
Low Permeability ◽  
Low Grade ◽  
Oil Reserves ◽  
Low Permeability Reservoirs

The main part of Russia's hard-to-recover reserves is 73% for low-grade and carbonate reservoirs, 12% for high-viscosity oil, about 15% of extensive sub-gas zones of oil and gas deposits and 7% of reservoirs lying at great depths. The development of such stocks with the usage of traditional technologies is economically inefficient. It requires the application of new technologies for their development and fundamentally new approaches to design, taking into account the features of extraction of hard-to-extract reserves (HtER). The purpose of this research is to find ways to improve the performance of low-permeability reservoirs. To accomplish this task, the Novobogatinsk South-Eastern Oil Field has been taken as an example and described. The necessary properties of production facilities in the field are highlighted, along with economic feasibility and technological efficiency. The reserves involved in the development are determined and, thanks to the knowledge of the geological oil reserves of the deposits, the potential oil recovery factor is calculated with the existing development technology. As a result of the research, development options were worked out with the results of the calculation of design indicators for the field as a whole. The comparison of oil recovery schedules and ORI, as well as the layout of wells, have been presented. As a result of the study, a description of 3 options for the development of design indicators for the field as a whole is given. The figures show oil production graphs, as well as location patterns. The authors of the study conclude which of the recommended development options can help extract maximum oil reserves.

LONG-TERM MONITORING OF SUBMERGED OIL IN THE GULF OF MEXICO FOLLOWING THE T/B DBL 152 INCIDENT

2008 ◽  
Vol 2008 (1) ◽  
pp. 275-278 ◽  
Author(s):  
Chris Pfeifer ◽  
Erik Brzozowski ◽  
Ralph Markarian ◽  
Ramsey Redman
Keyword(s):  
Gulf Of Mexico ◽  
Oil Recovery ◽  
Monitoring Program ◽  
Fate And Transport ◽  
Lessons Learned ◽  
Oil Field ◽  
Specific Information ◽  
Long Term Monitoring ◽  
Term Monitoring

ABSTRACT In November 2005, approximately 1.9 million gallons of Group V slurry oil was released in the western Gulf of Mexico following the allision of the double-hulled tank barge DBL 152 with the submerged remains of a pipeline service platform that collapsed during Hurricane Rita. The released oil was denser than seawater and sank to the bottom. After approximately six weeks of intermittent cleanup using diver-direct pumping, submerged oil recovery operations were suspended by the Unified Command based on the high percentage (50%) of weather-related downtime, as well as indications that recoverable accumulations of oil were dispersing naturally, which further reduced the feasibility of cleanup. However, the responsible party was required to develop and implement a long-term monitoring program (LTMP) to track the fate and transport of the sunken oil and determine the potential need for resuming oil recovery operations once more favorable weather patterns returned in the spring. This paper will present an overview of the approach, methods and results of the long-term monitoring efforts performed over a 14-month period following the incident. Major objectives of the LTMP included tracking the movement and fate of non-recovered submerged oil to assess its extent and continued dispersion; providing advance warning of potential impacts to Gulf Coast shorelines and other sensitive areas; and documenting changes in the oil'S chemical composition and physical properties through time due to weathering processes. Major findings of the LTMP include the dissipation of the main submerged oil field over the course of several months and the discovery, differential behavior and eventual dissipation of a discrete high-concentration oil patch found several miles from the incident location. The importance of long-term monitoring data in the decision-making process to determine both the need for and feasibility of resuming submerged oil recovery operations will be emphasized. Information on the fate and transport characteristics of submerged oil and the adaptation of monitoring techniques to address evolving needs will also be addressed. Both the incident-specific information and the practical lessons-learned are intended to benefit those who may be faced with monitoring submerged oil spills in the future.

scholarly journals A Data Mining Perspective on the Confluent Ions` Effect for Target Functionality

2021 ◽  
Vol 2 (3) ◽  
pp. 202-215
Author(s):  
Babak Fazelabdolabadi ◽  
Mostafa Montazeri ◽  
Peyman Pourafshary
Keyword(s):  
Data Mining ◽  
Oil Recovery ◽  
Recursive Partitioning ◽  
Oil Field ◽  
Reservoir Rock ◽  
Single Type ◽  
Relative Significance ◽  
New Perspective ◽  
Permeability Impairment ◽  
Ion Species

The production of hydrocarbon resources at an oil field is concomitant with challenges with respect to the formation of scale inside the reservoir rock – intricately impairing its permeability and hindering the flow. Historically, the effect of ions is attributed to the undergone phenomenon; nevertheless, there exists a great deal of ambiguity about its relative significance compared to other factors, or the effectiveness as per the ion type. The present work applies a data mining strategy to unveil the influencing hierarchy of the parameters involved in driving the process within major rock categories – sandstone and carbonate – to regulate a target functionality. The functionalities considered evolve around maximizing the oil recovery, minimizing permeability impairment/ scale damage. A pool of experimental as well as field data was used for this sake, accumulating the bulk of the available literature data. The methods used for data analysis in the present work included the Bayesian Network, Random Forest, Deep Neural Network, as well as Recursive Partitioning. The results indicate a rolling importance for different ion species - altering under each functionality – which is not ranked as the most influential parameter in either case. For the oil recovery target, our results quantify a distinction between the source of ion of a single type, in terms of its influencing rank in the process. This latter deduction is the first proposal of its kind – suggesting a new perspective for research. Moreover, the machine learning methodology was found to be capable of reliably capturing the data – evidenced by the minimal errors in the bootstrapped results. Doi: 10.28991/HIJ-2021-02-03-05 Full Text: PDF

Role of chemical additives and their rheological properties in enhanced oil recovery

2020 ◽  
Vol 36 (7) ◽  
pp. 789-830 ◽  
Author(s):  
Jinesh Machale ◽  
Subrata Kumar Majumder ◽  
Pallab Ghosh ◽  
Tushar Kanti Sen
Keyword(s):  
Rheological Properties ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Field ◽  
Water Soluble ◽  
Attractive Alternative ◽  
Chemical Additives ◽  
Sweep Efficiency ◽  
Chemical Eor ◽  
Natural Surfactants

AbstractA significant amount of oil (i.e. 60–70%) remains trapped in reservoirs after the conventional primary and secondary methods of oil recovery. Enhanced oil recovery (EOR) methods are therefore necessary to recover the major fraction of unrecovered trapped oil from reservoirs to meet the present-day energy demands. The chemical EOR method is one of the promising methods where various chemical additives, such as alkalis, surfactants, polymer, and the combination of all alkali–surfactant–polymer (ASP) or surfactant–polymer (SP) solutions, are injected into the reservoir to improve the displacement and sweep efficiency. Every oil field has different conditions, which imposes new challenges toward alternative but more effective EOR techniques. Among such attractive alternative additives are polymeric surfactants, natural surfactants, nanoparticles, and self-assembled polymer systems for EOR. In this paper, water-soluble chemical additives such as alkalis, surfactants, polymer, and ASP or SP solution for chemical EOR are highlighted. This review also discusses the concepts and techniques related to the chemical methods of EOR, and highlights the rheological properties of the chemicals involved in the efficiency of EOR methods.

Field Applications of a Semianalytical Model of Multilateral Wells in Multilayer Reservoirs

2010 ◽  
Vol 13 (06) ◽  
pp. 861-872 ◽  
Author(s):  
Yan Pan ◽  
Medhat M. Kamal ◽  
Jitendra Kikani
Keyword(s):  
Constant Pressure ◽  
Lessons Learned ◽  
Oil Field ◽  
Production Performance ◽  
Well Performance ◽  
Unknown Parameters ◽  
Reservoir Properties ◽  
Multilayer Systems ◽  
Main Challenge ◽  
Transient Data

Summary Advanced drilling technology has been widely and successfully applied to construct multilateral wells in reservoirs. This paper presents several field applications of a generalized semianalytical segmented model accounting for multilateral-well systems in commingled layered reservoirs. Cases include a heavy-oil field, Al Rayyan oil field offshore Qatar, and Dos Cuadras field offshore California. The model can predict the production performance under either constant-rate or constant-pressure conditions of a well system with any number of arbitrarily oriented laterals of any length and nonuniform formation damage. The reservoir layers, with different porosities, anisotropic permeabilities, and drainage areas, are noncommunicating except through the wellbore. The solution is valid for large reservoirs and when no-flow or constant-pressure boundaries affect the pressure behavior. Results of applying this method in the field cases showed that the model enabled us to predict multilateral-well performance, to obtain information about reservoir connectivity, and to estimate well and reservoir properties in a multilayer system. Uncertainty caused by the large number of unknown parameters in such a complex system represents the main challenge in using this method. It is recommended to use other means together with pressure transient data to reduce the uncertainty. The presented model and the lessons learned from the field applications provide engineers with a tool enabling the use of transient data collected from multilateral wells in multilayer systems for reservoir characterization and performance forecast.

scholarly journals Increased oil recovery from Halfdan chalk by flooding with CO2-enriched water: a laboratory experiment

1969 ◽  
Vol 17 ◽  
pp. 17-20
Author(s):  
Dan Olsen
Keyword(s):  
North America ◽  
Laboratory Experiment ◽  
North Sea ◽  
Oil Recovery ◽  
Oil Field ◽  
Geological Survey ◽  
Low Permeability ◽  
The North ◽  
The North Sea ◽  
Increased Oil Recovery

Injection of CO2 is a method that may increase the recovery of oil from Danish chalk reservoirs in the North Sea. The method is used elsewhere, particularly in North America, but has so far not been used in the North Sea and has nowhere been used for chalk reservoirs, and the performance of the method when used for North Sea chalk is therefore uncertain. A laboratory flooding experiment was conducted at the Geological Survey of Denmark and Greenland on a sample from the Nana-1X well of the Halfdan oil field in the Danish North Sea in order to test the efficiency of CO2-enriched water to produce additional oil from chalk. The sample is a low-permeability chalk from the Ekofisk Formation and represents rocks that are marginal to the Halfdan reservoir in an economical sense.

scholarly journals Analysis of Geologic CO2 Migration Pathways in Farnsworth Field, NW Anadarko Basin

Energies ◽  
2021 ◽  
Vol 14 (22) ◽  
pp. 7818
Author(s):  
Jolante van Wijk ◽  
Noah Hobbs ◽  
Peter Rose ◽  
Michael Mella ◽  
Gary Axen ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Petroleum System ◽  
Oil Field ◽  
Source Rocks ◽  
Reservoir Rock ◽  
Tracer Study ◽  
Deep Basin ◽  
Anadarko Basin ◽  
System Models ◽  
Migration Pathways

This study reports on analyses of natural, geologic CO2 migration paths in Farnsworth Oil Field, northern Texas, where CO2 was injected into the Pennsylvanian Morrow B reservoir as part of enhanced oil recovery and carbon sequestration efforts. We interpret 2D and 3D seismic reflection datasets of the study site, which is located on the western flank of the Anadarko basin, and compare our seismic interpretations with results from a tracer study. Petroleum system models are developed to understand the petroleum system and petroleum- and CO2-migration pathways. We find no evidence of seismically resolvable faults in Farnsworth Field, but interpret a karst structure, erosional structures, and incised valleys. These interpretations are compared with results of a Morrow B well-to-well tracer study that suggests that inter-well flow is up-dip or lateral. Southeastward fluid flow is inhibited by dip direction, thinning, and draping of the Morrow B reservoir over a deeper, eroded formation. Petroleum system models predict a deep basin-ward increase in temperature and maturation of the source rocks. In the northwestern Anadarko Basin, petroleum migration was generally up-dip with local exceptions; the Morrow B sandstone was likely charged by formations both below and overlying the reservoir rock. Based on this analysis, we conclude that CO2 escape in Farnsworth Field via geologic pathways such as tectonic faults is unlikely. Abandoned or aged wellbores remain a risk for CO2 escape from the reservoir formation and deserve further monitoring and research.

Sign in / Sign up

Export Citation Format

Share Document