Multilateral / Intelligent Wells Improve Development of Heavy Oil Field - A Case History

2004 ◽  
Author(s):  
Pascal Rump ◽  
Ronjoy Bairagi ◽  
John Fraser ◽  
Klaus Mueller
Keyword(s):  
Heavy Oil ◽  
Case History ◽  
Oil Field ◽  
Intelligent Wells

Expierence of development of the Liael area of Yaregskoye heavy oil field using different technologies

2019 ◽  
Vol 10 ◽  
pp. 62-67
Author(s):  
S.M. Durkin ◽  
◽  
I.N. Menshikova ◽  
L.M. Rusin ◽  
A.A. Terentiev ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Oil Field

Application of Polymer Flooding in the Revitalization of a Mature Heavy Oil Field

2021 ◽  
pp. 108695
Author(s):  
L.F. Lamas ◽  
V.E. Botechia ◽  
D.J. Schiozer ◽  
M.L. Rocha ◽  
M. Delshad
Keyword(s):  
Heavy Oil ◽  
Polymer Flooding ◽  
Oil Field

Application of CSS to Develop a Thick Heavy Oil Field in South Oman

2014 ◽  
Author(s):  
Mohammed Omar Al-Manhali ◽  
Mohammed Al-rawahi ◽  
Suleiman Mohammed Al-hinai ◽  
Abdullah Alwazeer ◽  
Simon John Brissenden ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Oil Field

Review of Research on Interlayer SAGD in Domestic and Foreign

2014 ◽  
Vol 644-650 ◽  
pp. 5142-5145 ◽  
Author(s):  
Peng Luo
Keyword(s):  
Heavy Oil ◽  
Development Process ◽  
Basic Research ◽  
Technical Support ◽  
Oil Field ◽  
Oil Reservoir ◽  
Steam Chamber ◽  
Heavy Oil Reservoir

China is rich in resources of heavy oil.But some oilfield heavy oil reservoir in the development process will encounter interlining, affecting the development effect. In the process of SAGD to carry out the basic research of reservoir interlayer is helpful to identify the basic attributes of reservoir in the interlayer. The interlayer of SAGD development process is helpful to find the study focus and direction of development. Steam chamber breakthrough research achievements of interlining research abroad, summarizes the steam chamber breakthrough interlining, provide technical support for the oil field SAGD breakthrough interlining, it is of great significance for promoting SAGD efficient development.

Application and Exploration of Early In-Situ Combustion Huff-and-Puff Technology in a Deep Undisturbed Reservoir with Extra Heavy Oil

2021 ◽  
pp. 1-13
Author(s):  
Wang Xiaoyan ◽  
Zhao Jian ◽  
Yin Qingguo ◽  
Cao Bao ◽  
Zhang Yang ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Heavy Oil ◽  
Gas Injection ◽  
Thermal Recovery ◽  
Oil Field ◽  
Pilot Test ◽  
In Situ Combustion ◽  
Coiled Tubing

Summary Achieving effective results using conventional thermal recovery technology is challenging in the deep undisturbed reservoir with extra-heavy oil in the LKQ oil field. Therefore, in this study, a novel approach based on in-situ combustion huff-and-puff technology is proposed. Through physical and numerical simulations of the reservoir, the oil recovery mechanism and key injection and production parameters of early-stage ultraheavy oil were investigated, and a series of key engineering supporting technologies were developed that were confirmed to be feasible via a pilot test. The results revealed that the ultraheavy oil in the LKQ oil field could achieve oxidation combustion under a high ignition temperature of greater than 450°C, where in-situ cracking and upgrading could occur, leading to greatly decreased viscosity of ultraheavy oil and significantly improved mobility. Moreover, it could achieve higher extra-heavy-oil production combined with the energy supplement of flue gas injection. The reasonable cycles of in-situ combustion huff and puff were five cycles, with the first cycle of gas injection of 300 000 m3 and the gas injection volume per cycle increasing in turn. It was predicted that the incremental oil production of a single well would be 500 t in one cycle. In addition, the supporting technologies were developed, such as a coiled-tubing electric ignition system, an integrated temperature and pressure monitoring system in coiled tubing, anticorrosion cementing and completion technology with high-temperature and high-pressure thermal recovery, and anticorrosion injection-production integrated lifting technology. The proposed method was applied to a pilot test in the YS3 well in the LKQ oil field. The high-pressure ignition was achieved in the 2200-m-deep well using the coiled-tubing electric igniter. The maximum temperature tolerance of the integrated monitoring system in coiled tubing reached up to 1200°C, which provided the functions of distributed temperature and multipoint pressure measurement in the entire wellbore. The combination of 13Cr-P110 casing and titanium alloy tubing effectively reduced the high-temperature and high-pressure oxygen corrosion of the wellbore. The successful field test of the comprehensive supporting engineering technologies presents a new approach for effective production in deep extra-heavy-oil reservoirs.

The Challenges of Developing a Deep Offshore Heavy-Oil Field in Campos Basin

2007 ◽  
Author(s):  
Fernando Pacifico Figueiredo ◽  
Celso Cesar M. Branco ◽  
Fabio Prais ◽  
Marcelo Curzio Salomao ◽  
Cristina Cledia Mezzomo
Keyword(s):  
Heavy Oil ◽  
Oil Field ◽  
Campos Basin

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.

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