Zonal Isolation Best Practices Helped in Maintaining Well Integrity and Achieved EOR Objectives in Highly Fractured Carbonate Reservoirs Case Study From Steam Injection Wells in Issaran Field in Egypt

2017 ◽  
Author(s):  
Sherif Mohamed ◽  
Ahmed Ali ◽  
Devesh Bhaisora ◽  
Wael Hassan ◽  
Emad Nabil ◽  
...  
Keyword(s):  
Best Practices ◽  
Steam Injection ◽  
Carbonate Reservoirs ◽  
Injection Wells ◽  
Well Integrity ◽  
Fractured Carbonate ◽  
Zonal Isolation

Block Model for Growth of Steam-Heated Zone in Oil-Bearing Naturally Fractured Carbonate Reservoirs

SPE Journal ◽  
2012 ◽  
Vol 17 (03) ◽  
pp. 671-679
Author(s):  
Philip J. Closmann
Keyword(s):  
Laboratory Tests ◽  
Steam Injection ◽  
Carbonate Reservoirs ◽  
Fractured Reservoir ◽  
Displacement Efficiency ◽  
Oil Saturation ◽  
Heated Zone ◽  
Naturally Fractured ◽  
Fractured Carbonate ◽  
Oil Displacement Efficiency

Summary A model for steam injection into naturally fractured carbonate reservoirs provides a method of calculating the volume of heated formation for a given amount of steam, provided that the assumptions of the model are satisfied. The model represents the fractured reservoir by a system of blocks, dependent on fracture spacing and dimensions. The amount of oil mobilized can be estimated from prior measurements of oil saturation and laboratory tests of oil-displacement efficiency. Results comparable to observations are obtained. In addition, the temperature distribution along the direction of propagation in the reservoir may also be estimated, providing a guide to variation in the local oil mobility. These results can assist in evaluating the effectiveness of steam injection in the recovery of oil from naturally fractured formations.

Steam Injection in Fractured Carbonate Reservoirs: Starting a New Trend in EOR

2005 ◽  
Author(s):  
Richard K. Penney ◽  
Riyadh Moosa ◽  
Gordon Thomas Shahin ◽  
F. Hadrami ◽  
A. Kok ◽  
...  
Keyword(s):  
Steam Injection ◽  
Carbonate Reservoirs ◽  
Fractured Carbonate

Steam Injection in Fractured Carbonate Reservoirs: Starting a New Trend in EOR

2005 ◽  
Author(s):  
Richard K. Penney ◽  
Riyadh Moosa ◽  
Gordon Thomas Shahin ◽  
F. Hadrami ◽  
A. Kok ◽  
...  
Keyword(s):  
Steam Injection ◽  
Carbonate Reservoirs ◽  
Fractured Carbonate

Well Integrity Issues in Steam Flood Injection Wells, Karim Small Field Cluster

2021 ◽  
Author(s):  
Alexis Ariwibowo ◽  
Al Salt Al Sulti ◽  
Yousuf Al Aufi ◽  
Muhammad Mirza
Keyword(s):  
Failure Analysis ◽  
Steam Injection ◽  
Observation Data ◽  
Injection Wells ◽  
Daily Monitoring ◽  
Well Integrity ◽  
Open Hole ◽  
Steam Flood ◽  
Remedial Actions ◽  
Seal Assembly

Abstract Two (2) steam flood vertical injection wells are under operation for the last 15 months in a two- pattern pilot. Previous steam injection experience in this reservoir did not indicate serious issues due to the short injection periods for cyclic steam stimulation (CSS) but several well integrity issues have been faced during the steam flood period. Key issues include high wellhead growth, steam leak to the annulus A, annulus between 7” production casing and 4-1/2” injection tubing, and groundwater vapor behind 9.625” surface casing. Negative impacts from these issues on the continuity and effectiveness of the steam flood are recognized and need to be resolved comprehensively. All wells in the steam flood pilot were drilled and completed based on designs and procedures according to thermal well compliance including well equipment, and cementing specification. Production casing was equipped with thermal expansion collars to support reduction in wellhead growth. Completion strategy uses seal bore packer with bore extensions to accommodate tubing movement and Vacuum-Insulated-Tubing to provide maximum thermal insulation. However, the presence of a total- loss zone near the surface (starting from 50 m depth) affects the cement isolation between surface casing and 12.25” open hole. Daily monitoring is performed on each well where key injection parameters and well responses are recorded. Maximum wellhead growth reached 61 cm within the first week and steam leak from the injection string to annulus A started after 6 months of steam injection. Soon after that, groundwater vapor starts to arise from the gap between 9.625” casing and 12.25” open hole. These series of failures occurred in both injection wells within 3 months apart from each other. It is believed that the steam leak to annulus A resulted in thermal transmission to groundwater vapor. Hoist entries to both injectors indicated that Injector-1 has tubing seal assembly stuck inside seal bore and resulted in parted tubing collar while Injector-2 has tubing seal assembly damage. Both wells have thick oil covering the retrieved seal bore packer. Remedial actions were performed, including a complete change-out of the seal bore packer assembly and top-job cement fill up to surface using fast-set cement to isolate the gap between 9.625” casing and 12.25” open hole to reduce wellhead growth. As a result, the maximum wellhead growth became only 19 cm and 4 cm in Injector-1 and Injector-2, respectively. These remedial actions also led to restoring well and thermal integrity. Retrieved seal bore packer was sent back to manufacturer for appropriate failure analysis and providing useful feedback reports on the above issues. Monitoring and observation data along with failure analysis should provide vital information and possible improvement in completion strategy for steam injection wells that are planned for continuous steam flood projects in similar reservoirs.

An Overview of Steam Injection Projects in Fractured Carbonate Reservoirs in the Middle East

2014 ◽  
Vol 3 (3) ◽  
pp. 101 ◽  
Author(s):  
Zuhair Al Yousef ◽  
Hussain AlDaif ◽  
Mohammed Al Otaibi
Keyword(s):  
Middle East ◽  
Steam Injection ◽  
Carbonate Reservoirs ◽  
Fractured Carbonate
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