Coiled-Tubing Perforation and Zonal Isolation in Harsh Wellbore Conditions

Author(s):  
Muhammad Ishamuddin Omar ◽  
Azhar Md Ali ◽  
Zulkifli Ali ◽  
Arthur Pinio Parapat ◽  
William Speck ◽  
...  
2004 ◽  
Author(s):  
Yoliandri Susilo ◽  
_ Hendarwin ◽  
Wahju Wibowo ◽  
Budhira L. Tobing ◽  
Arbai Imam ◽  
...  

2004 ◽  
Author(s):  
T. Saelensminde ◽  
H.F. Schjott ◽  
H.M. Koldal ◽  
T. Skeie ◽  
T.O. Meberg

2017 ◽  
Author(s):  
E. Tanoto ◽  
M. F. Jaffery ◽  
M. Pasteris ◽  
P. T. P. Habeahan

2011 ◽  
Author(s):  
Rifat Said ◽  
Surajit Haldar ◽  
F. Al-Subaie ◽  
Anton Burov ◽  
Wassim Kharrat ◽  
...  

2021 ◽  
Author(s):  
Talal Al-Aulaqi ◽  
Hussain Al Bulushi ◽  
Hashim Al Hashmi ◽  
Sultan Al Amri ◽  
Ali Al Habsi ◽  
...  

Abstract Over the last 50 years, thermal EOR has been an effective method for reducing the viscosity of and recovering heavy oil from deep reservoirs. In mature thermal EOR projects, conformance is one of the main challenges for maximizing reserves and meeting long-term production expectations. In this paper, Occidental presents a novel pilot to address thermal conformance in the Mukhaizna field in Oman. This is a thermal EOR operation in deep reservoirs (> 2,000 ft) with extremely high viscosity (>10,000 cp) in harsh desert conditions with temperatures exceeding 500°F. The pilot area is a mature thermal area with 15 years of continuous steamflood operations. The novel conformance technique, based on a combination of chemical and zonal mechanical isolation systems, was developed in-house in a low oil price environment. The pilot area consists of multiple reservoir zones that have undergone vertical steam injection since 2005. Thermal conformance has emerged as a challenge because more than 60% of the injected steam has been preferentially entering the high-permeability zones, with only 40% of the steam entering the other zones, which hold a larger amount the remaining oil. The subsurface and well engineering teams collaborated to design a rigless operation using dual coiled tubing units, one for cooling water and one pumping a chemical gelation recipe that gels at a certain trigger gelation temperature at the target zone. Zonal isolation of the reservoir is achieved using a novel inflatable packer triggered mechanically by ball gravitation through coiled tubing at 500°F and retrieved after the temporary zonal isolation. The well and reservoir surveillance included gathering data for injectivity assessment, vertical injection logging, temperature profiles, tracer tests in offset producers, and well testing for determining water cut. The pilot improved vertical conformance, as injection logging showed 40% steam reduction was achieved in the target zone, and more steam was re-allocated to the shallow zones. In addition, there was a water cut reduction of more than 20% in offset producers, and oil production tripled over a period of 3 months, which paid back the cost of the pilot and generated positive cash flow. To our knowledge, based on an SPE literature search, this is the first successful thermal conformance operation conducted with the following combination of technologies: 1) Placing a novel chemical recipe through temporary zonal isolation with an inflatable packer, and 2) Using rigless operation of coiled tubing units at harsh conditions of >500°F and high pressure >1000 psi. The outcomes open a new frontier for thermal EOR development in multi-stack reservoirs, offering better utilization of steam injection and improving mobility control over the field life cycle. The cost of the pilot project was paid off in the first 6 weeks, and all chemicals used were developed in an eco-friendly system.


2004 ◽  
Author(s):  
Yoliandri Susilo ◽  
_ Hendarwin ◽  
Wahju Wibowo ◽  
Budhira L. Tobing ◽  
Imam Arbai ◽  
...  

2013 ◽  
Author(s):  
Anton Ravilich Ablaev ◽  
Maxim I. Novikov ◽  
Maxim V Oparin ◽  
Andrey Alexandrovich Potryasov ◽  
Konstantin Burdin ◽  
...  

2015 ◽  
Author(s):  
Harmohan Gill ◽  
Ronald Morris ◽  
Prasad Karadkar ◽  
Syed Danish ◽  
Angel Arenas ◽  
...  

2021 ◽  
Author(s):  
Takeru Okuzawa ◽  
Kushal Gupta ◽  
Tetsuro Takanishi ◽  
Ahmedagha Eldaniz Hamidzada

Abstract In workover phase prior to commencing sidetrack operation, it is required to recover old existing completion string for isolating & abandoning existing reservoir section in accordance with well integrity and global well abandonment standards. Prior to utilization of the coiled tubing cementing approach, the practice was to recover all existing completion by cutting and pulling out the dual tubing or mill the permanent packer. After all the completion recovery, spot and squeeze cementing operations were conducted. However a major drawback of this process is, until recovering some part of completion string, the actual physical condition of the completion strings remains unknown and it poses high risk to get stuck in cased hole or end up in loosing accessibility inside completion string due to corrosion. Furthermore, in some of the old wells had failure to recover completion components like a dual flow assembly and a dual packer due to completion age, had led to improper zonal isolation. Even if all the old existing completion is recovered successfully, it consumes a lot of operation time and several fishing trips with overshot or junk mill BHA (Bottom Hole Assembly). In order to minimize the risk of being stuck or loosing accessibility and ending up failing to recover existing completion and to save operational time, the coiled tubing cementing was conducted to isolate existing reservoir and leave remaining parts of completion downhole. During the operation phase, injectivity test was performed by pumping sea water followed by bull heading kill fluid in to the reservoir. Losses rate was evaluated while observing the well, a high viscosity pill was spotted in order to treat losses and control loss rate. Coiled tubing was rigged up on Long string and run in hole to tag a landing nipple in existing completion string in order to have reference of depth corrected against ORTE (Original Rotary Table Elevation) depths while using the coiled tubing for operations. After having correct reference of depth with tagging completions nipple accessory, coiled tubing with slim OD cementing BHA was run in hole to tag PBTD (Plug Back Total Depth) and then picked up to certain depth while spotting cement slurry at controlled speed. Once the complete amount of slurry was spotted during picking up coiled tubing was pulled out to be away from cement slurry and then coiled tubing BOP (Blow Out Preventer) was closed and cement was squeezed in to the formation. After squeezing pre determined volume or archiving the lock up pressure, coiled tubing was pulled further up and circulated out to ensure all cement slurry out from coiled tubing (inside and outside). Top of cement was confirmed by tagging with the milling assembly connected to coiled tubing and the pressure test was performed after waiting on cement to confirm the integrity of the barrier. For short string, similar abandonment plug process was followed as that of the long string. After performing tagging operations, cement was spotted while pulling out the coil tubing to certain depth and then coil tubing was picked up above the cement to squeeze cement in to the formation. Similar coiled tubing cement operation for isolating lower perforations was performed on three other wells, and proper zonal isolation was achieved against reservoirs. This improved approach of abandoning lower reservoir prior to completions recovery proved to save 2-3 days of rig operational time in comparison to previous operations practices of recovering existing completion completely & then perform cementing operations for zonal isolation against each reservoir. Based on the successful result in three wells, it is concluded that this coiled tubing cement operation is effective for zonal isolation and provide savings in operation days.


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