Drilling rigs of different designs and construction are available in the market with varying specifications and limitations. Multiple number of both single and multi-string completion assemblies have been successfully run globally in the oil and gas industry to meet production to reservoir management well objectives. In comparison to running a single string completion, running a dual string completion poses an additional challenge with regards to simultaneous handling of dual tubulars. The short string tail pipe needs to be run together with the long string until the dual packer is made up and afterwards until the dual completion tubing hanger is finally landed in the wellhead. This simultaneous operation surely presents more operational as well as safety challenge to the tubular running and rig floor personnel.
In addition, these, completion tubing come manufactured in different ranges depending on the average length per joint of the tubing and because drilling rigs by design are manufactured with mostly fixed-elevation components with regards to distance from the rig floor. Considering the above factors, most drilling rigs are equipped with adjustable stabbing boards that allow a dedicated stabber operating from this platform to adjust the platform for easy accessibility to the completion string as required depending on the tubing range to be run.
This paper highlights the challenges with running a "R2 range" dual completion string with a rig equipped with fixed stabbing board, present a proven, effective, and safe procedure that eliminates the need for a stabbing board and its associated potential HSE risk to a stabber. It also presents ADNOC Onshore experience and opportunities for further optimization and improvement briefly highlighting the methodology employed by operator and service provider engineers in the planning and execution with results.
Applying this simple but innovative approach, saved the operator deferred realization of business objective due to delay in availability of rigs with adjustable stabbing board.
The process utilizing a single automated catwalk and a modified mousehole, eliminated the need for a stabbing board, a dedicated stabber to operate from the stabbing board, the associated risk of working at height and dropped objects hazard. It does not require any modification to rig structural or mechanical design.
Reducing overall running time from 9 days to 1.2 days saved the operator about $350,000 of well cost.
Implementing this technique across all rigs with similar configuration removed the limitation that had earlier constrained the operator to run dual string completions with only select rigs having specific designs. With fixed or adjustable stabbing board rigs, both single and dual completion strings can now be run safely and efficiently.
It proved again the value of excellent teamwork, risk assessment, job safety analysis and effective communication in value delivery.