Estimating Friction Reduction ForCasing Operations in High-Angle Wells in The Arctic Region - A Russia Case History
- Chimerebere Onyekwere Nkwocha (Geopro Technology Ltd) | Evgeny Glebov | Alexey Zhludov | Sergey Galantsev | David Kay
- Document ID
- Society of Petroleum Engineers
- SPE Arctic and Extreme Environments Conference and Exhibition, 18-20 October, Moscow, Russia
- Publication Date
- Document Type
- Conference Paper
- 2011. Society of Petroleum Engineers
- 1.6 Drilling Operations, 1.14 Casing and Cementing, 7.7.1 New Technology Deployment, 1.12.3 Mud logging / Surface Measurements, 5.2.1 Phase Behavior and PVT Measurements, 1.10.1 Drill string components and drilling tools (tubulars, jars, subs, stabilisers, reamers, etc), 1.1.3 Trajectory design, 1.6.10 Running and Setting Casing
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Casing and liner running and cementing operations in high angle wells with long open hole sections pose seemingly diverse sets of challenges irrespective of location and drilling environment. The fluvial loose formations predominant in the arctic region of Russia and most parts of Siberia provides more than adequate tests and constraints to modelling, understanding and accommodating the risks associated with such operations as this. This is further complicated with no reliable nor consistent information regarding representative geo-mechanics models or failure plains within the region.
This paper looks at modelling casing1,2,3,4 running operations and the impact of perceived friction factors and choice of accessories on the overall out come of the operation. The objective is to better understand the modelling constraints and the importance of certain parameters and assumptions in the final solutions. Successes, failures and lessons learned will be articulated to provide key best practices or design considerations for similar or future projects. Furthermore, we will also evaluate the technologies available within the area and the impact of technology adoption on both the ability to land casing/liner and provide adequate cementing.
The Yokhar Field in the Yamal Region of Russia is located within the Artic Circle and is a prolific oil, gas and condensate producer. Over the last couple of years the drilling envelope has been consistently stretched to high degrees of step outs (in excess of 5Km) and future plans are indicative of much higher step-outs with reaches in excess of 7Km. Figure 1 shows a typical well design with the intermediate casing set as shallow as 1400m MD whilst production casing is set right on top of the reservoir at over 5000m MD in most cases. Future wells are expected to have open-hole sections in excess of 5500m across the tangent sections whilst the drain-hole section may be pushed to as long as 1800m.
In this paper we look at the implication of results from several iterations carried out to evaluate the suitability of the friction model to ensure casing strings are landed at the appropriate depths. This is then compared to the actual data from test wells and against offsets where casing strings have been run in high angle wells through long open-hole sections. For these wells we compared the simulated hook loads with actual recorded data. The comparison provides an idea of representative friction factors for casing strings. Furthermore, the comparison of predicted versus actual data provides some indication on the impact of the centralizers on the effective friction factors whilst running the casing string. All 245mm (9????) casing strings were run in 311.15mm (12 ¼??) hole.
Figure 1 shows an overview of 3 wells that have been drilled in the field so far. The 13??? casing was set at 1350m TVD in these wells. The well profiles are quite similar with a maximum DLS of about 3º/30m. The sail angles are quite similar, ranging from 68º to about 78º inclination. A deliberate effort was taken to ensure no meaningless turns are incorporated in the trajectory design across the 12 ¼?? (311.15mm) hole section which is critical to the success of these wells. The wells have been designed to be completed as 8 ½?? (215.9mm) dual laterals.
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