English Edition (6 MB pdf) - Saudi Aramco
English Edition (6 MB pdf) - Saudi Aramco
English Edition (6 MB pdf) - Saudi Aramco
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to 60 ft/hour with the hydraulic orienting tool (HOT)<br />
configuration, allowing for all three wells to be completed<br />
two days ahead of schedule.<br />
KSA UBCTD Project Background<br />
The Ghawar field is by far the largest conventional oil field in<br />
the world, and accounts for more than half of the cumulative<br />
oil production of <strong>Saudi</strong> Arabia. Beginning in the 1980s, deep<br />
drilling through the Jurassic beneath Ghawar field has proved<br />
up large reserves of gas, sometimes with condensate in the<br />
Permian Khuff limestone and pre-Khuff sandstone. Now <strong>Saudi</strong><br />
<strong>Aramco</strong> is developing Khuff and pre-Khuff gas beneath<br />
Ghawar 5 .<br />
In several areas around the world, including the U.A.E. 6, 7<br />
and North America 2, 8 , it was proved that UBCTD reentries<br />
can provide cost-effective access for infill drilling activity.<br />
Testing this technology in the Khuff limestone reservoir was a<br />
logical step towards further opening up those resources. In the<br />
summer of 2008, the first UBCTD pilot project in the<br />
Kingdom of <strong>Saudi</strong> Arabia was undertaken to evaluate the<br />
feasibility of reentering old wellbores using UBCTD to reverse<br />
declining gas production.<br />
Vertical Khuff gas producers, completed with 4½”, 5½” or<br />
7” liners, were reentered and sidetracked using CT. A typical<br />
operational sequence for the current UBCTD project includes<br />
running and setting a whipstock and exiting the liner by<br />
milling a window, sidetracking the well and drilling one lateral<br />
across the Khuff formation, performing open hole sidetracks<br />
and drilling up to three more laterals. All operations are<br />
typically performed underbalanced while the well is<br />
producing. As of October 2009, 11 wells (31 laterals) were<br />
successfully drilled, exposing up to 7,000 ft of open hole per<br />
well and averaging 1,511 ft of lateral length.<br />
After a nine well pilot phase was successfully completed<br />
using personnel and best practices from around the world, a<br />
great emphasis was placed on further improving UBCTD<br />
project economics through improved operational efficiency<br />
and the introduction of new underbalanced CT drilling<br />
techniques and services.<br />
As lessons were learned and office engineering personnel<br />
and crews on location became more experienced, the average<br />
number of operating days on location required to drill 500 ft<br />
of open hole fell from 4.2 to below three days, Fig. 1.<br />
New Technology Introduction to UBCTD Project in KSA<br />
Since its first deployment in the Middle East at the end of<br />
March 2009 to October 2009, a 3” RSM tool has been tested<br />
in six consecutive wells drilling 15,551 ft in 15 runs and<br />
successfully performing five open hole sidetracks. The RSM<br />
has contributed to achieving the following major<br />
improvements in drilling the lateral sections:<br />
• Optimization of the biosteering process together with<br />
the introduction of new rib steered technology helped<br />
maximize reservoir exposure, extending lateral reach<br />
Fig. 1. UBCTD project days/500 ft.<br />
Fig. 2. UBCTD project motor performance comparison.<br />
and using advanced inclination control modes to stay<br />
within the 2 ft porosity zones. The longest lateral on the<br />
current UBCTD project was drilled with the RSM tool<br />
never leaving the pay zone.<br />
• Average ROP in the pay zone was increased by 35%,<br />
Fig. 2, when drilling with the RSM tool BHA compared<br />
with a conventional oriented bent motor coil drilling<br />
assembly. The rib steered BHA has also set a daily<br />
footage record of 968 ft/24 hrs for the current UBCTD<br />
project.<br />
As an illustrative example of the advantages that rib steered<br />
technology brings to the UBCTD operations, three case<br />
scenarios were evaluated to assess the weight on bit (WOB)<br />
available/reachable depth:<br />
1. CASE 1 - Planned Well Path – AKO 0.8: Using oriented<br />
bent motor, which requires constant orientation and TF<br />
corrections generating an anticipated DLS of 7°/100 ft.<br />
2. CASE 2 - Planned Well Path - RSM: Using rib steered<br />
technology, which requires a straight well profile with<br />
anticipated DLS of 0-1°/100 ft.<br />
SAUDI ARAMCO JOURNAL OF TECHNOLOGY SUMMER 2010 13