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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as pipe sticking. In some parts of the field, the mud weight<br />
must be increased considerably because of the over pressure<br />
present in the Jilh formation, which increases the difficulty of<br />
drilling the section 1 .<br />
Rotary steerable system (RSS) tools were introduced into<br />
the <strong>Saudi</strong> <strong>Aramco</strong> deep gas operations to improve hole quality<br />
and ROP. To enable optimum steerability, stability, ROP, and<br />
bit life, it was necessary to develop a polycrystalline diamond<br />
compact (PDC) bit to match the system.<br />
After several bit optimization cycles and optimum drilling<br />
practices based on the accumulated experience, the latest<br />
iteration of the 12” PDC bit designed to match the powered<br />
rotary steerable systems (PRSSs) achieved multiple drilling<br />
records in most zones of the Ghawar field. Today, it is<br />
possible to drill the entire section in one run, which sig -<br />
nificantly reduces the drilling time and costs of the deep gas<br />
operations in <strong>Saudi</strong> Arabia.<br />
GEOLOGY OF THE 12” SECTION<br />
The geology of the 12” section, Fig. 2, includes the following<br />
formations.<br />
Base of the Jilh Formation<br />
The base of the Jilh formation consists primarily of carbonates<br />
(dolomitic limestone and dolomite) with streaks of anhydrite<br />
and shale. Because the Lower Jilh is known to be a highpressure<br />
zone, casing is set in the base Jilh dolomite to<br />
increase the mud weight to compensate for the high-pressure<br />
zone. The estimated formation pore pressure is 75 pounds per<br />
cubic foot (pcf) to 80 pcf equivalent mud weight, and it is<br />
drilled with a mud weight of 78 pcf to 90 pcf. The typical<br />
mud weight is 100 pcf.<br />
Sudair Formation<br />
The Sudair formation consists primarily of shale with streaks<br />
of anhydrite, siltstone and dolomitic limestone. The estimated<br />
formation pore pressure is 80 pcf to 82 pcf equivalent mud<br />
weight, and it is drilled with a mud weight of 90 pcf to 93<br />
pcf. The shale in the Sudair formation is reactive to hydration;<br />
bit and stabilizer balling is common in some zones of the field.<br />
Khuff Formation<br />
The Khuff formation is a highly intercalated formation that<br />
consists primarily of carbonates (limestone and/or dolomite<br />
and/or dolomitic limestone) with streaks of anhydrite and<br />
shale. The Khuff formation contains three gas reservoirs<br />
(Khuff A, B and C). Khuff A and B are medium hard<br />
formations, and Khuff C is more consolidated.<br />
WELL PROFILE<br />
Early directional wells used conventional motor systems. The<br />
vertical section was drilled with a performance motor and an<br />
aggressive PDC bit. The bit was then pulled out of the hole,<br />
Fig. 2. Stratigraphic column; formations drilled directionally.<br />
and the build section was drilled with a steerable motor<br />
bottom-hole assembly (BHA). Directional objectives could be<br />
achieved; however, drilling with a conventional motor BHA<br />
requires numerous bit runs and provides low ROPs. Before<br />
the introduction of the PRSS application, the average ROP<br />
when drilling a 12” curve section was approximately 10 ft/hr.<br />
Figure 3 shows the well profile.<br />
In a typical well design, 13 3 ⁄8” casing is set 30 ft into the<br />
base of the Jilh dolomite. A typical well profile requires<br />
vertical drilling approximately 800 ft to 1,000 ft with a<br />
performance motor and an aggressive PDC bit. The curve<br />
section is planned with a dogleg severity (DLS) of<br />
approximately 4°. The 9 5 ⁄8” casing was planned to be set into<br />
the Khuff C carbonate. It required an average of two to four<br />
bit trips to drill the curve section. The formations encountered<br />
while drilling the build section are hard, and because of the<br />
number of hours, bit wear, low ROP, and tool failures,<br />
additional trips were required.<br />
The objectives with the PRSSs were to drill both vertical<br />
and curve sections in one run, maximize the ROP, and<br />
increase the footage drilled per bit run, while meeting<br />
directional requirements.<br />
BIT PERFORMANCE WITH A STEERABLE MOTOR<br />
This section will discuss the bit performance with a steerable<br />
motor in a 12” section of the southern Ghawar field where<br />
the bit optimization process occurred. The hardness of the<br />
rock, transition zones, shale reactivity, and rock abrasiveness<br />
in the southern zones differs slightly between zones, which<br />
represents various bit design challenges.<br />
46 SUMMER 2010 SAUDI ARAMCO JOURNAL OF TECHNOLOGY