American Oil and Gas Reporter - April 2015 - 84
SpecialReport: New World Mexico
The drilling fluid must provide proper
rheology for hole cleaning and chemical
properties to minimize destabilizing shales.
The high fluid volume quickly exceeds
available rig storage capacity and mixing
capabilities, thus the pump-and-dump system is utilized to mix the drilling fluid in
real time. To produce it consistently and
with homogenous properties, mixing on the
fly is undertaken to ensure the correct blend
at high workflow rates. High-density bentonite fluid volume is prepared onshore,
and a supplying vessel ships it to the rig and
a mud boat for pumping. The following
variables should be considered for pumpand-dump planning: rate of penetration,
flow rate, interval length, and fluid volumes
needed to ensure proper hole cleaning.
During the drilling campaign, jetting
practices include controlling the string
slack-off weight while jetting, and reciprocation of the conductor in relation to the
weight on bit. After the first ultradeepwater well (Supremus-1) was drilled in the
Perdido area, the team reviewed the surface conductor setting procedure with
data to optimize the relevant parameters.
The minimum ROP for jetting was determined to be 17 meters/hour in order to ensure the team could jet the casing to the desired depth.
Pemex applied the best practice of
maintaining the well's verticality while
drilling surface sections to minimize lateral forces, prevent casing wear and maximize wellbore quality for better cementing operations.
Redesigned BHA
For the next Perdido wells, Trion-1 and
Pep-1, a redesigned bottom-hole assembly
incorporating rotary steerable, hole-opener tools was used to enlarge the hole to 33
inches to set 28-inch casing. The system
included an under-reamer positioned above
the motor to reduce the rat hole length and
improve the measure point of the loggingand measurement-while-drilling tools.
This BHA proved very successful with Trion-1, delivering a maximum inclination of
0.18 degrees. The Pep-1 well assembly entered with an inclination of 1.02 degrees
and ended with 0.09 degrees. The maximum inclination obtained was 0.26 de-
FIGURE 2
Wellbore Geometry Evolutions According to Water Depth
(Hole Enlargement with Multiple Under-reamers in BHA)
500 m > Water Depth < 1,500 m
Jetting
30 in
26-in hole size, pump and dump
22 in
Pilot hole 121⁄4-in, then
hole enlargement to
171⁄2-in x 20-in hole size
16 in
> 1,500 m Water Depth
Jetting
30 in
28-in x 33-in hole size
28 in
26-in hole size, pump and dump
22 in
121⁄4-in x 22-in hole size
18 in
121⁄4-in x 20-in hole size
16 in
171⁄2-in hole size
135⁄8 in
113⁄4 in
9 ⁄8 in
5
75⁄8 in
51⁄2 in
Pilot hole 121⁄4-in, then
hole enlargement to
121⁄4-in x 141⁄2-in hole size
105⁄8-in x 121⁄4-in hole size
81⁄2-in x 97⁄8-in hole size
61⁄2-in hole size
84 THE AMERICAN OIL & GAS REPORTER
121⁄4-in x 171⁄2-in hole size
135⁄8 in
117⁄8 in
9 ⁄8 in
5
75⁄8 in
51⁄2 in
121⁄4-in x 141⁄2-in hole size
105⁄8-in x 121⁄4-in hole size
81⁄2-in x 97⁄8-in hole size
61⁄2-in hole size
grees, and the 28-inch casing was run and
cemented successfully.
Well design possibilities have evolved
to include tandem hole openers with
BHAs of 121⁄4 x 171⁄2 x 22 inches, 121⁄4 x 161⁄2
x 20 inches, or 121⁄4 x 141⁄2 x 171⁄2 inches.
These new assemblies incorporate the rotary steerable system with mechanical and
hydraulic hole openers, plus a complete set
of LWD measurements to support realtime formation and geomechanical evaluation (Figure 2).
The hole, therefore, can be drilled, evaluated and enlarged in one run, reducing
wellbore stability risk and saving rig
time. The team used a comprehensive approach to protect against accidental sidetracking using hydraulics analysis, torque
and drag modeling, and shock and vibration simulations with varying drilling parameters to optimize the BHA design. A
bull-nose, tandem hole-enlargement BHA
design was selected and validated with
drilling simulation software.
New technologies and techniques were
used in Pemex's deepwater and Perdido
wells to better meet well objectives. This
included caliper data for confirming good
wellbore quality in enlarged hole sections
for evaluating shallow and deeper targets,
integrating a multi-activation circulating
sub above the BHA to solve lost circulation issues, and using simulation software
to model and optimize complex BHAs. A
dual-tandem under-reamer assembly eliminated a subsequent rat hole enlargement
trip, saving a full BHA trip and any subsequent wellbore stability risk.
LWD tools allowed evaluation decisions based on petrophysical and geomechanical data, and quadrapolar sonic tools
improved source strength and protected
against reamer attenuation. A BHA with
a special hydraulic opener was designed to
completely remove the cement inside 22inch casing during drill-out, ensuring that
a cement ring was not left behind that could
lead to stuck pipes, casing damage and potential circulation losses during cementing.
Technological Advances
Figure 3 shows the techniques and tech-
American Oil and Gas Reporter - April 2015
Table of Contents for the Digital Edition of American Oil and Gas Reporter - April 2015
Contents
American Oil and Gas Reporter - April 2015 - Cover1
American Oil and Gas Reporter - April 2015 - Cover2
American Oil and Gas Reporter - April 2015 - Contents
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