American Oil and Gas Reporter - June 2018 - 70

FIGURE 3A

FIGURE 3B
Well Design
For 10K Laterals

Modiﬁed Original Well Design Used in Speciﬁc Areas
For 5K, 7.5K and 10K Laterals

Surface:
Hole: 171⁄2 in.
Casing: 133⁄8 in.
Mud Weight: 8.4-8.8 ppg

Surface:
Hole: 171⁄2 in.
Casing: 133⁄8 in.
Mud Weight: 8.4-8.8 ppg

Evaporite
section

Evaporite
section

Intermediate:
Hole: 121⁄4 in.
Casing: 95⁄8 in.
Mud Weight: 8.8-10.0 ppg

Water
ﬂow
Lost
circulation

Lost circulation

Intermediate:
Hole: 121⁄4 in.
Casing: 95⁄8 in.
Mud Weight: 8.8-10.0 ppg
Production:
Hole: 81⁄2 in.
Casing: 51⁄2 in.
Mud Weight: 9.0-12.0 ppg

Figure 2 demonstrates the improvement
in footage drilled per day versus rig release
date, along with the transition from 5,000foot to 10,000-foot laterals. The depth of
the lateral target has increased from 4,000
to 9,000 foot true vertical depths for the
majority of the horizontals drilled prior
to 2016, to 8,000-10,500- foot TVDs for
wells drilled since 2016. Specific to 5,000foot lateral lengths, total drilling times

Production:
Hole: 81⁄2 in.
Casing: 51⁄2 in.
Mud Weight: 8.0-9.5 ppg

from rig release to rig release improved
53 percent from 2012 to 2017.
Well Design Strategy
With the development program in the
New Mexico Delaware Basin expanding
from a single bench to multiple benches
starting in 2016, the well design strategy
similarly has evolved from a single design
to fit-for-purpose designs tailored to spe-

cific areas. Areas with varying regulatory
requirements and different drilling hazards
(e.g., lost circulation, water flows, lateral
reservoir pressures, etc.) mandate the use
of fit-for-purpose well designs. Multiple
well designs require more casing inventory
and more downhole tools. However, the
results achieved so far validate the strategy
of multiple fit-for-purpose designs.
The original well design first deployed

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70 THE AMERICAN OIL & GAS REPORTER

American Oil and Gas Reporter - June 2018

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