Page 156 - Practical Well Planning and Drilling Manual

Section 2 revised 11/00/bc 1/17/01 12:04 PM Page 132

[ ] Well Programming
2.1.3

Losses occurred in Brecon 2 after taking a 0.797 psi/ft kick at 3176
ft into the Lower Cretaceous. The loss zone and bottom part of the
drillstring were cemented off.
The mud should not be treated (expensively) to maintain high inhibi-
tion unless dictated by hole condition. YP can decrease slightly to 15-18.
The bit selection is important due to the long trip times and
potentially low ROP. Unfortunately, the offset bit records are not com-
plete though some conclusions can be drawn. Gauge protection does
not seem to be an issue with most of the offset bits being in gauge,
1
however, a few of the bits were significantly undergauge (up to /2 in).
For this reason it is worth paying more for enhanced gauge protection.
Insert bits with journal bearings should allow good durability with
high WOBs.
There is also a possible polycrystalline diamond compact (PDC)
application here. This will be looked at prior to starting this section
and the final decisions on which bit to run will be made at the time.
The bottom hole assembly again will be fully stabilized. This is to
allow high WOB to be run without buckling and should reduce hole
drags and problems by drilling a straighter hole.

2.1.3. Formatting the Drilling Program

The program and technical justification should be written as a
technical document. Therefore, they should be written for easy under-
standing and reference. Following are some guidelines:

Use clear, concise writing style; avoid long words and long
sentences
Do not include irrelevant material that does not help the rig
Paginate and include table of contents
Use diagrams such as well status
Print two sides (use less paper; lighter; easier to read)
Refer to standard documents that would be on the rig, where
applicable (e.g., company procedures)

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