to the bottom of the reservoir. CNRL to detect the base of the reservoir during Lee explains that this method of using
collaborates with Halliburton to utilize horizontal drilling and geosteers the well the bit to steer by and refine the geology
logging-while-drilling (LWD) techniques one metre above the reservoir base. results in a reduction in overall drilling
to achieve optimal well placement in time by eliminating the need to
relatively thin, heterogeneous reservoirs The team uses real-time data to intentionally “tag” the bottom of the
of the Clearwater Formation in its recalculate well plans as they acquire reservoir. Wellbore completion is also
commercial cyclic steam stimulation new surveys and petro-physical data. improved by ensuring maximum steam
operations. Data collected are integrated for 3-D contact with the reservoir.
geological modelling and well planning.
Halliburton’s proprietary StrataSteer 3-D In turn, the geological surfaces are “When you’re drilling horizontal, the
service is used both prior to and during revised while drilling and applied to responsibility of the team is wellbore
real-time drilling to plan, model and successive wells. Log responses are also placement,” says McKain. “Before
steer the horizontal well. The team characterized and correlated to the geosteering, it was very difficult to
monitors resistivity and gamma ray in RT known-area geology. maintain the optimal separation from the
shale.”
HEAVY / EXTRA HEAVY OIL
BITUMEN
INTEGRATED PETROLEUM ENGINEERING
THERMAL PRODUCTION
SAGD PERFORMANCE
DATABASE FOR ALBERTA
• SAGD
• CSS
• Steam flood
- Cum. & Daily SOR & Produced WOR
- Cum. & Daily Injection Rates
- Instantaneous SOR & WOR
- No. and % Wells on Production & Steam
- % Recovery of OBIP
COLD PRODUCTION
• Conventional
• CHOPS
Advisory services
Concept & feasibility
Reservoir surveillance
Field development
Production & monitoring
Technology transfer
DALLAS
HOUSTON
HALIFAX
CALGARY
Gerry Belyk
403.265.7226
gbelyk@apa-inc.com
For example, with a 24-well pad, which
includes 16 true horizontal wells in
addition to a combination of short-reach
horizontal and directional wells, CNRL
averaged between six to 10 sidetracks
per pad as they searched for the base of
the reservoir by drilling into the
underlying formation. With geosteering,
the wellbore placement stays within a
metre of the shale and allows CNRL to
drill more than 55 wells without
sidetracks.
In addition, the rate of penetration is
fast—in excess of 300 metres per hour. A
job that once took 4. 25 days per lateral
section has been reduced to 3.0. “We’ve
cut off a day and a quarter in operational
lateral section, which resulted in a 13 per
cent reduction in cost.”
CNRL has also seen benefits in terms of
wellbore geometry. Drilling horizontally
means that the well path can go up and
down like a corkscrew, creating what
drillers call “dog legs.” Every time a
wellbore moves in a different direction, it
creates dog legs or a bend. “We’ve seen a
positive decrease in wellbore dog-leg
severity due to the reduction in
sidetracking,” McKain explains.
Working in real time over long distances
extends beyond the drilling industry.
Whether in the field or in the plant, oil
and gas operators are increasingly
turning to real-time monitoring of wells,
pumps, compressors and other
equipment. This can serve to increase
production, as well as decrease the
number of staff required for operations,
which is good news for an industry facing
a labour crunch.
“[Industry] is trying to prepare for a
younger workforce and a smaller
workforce,” says Warren Mitchell, director
of advanced applications for Matrikon
