gc spe permian study group
TRANSCRIPT
5/13/2018 GC SPE Permian Study Group - slidepdf.com
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Successful Stimulation of Open Hole
Carbonate Formations
Using Coiled Tubing
A Presentation for the Gulf Coast
Permian Basin Study Group
Presented By:
Jeff Harris
BJ Services (Coiltech)
Midland, Texas
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OR OR
GETTING THE MOST FROM
HORIZONTAL OIL AND GASWELL ACID TREATMENTS
USING
TECHNOLOGY
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Why the titles? What¶s this to
do with acidizing HorizontalWells?
Too many CT jobs are performedthe same way they were done
³back when´
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Our own in-
house survey
But first ...
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How many of you
have had experiencesin stimulating HZ
wells?
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Economically have
your Hz wells proven
to be ««.Good
Fairor Poor?
(be honest)
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How were yourwells stimulated?
-
-
-
-
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Did you know only40% of the Hz wells
drilled are likely to
become economicallyviable
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Hopefully after thisdiscussion we can
increase our ³luck´
when stimulating Hz
wells!!!!
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Part One
Some Simple
Basics
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What does a simple
horizontal well look like?
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Heel
A Basic Horizontal WellA horizontal well may be drilledA horizontal well may be drilled
into a gas or oil bearing strata,into a gas or oil bearing strata,
as well as being used for water, steam or miscibleas well as being used for water, steam or miscibleflood injection.flood injection.
Lateral Section
Build Section Fractures
A Basic Horizontal Well
50 to more than 1500 metres of lateral
section depending upon objectives«..
HeelToe
Target formation
150 to more than 5000 ft of lateral section
depending upon objectives...
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Horizontal wellsare expensive to
drill andstimulate so why
drill
horizontally?
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The decision to drill a well
horizontally may depend uponmany factors
and can include
the necessity for greater exposure of
narrow target zones to the wellbore
a reduction of solids migration to thewellbore because of reduced drawdown
intersection of naturally occurring
vertical fractures
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Part Two
The
Formation
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Simply put the extremes of the
types of rock we drill into
for oil or gas are
a tight, low perm carbonate
a fractured carbonate with good
porosity and permeability
a sandstone
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Consider
A very tight,
low perm/low porosity
carbonate reservoir
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No upward folding to cause
stress fractures
Low Perm / Low Porosity
Carbonate Reservoir
(tombstone)
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When there are No
fractures and low
permeability...« Matrix Acidizing has
ONLY VERY LIMITEDEFFECTIVENESS IF ANY!
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Now Consider
a fractured carbonatereservoir with good
porosity and permeability
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Carbonate Reservoir
The best example of this type of reservoir is
formed by an upward folding of the formation to
causes stress fractures
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Horizontal wellsdrilled into this type of
formation areespecially suited to
squeezed matrix acidstimulation techniques
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Carbonate
Reservoir
Fractures
Horizontal
Wellbore
Intersecting
Fractures
Vertical drill -
may not
intersect
fractures
³K ill the Geologist´
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Finally «..
«.. sandstone reservoirs - a
topic for discussion on
another day!!!
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Part Three
Formation Damage
(typically carbonate reservoirs)
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Fact : Almost all horizontalwells are very susceptible to a
variety of formationdamaging mechanisms while
drilling.
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Drilling damage acrossthe wellbore may look
like «.....
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Drilling Damage
FracturePlugging Pore Plugging
Filter Cake
Shallow
MatrixDamage
Wellbore Crushing
Also possible damage
from rock polishing, aqueous
phase trapping, the use of poor fluid choices etc.
Drill fines may be as
small as 2 microns!!
Shallow Matrix
Damage
Wellbore
Crushing
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Drilling damage alongthe wellbore may look
like ...«..
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Drilling fluid
Overbalanced finesOverbalanced finesmigration into fracturesmigration into fractures
Open Hole SectionOpen Hole Section
Compressed Filter Cake -Compressed Filter Cake -considered to be 2 to 5 mm thickconsidered to be 2 to 5 mm thick
Drilling Fluid &
Cuttings
Loosely held fines
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Formation damage one finds
restricting flow in vertical wellsmay also occur in horizontal
wells- for example
Fluid incompatibilities
Oil wetting the formation
Anhydrite or soft rock smearing
Sulphur deposition in high H2S wells
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b
Horizontal Well Drilling DamageHorizontal Well Drilling Damage
The heaviest damage is to be expected at the heelThe heaviest damage is to be expected at the heel
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Part Four
Designing Horizontal
Well Acid StimulationPrograms
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Horizontal well stimulationprogram design requires
intercompany teamwork!
Geologists, reservoir engineers, mud
engineers, technologists, laboratory
and specialised service company staff all have a role in designing the best
stimulation program possible
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Before recommending any
stimulation treatment wecarefully carryout many
tests and observations.
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Well data
Geology reports
Drill cuttings
Drilling mud
Stimulation Program
Acid solubility
Service Company
Experience
Target zones
Drill Bit
ROP
Fractures
Well fluids
Stimulation
package design
Computer modelling
SEM analysis
Drilling reports
losses
Other information
Core flow studies
porosityGas shows
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Hz Well Stimulation ProgramPossibilities
Fracturing
Enzyme Squeeze Treatments
Acidizing
Oil or Water Based Fluids
Carbonate
SandstoneOther specialised treatments
Roto-Jet
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Assuming the drilling fluids
have been designed to beacid compatible «...
«.. then acid is the best stimulation
media for removing drill fines, drill
cuttings, filter cake, crushed and
polished rock, and acid soluble LCM
both around the near wellbore and
into any extending fractures
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But how do we conveythe acid to the damaged
areas of the wellbore andformation, as well as
squeezing acid into thefractures?
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By ««...
Bullheading aciddown tubing - NO,
NO, NO!!!
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Why? Because acid
will go where IT wantsto go - not where YOU
want it to go. THERESULT
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Water
Oh No!Oh No!
Not Another Water Well!Not Another Water Well!
I should have listened toI should have listened to
Jeff Jeff
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By ««...
Bullheading acid down tubing
using diverting agents (wax
beads, benzoic acid, salt) -NO!!!
Pumping acid down productiontubing placed at various depths
along the lateral section - NO!!!
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By ««...
Pumping acid down a work
string RIH to the toe while
pumping acid down thebackside of the workstring
hoping to palce acid all alongthe OH lateral - NO!!!
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By ««...
Pumping acid down a work
string RIH to the toe with holes
along the length of the lateralhoping to obtain limited entry -
I don¶t think so!!!!
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Why? Because acid
will go where IT wantsto go - not where YOU
want it to go. THERESULT
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Water
Oh No!Oh No!
The acid still wentThe acid still went
where it wanted to gowhere it wanted to go
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Then How?????
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I know of a couple of methods
that have worked for me.
So-
Let¶s talk about them -
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The first tool I was given for OH
acidizing was a rotating jetting
tool.
This tool rotates 360° at a
controlled speed, induces cyclic
stress on the drilling damage anddevelops high impact pressure.
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The tool was developed for
removing hard scales, but I thought
³what a great acidizing tool this
could be for open hole´
The first jobs went great - well productivity
increased as much as 7 fold. That promptedan SPE paper (SPE 54467).
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The first candidates were deeper
wells that had fairly high BHTand the acid reacted almost
instantly as the tool was runalong the length of the OH.
Then someone read the SPE
paper and wanted to use the tool
and procedure on a San Andres
open hole horizontal!!
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Since the San Andres doesn¶t have a
very high BHT, the customer wanted some type of diversion to
insure that the acid went where he
wanted it to go!
I suggested a method that had
worked for me over the years
FOAMFOAM
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But wait a minute ««..
Foam as a diverting agent!
Surely it¶s only good forshaving!!!
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Not so!
A 75% quality foam willprovide a thick, viscous, non-
damaging fluid media that is a
useful diverting agent in both
vertical and Hz wells
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Obviously the foam must beacid compatible «..
«.. such foams are able
to divert acid very
effectively
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So the
customer said³OK, let¶s try
it!
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But I want to be sure this FoamTechnology is working «...
I want to use isotope tracers in the
acid stages´.
Sounded like a good idea to me«..
another trip into the hole$
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After stimulating and logging
four wells, using tagged acid
stages and foam diversion
stages«.
It was confirmed that the acid
went where he wanted it togo!!!!
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The following illustration is the
basic procedure used on those
four wells
Over time there have been
variations of this procedureused to ³fit the purpose´
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Foam Diverted Acid Squeeze
1. Coil tubing is RIH to the toe and the
wellbore is cleaned underbalanced at a
designed penetration speed to get 360°/nozzle
coverage with the rotating jetting tool
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Foam Diverted Acid Squeeze
2. Circulation continues until returns are clean
3. Foam is pumped to the BHA
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Foam Diverted Acid Squeezing
4. The OH is filled with foam
- it is not necessary to fill the well completely
with foam
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Foam Diverted Acid Squeezing
5. Close in the well, start PUH and
acidizing by pumping calculated volumes
of acid and foam stages
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Foam Diverted Acid Squeezing
6. Continue pumping acid and foam stages
along the target intervals of the open hole
until desired acid coverage is achieved
7. Flush CT and OH (gas lift if desired)
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Are the results always as good
as the examples in the SPEPaper?
As far as increasing
productivity«.
The answer is«.not always«.
BUT
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There is an additional benefit that
has made using the rotating jetting
tool and foam diverted acid squeeze
stimulations beneficial«.
Less acid/foot«.A lot less acid/foot«.
7 to 10 gal/ft has produced the sameresults as the 35 to 50 gal/ft used with
other methods.
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The San Andres wells we have
stimulated in the last 3-4 yearshave had laterals >5000 ft long
With 1.75´ coiled tubing and the 1.75´
tool, pumping rates <1.5 bpm meant long
job times«. some over 40 hours.
Our customers (field personnel) weren¶ttoo crazy about sitting on these jobs for
hours and hours and «. So «.
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We were ask if there was some
way to cut the job time!!!!
We requested a larger
rotating tool and got it«.plus larger coiled tubing
and equipment.
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Now we were able to pump 3 -
3.5 bpm and the job time was cutin half«.18 to 20 hours«.field
personnel happier but still not
that happy!
I had heard about a new self-
diverting acid system that was inhigh demand in Saudi - So I
looked into it - a year or so later!
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This is what I learned about the
self -diverting acid system Single Surfactant System
Stimulates and diverts in a single stage - design and
operation less complicated Break mechanisms: hydrocarbon, water, internal
breaker and system also breaks on spending of acid
Matrix Acidizing Applications Are Delayed Viscosifying System
Self Diverting Acid
Viscosified Diverted Acid
Staged Acid
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Application
For carbonate and sandstone acidizing
Acid Type - HCl, HF
Surfactant added to acid
Concentration range - 40-80 gpt in acid
HCL concentration range - 20-28%
Internal breaker recommended for - Wells with no Oil/Condensate- Wells with no Formation Water Production
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Application
Incompatible - some mutual solvents,
surfactants, corrosion inhibitors
Temperature stable to 275ºF
Surfactant type - amphoteric, worm-like
micelle
Wettability - water wets limestone
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The next slide is a graph thathelped me understand how the
system worked.
I also sent this information to the customer
(Production Eng and Field Forman) and
pointed out that we could cut job time even
more«.It wasn¶t a hard sell!!
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Viscosity of Spent Acid vs. calculated %HCL concentration
28% HCL initially -- Ambient Temperature and 150F
0
200
400
600
800
1000
1200
0 5 10 15 20 25 30
%HCL (calculated)
V i s c o s i t y ( c P ) @ 1
7 s e c - 1
Divert S 75F
Divert S with CI-25
Divert S 150F
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2-Dec-05 REVISION DATE GIVEN REQUIRED
REVISED by J. Harris PUMP PUMP COILCOIL INTERVAL RATE RATE TIME SPEED
STEP DIRECTION FT FT FT FLUID GALLON BBL BPM SCFM MIN FPM
1 DOWN 0 5023 5023 WATER 1,055 25.1 0.25 0 100.5 50.0
2 DOWN 5023 6400 1377 WATER 723 17.2 0.25 0 68.9 20.0
3 DOWN 6400 8088 1688 WATER 20,103 478.6 3.5 0 112.5 15.0
4 UP 8088 7700 388 Load Hole w/Acid 1,680 40.0 3.5 0 11.4 34.0
Close CT Annulus
5 UP 7700 7200 500 ACID 3,500 83.3 3.5 0 23.8 21.0
6 UP 7200 7000 200 Do Not Pump 0 0.0 0 0 9.5 21.0
7 UP 7000 6400 600 ACID 4,200 100.0 3.5 0 28.6 21.0
8 UP 6400 5023 WATER Flush * 6,476 154.2 3.5 0 44.1
* Do not wash at high rate via nozzel or acidize across
the curve
TOTALS Total fluid pumped 37,736 Total time (mins) 399.2
Gallons of Acid 10,000 9,380 Total time (hrs) 6.7
Gallons of water 28,356 Acid Pump time (hrs) 63.8
BBL of water 675
NOTE: 10,000 gal of Acid to contain 2 drums of Low PH Scale Inhibitor.
The first well was a Terry County
producer with a 4 3/4´ OHlateral. MTD was 8088 ft.
Pump Schedule
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Th lt f th S lf Di ti
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The results of the Self -Diverting
Acid System are impressive«.
The field is ~30 years old and average
oil production is 10 -12 BOPD
After the well was put on production
the oil was up to 40 BOPD
At the end of one month it was
45BOPD
Last week it was producing 50 BOPD
Th d ll T C t
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4-Jan-06 REVISION DATE GIVEN REQUIRED
REVISED by J. Harris PUMP COIL
COIL RATE Acid TIME SPEED
STEP DIRECTION FT FT FT FLUID GALLON BBL BPM Gal/ft MIN FPM
1 DOWN 0 5288 5288 WATER 1,110 26.4 0.25 0 105.8 50.0
2 DOWN 5288 5737 449 WATER 236 5.6 0.25 0 22.5 20.0
3 DOWN 5737 8716 2979 WATER 35,179 837.6 3 0 248.3 12.0
4 UP 8716 8696 20 Load w/Acid 1,050 25.0 3 0 8.3 2.4
Close CT Annulus5 UP 8696 8440 256 ACID 770 18.3 3 3 6.1 41.9
6 UP 8440 8360 80 ACID 400 9.5 3 5 3.8 21.0
7 UP 8360 8280 80 ACID 240 5.7 3 3 1.9 42.0
8 UP 8280 7830 450 ACID 2,700 64.3 3 6 21.4 21.0
9 UP 7830 7670 160 ACID 800 19.0 3 5 6.3 25.2
10 UP 7670 7410 260 ACID 1,040 24.8 3 4 8.3 31.5
11 UP 7410 7010 400 ACID 2,400 57.1 3 6 19.0 21.0
12 UP 7010 6880 130 ACID 520 12.4 3 4 4.1 31.5
13 UP 6880 6130 750 ACID 5,250 125.0 3 7 41.7 18.0
14 UP 6130 6030 100 ACID 600 14.3 3 6 4.8 21.015 UP 6030 5860 170 ACID 850 20.2 3 5 6.7 25.2
16 UP 5860 5288 572 WATER Flush * 10,500 250.0 3 0 83.3 25.0
* Do not wash at high rate via nozzel or acidize across
the curve
TOTALS Total fluid pumped 63,645 Total time (mins) 592.3
Total Acid 17,250 Total time (hrs) 9.9
Gallons of water 46,395 Acid Pump time (hrs) 2.3
BBL of water 1,105
NOTE: 17,250 gal of Acid to contain 5 drums of Low pH Scale Inhibitor
INTERVAL
The second well was a Terry County
Water Injection Well
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The post- job injection rates are
the same as pre- job rates«. but injection pressures were
25%-
30% less
This well is a multi-lateral and this
was the last lateral to be
stimulated.
5/13/2018 GC SPE Permian Study Group - slidepdf.com
http://slidepdf.com/reader/full/gc-spe-permian-study-group 81/83
Other Case Results
East Texas - self diverting acid stages
between acid stages down 2 3/8´ Tbg.
Pre-job production - 0 MCFD Post-job production - 1500 MCFD
Saudi - Hz Injection Well - the diverting
stages were foamed-the surfactant wasused to stabilize the foam (SPE 93536)
Pre-job injection - 17,000 BWD @ 1643 psi
Post-job injection - 77,000 BWD @ 1180 psi
5/13/2018 GC SPE Permian Study Group - slidepdf.com
http://slidepdf.com/reader/full/gc-spe-permian-study-group 82/83
One More Case Result
Saudi - Hz Oil Producer - Acid stages
using diverting acid stages between.
(SPE 94044) Post job results - Production increase of
76,000 BOPD.
5/13/2018 GC SPE Permian Study Group - slidepdf.com
http://slidepdf.com/reader/full/gc-spe-permian-study-group 83/83
Thank you allfor coming today
...
Any questions? AnyHz OH wells you