The document discusses Halliburton's Carbonate 20/20 acid stimulation technique. It provides an overview of the challenges with conventional acidizing treatments, and outlines Carbonate 20/20's systematic approach which focuses on rock analysis and uses specialized acid systems to increase production rates and recovery from carbonate reservoirs. Key aspects of Carbonate 20/20 include the use of engineering software, simple acid fluid systems, proven field techniques, diverting agents like Guidon, and optimization of fracture geometry and treatment design with tools like SIGMA and STIM2001.

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ACID STIMULATIONS

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SIGMA Process

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Selection Criteria

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Selection Criteria

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Selection Criteria

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PRONOSTICO ECOMONICO
0 15 30 45 60 75 90
Longitud de Fractura Xf (m)
0
200000
400000
600000
800000
1000000
1200000
1400000
1600000
1800000
2000000
A
Valor
Presente
Neto
(US
Dollar)
-5
0
5
10
15
20
B
Incremental
ROI
0
50
100
150
200
250
300
350
400
C
Tasa
Interna
de
Retorno
(%)
Net Present Value Incremental ROI Internal Rate of Return
A B C
Selection Criteria

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Selection Criteria

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1 E -3 0 .0 1 0 .1 1 1 0 1 0 0 1 0 0 0
1
1 0
1 0 0
1 0 0 0
1 0 0 0 0
1 E + 5
Log-Log plot: dp and dp' [psi] vs dt [hr]
Selection Criteria

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Pozo Fracturado
Qo=22 MMscfd,
Pff= 11,500 psi,
Est 1/2”.
Pozo Fracturado
Qo=13 MMscfd,
Pff= 11,522 psi,
Est 3/8”.
Est Mat Extendida
Qo=19 MMscfd,
Pff= 10,050 psi,
Est 1/2”.
Est Mat Extendida
Qo=12.5 MMscfd,
Pff= 10,050 psi,
Est 3/8”.
Est Matricial Convencional
Qo=17 MMscfd, Pff= 9,000 psi, Est 1/2”.
Qo=11.8 MMscfd, Pff= 10,000 psi, Est 3/8”.
Selection Criteria

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Fecha: Øest.
(pg.)
Ptp
(kg/cm2)
Qo neto
(bpd)
Qg
(mmpcd)
RGA
(m3/m3)
Ttp
°C
%
Agua
%
Sed.
°API
10-nov-05 1/2 454.1 3,712 21.4 1027 130.7 0 0 39.7
11-nov-05 5/8 367.0 4,788 27.5 1023 135.0 0 0 40.7
11-nov-05 3/4 295.0 5,526 31.3 1010 138.0 0 0 40.7
12-nov-05 3/8 531.5 2,300 13.3 1032 123.0 0 0 40.5
Condición Pre-Fractura – Nov05
Ptp-3100 psi
Pff – 6,000 psi
Qg-11MMPCD
Ql – 2300 blpd (activo)
S=+120
DP – 5,900 psi
DP – 127 psi DP – 184 psi DP – 241 psi
Selection Criteria

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S = 10
S = 184
10,000 bpd
14,000 bpd
Selection Criteria

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Selection Criteria
S = 10
S = 184
10,000 bpd
14,000 bpd
PRODUCCION (bbl/d) (bbl/d)
10000
8000
6000
4000
2000
0
20000
15000
10000
5000
0
ESTIMULACION 2005
ESTIM W/GUIDON AGO 2006
EST 1/4"
EST 1/2" @ 2005
EST 1/2" @ 2006
EST 3/4" @ 2005
EST 3/4" @ 2006
EST 7/8" @ 2006
1
2
3
4
5 6
IPR SINAN 156 SITUACION POST_ESTIMULACION 2005 VS 2006
POST_ESTIMULACION 2005
1)1,264 bpd, 9,527psi, DP = 60 Kg/cm2 @ ¼”
2)3,136 bpd, 7,595 psi, DP = 203 Kg/cm2 @ ½”
3)4,650 bpd, 6,179 psi, DP = 303 Kg/cm2 @ ¾”
POST_ESTIMULACION 2006
1)4,687 bpd, 8,655psi, DP = 6 Kg/cm2 @ ½ ”
2)8,098 bpd, 8,292 psi, DP = 10 Kg/cm2 @ ¾”
3)9,706 bpd, 8,188 psi, DP = 15 Kg/cm2 @ 7/8”

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CVP Analysis for determine post stimulation S
April 2005 Aug 2006
St April 2005 = 41.2 St Jul 2006=0.09

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Stimulation Techniques and
Acidification
Carbonate Experiences

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Current challenges in Acidification
• Inadequate production rats after acidification
treatment
• Rapid decline in production
• Treatment design is a complex engineering
problem
• Designs are often implemented with little
knowledge of training

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Carbonate 20/20
Provides solutions to today's challenges
• Systematic Approach
Carbonate 20/20 provides a systematic
approach to this complex engineering problem
•
• Focused on the Rock
Carbonate 20/20 includes testing and analysis
necessary for a better knowledge of the training
•
• More Production Carbonate 20/20 provides high
and sustained production levels

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Carbonate 20/20
Production Performance
Conventional
Carbonate
20/20
Production
Increase
Convencional
Carbonate 20/20
Tiempo
Gasto
(BPD)

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Technical details of Carbonate
20/20 threat.
• Software de Ingeniería -Tool-Kit
• Simple Fluid Systems
• Good Practices and Proven Field
Techniques
•
PLUS
PLUS

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Carbonate 20/20
Engineering Software -Tool-Kit
• SIGMA
• Stim 2001
• StimWin
• FRACPRO PT

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Carbonate 20/20
Simple Fluid Systems
• 1. Carbonate Completion Acid
• 2. Carbonate Stimulation Acid
• 3. Fines Recovery Acid
• 4. Carbonate Emulsion Acid
• 5. Hot Rock Acid
• 6. Zonal Coverage Acid

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Carbonate 20/20
Good Practices
1. Matrix Acidification
2. Acid Fracturing
3. Divergence
4. Laboratory Tests
5. Identification of Natural Fracture

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Þ TECNICA SUPRA-CE
Þ HOT ROCK ACID “HRA”
Þ ZONAL COVERAGE ACID “ZCA”
Þ ACIDO ENCAPSULADO
Acid Fracturing

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Low
Viscosity
Acid
Fracture
Cement
Casing
Perforations
HighViscosity
Preflush
TREATMENT TECHNIQUE : SUPRA - CE™
Fracture Acidizing
Fracture Acidizing
Fracture Acidizing
Differential Etching = Conductivity
GEL ACID
CLOSED
FRACTURE
OPEN FRACTURE
Hydrocarbon
Production
“SUstained Production Acidizing - Conductivity Enhancement”
Proceeds:
Differential Engraving
Longer Etched Fracture
Length

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Hot Rock Acid a
300° F
Mismo núcleo
, excelente
grabado
HCl al 15% a 300° F
Note que el ácidose gasta
rápidamente dejandode
grabar el núcleode carbonato
HOT ROCK ACID “HRA”
Dissolution capacity equal to 15% HCl
Combination of Organic Acids
Higher Live Acid Penetration = Higher Etched Fracture Length

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ZONAL COVERAGE ACID “ZCA”
•In situ crossing - rheologies from 25 to 500 cp.
•Gelled acid for the control of fluid loss in acid fractures.
•Longer, conductive fractures.
•Excellent fine transport capacity.
•Diverging agent
•ZCA can be used in stages with other acid systems as part of the SUPRA
Technique
•
Linear gel acid allows
too much fluid loss and
generation of
wormholes, wasting in
the vicinity of the well
ZCA system limits
continued wormhole
growth by preserving live
acid for greater
penetration

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Deviation WITH "ZCA"

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Acid Fracturing
• It is basically the same as fracturing with
sand, but the conductive medium is
achieved by the dissolved rock (etching)
instead of the underpinning.
SUPRA CE

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Optimization of Acid Fracturing
• In the simplest terms, three (3) factors
influence the results:
• 1. Fracture Height
• 2. Fracture Length
• 3. Conductivity (Acid Etching)

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Fracture Geometry
Frac-Pro PT

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STIM2001 Treatment Optimization
SPE 82261 - STIM2001
“Fully Integrated Approach”

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STIM2001 Treatment Optimization

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Single high-perm zone
dominates productivity
but accounts for less
than half of reserves
Four low perm zones
are small contribution
to rate but account for
¼ of reserves
Mala distribución con HCl
directo; zonas de alta
pemeabilidad toma el mayor
%
Gel + bolas selladoras logran
buena diverencia; mejor
recuperación
STIM2001 Treatment Optimization

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Plain 28% HCl – C/TF

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28% Gelled HCl – Sealing Balls

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GuidonSM AGS
“Revolutionary divergent system technology based
on relative permeability modifiers”
• Recommended when:
• Areas of water nearby or in presence with the oil
• Mechanical isolation is not possible
• Sands or carbonates
• Numerous cases in conjunction with SIGMA analysis
• +80+ treatments to date
• Naturally fractured carbonates
•

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GuidonSM AGS
"Revolutionary divergent system technology
based on relative permeability modifiers"

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GuidonSM AGS
"Revolutionary divergent system technology
based on relative permeability modifiers"

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GuidonSM AGS
“Tecnología revolucionaria de sistema divergente
basada en modificadores relativos de
permeabilidad”

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GuidonSM AGS
"Revolutionary divergent system technology
based on relative permeability modifiers"

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GuidonSM AGS
Log-Log plot: dp and dp' [psi] vs dt [hr]
Log-Log plot: (p-p@dt=0).Q/[qn-qn-1] and derivative [psi] vs dt [hr]
S156, Historical Production
0
2
4
6
8
10
Mar-05 May-05 Jul-05 Sep-05 Nov-05 ENE-06 Mar-06 May-06 Jul-06 Sep-06 Nov-06
Time (Months)
Oil
Rate,
(MBPD)
0
10
20
30
40
50
60
70
80
90
100
Water
Cut
(%)
ACID
STIMULATED
WITH AP
DIVERTER
ACID
STIMULATED
WITH VISCOUS
SLUGS AS
DIVERTER
FLOW RATE (bbl/d)
10000
8000
6000
4000
2000
0
FLOWING
BTM
PRES
(psig)
20000
15000
10000
5000
0
Inflow/Outflow Plot
ANTES S= 22
DESPUES S= 0

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ACID FRACTURES
Halliburton Pumping Diagnostic Analysis Toolkit
Step Rate
Sinan-53
2 4 6 8 10 12 14 16 18
Gasto de bombeo (bpm)
14000
14250
14500
14750
15000
15250
15500
(2.024, 14212)
(m = 88.72)
Frac Ext (13.97, 15272)
(Y = 14210)
(17.15, 15465)
Bottom Hole Pressure (psi)
Step Rate Events
Time
21:14:21
21:20:14
21:27:15
21:33:39
21:37:32
21:43:40
21:48:14
21:55:22
21:59:02
22:04:01
22:07:43
22:12:38
22:17:29
BHP
14254
14306
14389
14485
14563
14576
14722
14794
14899
15083
15275
15371
15480
Gdb
2.004
3.006
4.007
4.999
6.011
7.003
7.963
8.965
9.966
11.97
13.88
16.02
16.96
Customer: PEMEX Job Date: 13-Jul-06 14:38:09 Sales Order #: IFS-074130706
Well Description: SINAN 53 UWI:
H A L L IB U R T O N
INSITE for Stimulation v2.4.0p1
13-Jul-06 23:27
Analisis FallOff PostFrac
Log-Log plot: dp and dp' [psi] vs dt [hr]

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ACID FRACTURES
Pozo Fmt
Inter
valo
M
Fecha
Solv
ente
M3
GE
L
PA
D
M3
Acid
o
M3
Gal/f
t
DP
(psi)
DP2
(psi)
DP
(psi)
elimi
nada
Qg
Ant
es
mm
scf
Qo
Ante
s
bop
d
Qg
Frac
mmscf
Qo Frac
bopd
DQo
May-DL1 KM 30 08-Nov-05 30 80 85 228 5,900 900 5,000 11 1,700 25 5,800 4,100
Behelae-1 KI 50 23-Ene-06 50 80 120 193 NF ND 0 0 0 0 0 0
Mison-42 KM 50 26-Feb-06 50 50 100 161 NF ND 0 0 0 0 0 0
Bolontiku-2 KS 65 02-Mar-06 40 60 120 149 5,900 2,500 3,400 3 1,800 3 3,100 1,300
03-May JSK 55 04-Jul-06 30 80 240 351 4,500 1,200 3,300 11 1,500 25 5,700 4,200
Sinan-53 KM 40 13-Jul-06 50 80 120 242 5,800 5,000 800 3 750 3 1,800 1,050
May-108
KS,K
M
66 21-Sep-06 40 80 230 281 6,000 1,500 4,500 0 0 30 10,000 10,000
May-113
KS,K
M
90 26-Sep-06 40 90 290 260 NF NF 4500* 0 0 29 10,200 10,200
Sinan-158 KM 61 20-Oct-06 40 80 190 251 NF NF 4500* 0 0 2 3,200 3,200
mms
cfd
bopd
117 39,800

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