ESTIMULACIONES ACIDAS PEMEX – Enero 07 Eduardo Soriano

Proceso SIGMA

Criterios de Selección

Criterios de Selección

Criterios de Selección

Criterios de Selección

Criterios de Selección

Criterios de Selección

Criterios de Selección

Criterios de Selección DP – 127 psi DP – 184 psi DP – 241 psi Condición Pre-Fractura – Nov05 Ptp-3100 psi Pff – 6,000 psi Qg-11MMPCD Ql – 2300 blpd (activo) S=+120 DP – 5,900 psi

Criterios de Selección 14,000 bpd S = 184 10,000 bpd

Criterios de Selección 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” S = 10 14,000 bpd S = 184 10,000 bpd

Técnicas de Estimulación y Experiencias en Carbonatos Acidificación Experiencias en Carbonatos

Retos actuales en Acidificación Gastos de Producción inadecuados después de los tratamientos de acidificación Rápida declinación en la producción Diseño de tratamiento es un problema complejo de Ingeniería Our customers face the challenge of efficiently producing Oil and Gas. They challenge HES to effectively stimulate their reservoirs. We have been driven by economics to reduce the cost of treatments possibly to the point the treatment is not the best for the well. We need to “Focus on the Rock” the reservoir to best determine the proper stimulation method. This involves taking a different look at how we acidize. Diseños son frecuentemente implementados con poco conocimiento de la formación

Carbonate 20/20 Provee soluciones a los retos actuales Mas Producción Carbonate 20/20 provee altos y sostenidos niveles de producción Aproximación Sistemática Carbonate 20/20 provee una aproximación sistematica para este problema complejo de ingeniería Carbonate 20/20 is different because it introduces more effective acid blends developed by research, more accurate engineering values to use in FRACPRO, incorporates into FRACPRO reaction rate and mass transfer equations that were in previous Halliburton acid design programs. Stim 2001 has been introduced to take much of the guess work out of designing carbonate matrix acidizing treatments. This is particularly important on long horizontal wells. We will have a candidate selection process to help everyone come to the same conclusions for consistent recommendations. Carbonate 20/20 will take advantage of the stimril reservoir simulator for aiding in deciding whether a well is a candidate for stimulation and whether matrix acidizing or fracture acidizing should be performed. Enfocado en la Roca Carbonate 20/20 incluye prueba y análisis necesarias para un mejor conocimiento de la formación

Production Performance Carbonate 20/20 Production Performance Carbonate 20/20 Carbonate 20/20 Production Increase Gasto (BPD) Convencional Carbonate 20/20 is a step by step method to determine how to acidize a well. It has a global view that incorporates both matrix and fracture acidizing. We have performed treatments in various places (including the Permian basin, California, Kansas, Mexico, etc.) that have proven that the reservoir can be effectively stimulated when a treatment is designed properly. We need to make everyone aware of the things needed for proper designs and spread across latin america and the world. Conventional Tiempo

Que es Carbonate 20/20? PLUS PLUS Sistemas de Fluidos simples Software de Ingeniería -Tool-Kit PLUS Sistemas de Fluidos simples Carbonate 20/20 is a combination of several things including new software, new acid additive packages, and a compilation of HES best practices that must be followed to allow us to design treatments that deliver true sustained production PLUS Buenas Prácticas y Técnicas de campo probadas

Carbonate 20/20 Software de Ingeniería -Tool-Kit SIGMA Stim 2001 StimWin FRACPRO PT the Carbonate 20/20 Tool Kit includes the following: Sigmalog is an HES processed log that will include stress profiles, carbonate/dolomite %, Perm from MRIL, etc. for accurate fracture height and length predictions.. Stim 2001 software with data base and advisor for stimulate carbonate and sandstone . STIMWIN is a HES program that includes information on various fluid systems, such as Rheology, fluid loss, etc. It includes a versatile graphics program and a well temperature simulator. STIMWIN can also be used to receive Remote data transmission information with a COE machine so the customer does not have to be on location. FRACPRO is a 3D fracture model that has been very effectively used for designing fracture treatments

Carbonate 20/20 Sistemas de Fluidos Simples 1. Carbonate Completion Acid 2. Carbonate Stimulation Acid 3. Fines Recovery Acid 4. Carbonate Emulsion Acid 5. Hot Rock Acid 6. Zonal Coverage Acid The Carbonate 20/20 Acid Systems takes the guess work out of additive selection. These systems are designed with “customer needs” and/or “well problems” in mind. Carbonate Completion Acid is the safest blend to use. It is an acid blend with exceptional dispersability. It contains a high performing additive package which has been shown to out perform any other blends on the market (Pemex-Mexico). Carbonate Stimulation Acid: Gelled acid to aid in zonal coverage in matrix acidizing, fluid loss in fracture acidizing, and fines transport in wellbore cleanout treatments. Fines Recovery Acid: Acid foamed with SGA-I which is a good foaming agent as well as an excellent fines suspender. Carbonate Emulsion Acid: The ultimate in retardation. Zonal Coverage Acid: Previously known as VCA but with a new emphasis in use for matrix acidizing. Hot Rock Acid: Acetic-Formic blend for when HCl must be avoided. Note the similarity between the Carbonate 20/20 and the Sandstone 2000 names. Carbonate Completion = Sandstone Completion; Volcanic=Hot Rock; etc.

Carbonate 20/20 Buenas Prácticas Acidificación Matricial Fracturamiento Acido Divergencia Pruebas de Laboratorio Identificación de Fracturas Naturales The Carbonate 20/20 Acid Systems takes the guess work out of additive selection. These systems are designed with “customer needs” and/or “well problems” in mind. Carbonate Completion Acid is the safest blend to use. It is an acid blend with exceptional dispersability. It contains a high performing additive package which has been shown to out perform any other blends on the market (Pemex-Mexico). Carbonate Stimulation Acid: Gelled acid to aid in zonal coverage in matrix acidizing, fluid loss in fracture acidizing, and fines transport in wellbore cleanout treatments. Fines Recovery Acid: Acid foamed with SGA-I which is a good foaming agent as well as an excellent fines suspender. Carbonate Emulsion Acid: The ultimate in retardation. Zonal Coverage Acid: Previously known as VCA but with a new emphasis in use for matrix acidizing. Hot Rock Acid: Acetic-Formic blend for when HCl must be avoided. Note the similarity between the Carbonate 20/20 and the Sandstone 2000 names. Carbonate Completion = Sandstone Completion; Volcanic=Hot Rock; etc.

Fracturamiento Acido  TECNICA SUPRA-CE  HOT ROCK ACID “HRA”  ZONAL COVERAGE ACID “ZCA”  ACIDO ENCAPSULADO

TÉCNICA DE TRATAMIENTO : SUPRA - CE™ “SUstained Production Acidizing - Conductivity Enhancement” Beneficios : Grabado Diferencial Mayor Longitud de Fractura Grabada

HOT ROCK ACID “HRA” Capacidad de disolución igual a un HCl al 15% Combinación de Ácidos Orgánicos Mayor Penetración del Acido Vivo = Mayor Longitud de Fractura Grabada

ZONAL COVERAGE ACID “ZCA” Cruzamiento in situ - reologías desde 25 a 500 cp. Acido gelificado para el control de pérdida de fluido en fracturamientos ácidos. Fracturas más largas y conductivas. Excelente capacidad de transporte de finos. Agente divergente El ZCA puede emplearse en etapas con otros sistemas ácidos como parte de la Técnica SUPRA Acido con gel lineal permite demasiada perdida de fluido y generación de agujeros de gusano, gastándose en la vecindad del pozo El sistema ZCA limita el crecimiento continuo de los agujeros de gusano conservando el ácido vivo para una mayor penetración

Desviacion CON “ZCA”

Fracturamiento Acido Basicamente es lo mismo que el fracturamiento con arena, pero el medio conductivo es conseguido por la roca disuelta (grabado) en lugar del apuntalente. The 3 fundamentals of fracture acidizing are 1) proper reactivity control, 2) fluid loss control, and 3) conductivity generation. The first two fundamentals mostly control which fluid we will select for the stimulation treatment. We want to choose a slow reacting fluid for high temperature applications but a fast reacting fluid for low temperature applications. At the same time, we know that the first step in providing acid fluid loss control is to viscosify the acid. So, choosing the right Carbonate 20/20 fluid for fracture acidizing involves choosing a viscous fluid with the right reactivity for the rock we are trying to stimulate. The third fundamental determines how we are going to place the acid in the fracture for obtaining SUstained PRoduction from Acidizing. We must generate uneven etching in the created fracture and the etching must be capable of supporting the conductivity after closure. This becomes an engineering design challenge controlled largely by the rock rather than simply a fluid selection process. SUPRA CE

Optimización del Fracturamiento Acido En los términos mas simples, tres (3) factores influyen en los resultados: 1. Altura de Fractura 2. Longitud de Fractura 3. Conductividad (Grabado de Acido)

Geometria de Fractura Frac-Pro PT This is a very simplified view of an acidized formation. Parameters of interest are the hydraulic fracture length, the rate at which acid spends as it travels from the wellbore into the fracture, and the etched (or effective) fracture length. In order to estimate the production increase which may be obtained following a treatment, these parameters must be determined. Fracture Height: The height that the fracture grows. This may or may not be the same as the zone height. If a 2D simulator is used, this dimension of the fracture is part of the input parameters. Fracture Width: The width created by the fluid as it creates the fracture. As the width increases, the distance that hydrogen ions must travel to reach the fracture face increases, therefore the spending rate will decrease. In addition, tan increase in width will decrease the velocity of the fluid traveling down the fractures. This decreases the turbulence which decreases the mass transfer and therefore the acid spending rate. Created Fracture Length: The hydraulic or created fracture length is the entire length of the fracture that was created by the fluid. Much of this is spent acid and does not generate conductivity. The length term of interest is the Effective Fracture Length. This length has conductivity and contributes to the production increase.

STIM2001 Optimization del Tratamiento SPE 82261 - STIM2001 “Fully Integrated Approach”

STIM2001 Optimizacion del Tratamiento

STIM2001 Optimization del Tratamiento 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 Fluid placement and diversion simulations: Of seven Khuff layers, one is high conductivity, two medium, and four low, causing large injectivity contrast across formation. Placement scenarios: 1. Placement of 28% HCl with CT, showing fairly good penetration of acid into lowest two low-perm zones, but high-perm zone C5 steals most of acid, resulting in minimal coverage of upper zones. (click graph for video animation) 2. Placement of 28% HCl with ball sealers in three ZCA diverter stages, showing effective blockage of C5 high-perm zone and good distribution of acid to all zones. (click graph for video animation)

Plain 28% HCl – C/TF

Plain 28% HCl – C/TF Pobre divergencia con el uso de 28% de HCl. Zonas de alta permeabilidad tomando la mayoría del acido. El resto estimuladas pobremente

28% HCl Gelificado – Bolas Selladoras

GuidonSM AGS “Tecnologia revolucionaria de sistema divergente basada en modificadores relativos de permeabilidad” Recomendado cuando: Zonas de agua cercanas o en presencia con el aceite Aislamiento mecanico no es posible Arenas o carbonatos PEMEX Success Numerosos casos en conjunto con analisis SIGMA +80+ tratamientos a la fecha Carbonatos naturalmente fracturados

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

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

CHUC 63 Well completed on Dec 2004. with a oil production of 1,227 bopd, and 20 % of water cut by 1 ½” choke size ( water cut remains with chokes of ¾ and 1”.) By Feb 2005, oil production dropped up 245 bopd and 16% water cut. Time later, well is shut in because only gas was being produced. Well is stimulate with acid + Guidon nitrified one month later Last data Qo= 3,730 bopd and water cut of 0 % by @ 1 3/8” @ 31/11/06 SPE 103771

CAAN 73A Lower Interval is sealed off because of high water cut. It is perforated in a new zone 18 m above top of watered out one. Stimulated with acid + Guidon nitrified Well is put on production with no water cut. Last Production data 3,652 bopd and 0% of water cut.

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

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

GuidonSM AGS ANTES S= 22 DESPUES S= 0

FRACTURAMIENTOS ACIDOS

FRACTURAMIENTOS ACIDOS Pozo Fmt Intervalo M Fecha Solvente M3 GEL PAD M3 Acido M3 Gal/ft DP (psi) DP2 (psi) DP (psi) eliminada Qg Antes mmscf Qo Antes bopd Qg Frac mmscf Qo Frac bopd DQo May-DL1 KM 30 08-Nov-05 80 85 228 5,900 900 5,000 11 1,700 25 5,800 4,100 Behelae-1 KI 50 23-Ene-06 120 193 NF ND Mison-42 26-Feb-06 100 161 Bolontiku-2 KS 65 02-Mar-06 40 60 149 2,500 3,400 3 1,800 3,100 1,300 03-May JSK 55 04-Jul-06 240 351 4,500 1,200 3,300 1,500 5,700 4,200 Sinan-53 13-Jul-06 242 800 750 1,050 May-108 KS,KM 66 21-Sep-06 230 281 6,000 10,000 May-113 90 26-Sep-06 290 260 4500* 29 10,200 Sinan-158 61 20-Oct-06 190 251 2 3,200   mmscfd bopd 117 39,800

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