Techincal Proposal - Drilling_Fluid_Program_EL JEFE 01

8/12/2019 Techincal Proposal - Drilling_Fluid_Program_EL JEFE 01

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Propietario: Global Operations Manager Documento #: TEM-GL-HAL-DF-102-L1Aprobado por: Dennis Lynch Revisin: A Date: 26-Feb-14

1

PETROMEJOR COMPANY

DRILLING FLUID PROPOSAL

El Jefe-01

Latin America

Prepared by: Danny CastellanosBaroid Field Supervisor

Signature:Date:

18/07/2014

Prepared by : Luis DuranBaroid Field Supervisor

Signature: Date:18/07/2014

Reviewed by:Operations Manager

Signature:Date:

18/07/2014

Approved by:Drilling Engineer PetroMejor

Signature:Date:

18/07/2014

Version No. 1 Version Date: 18/07/2014


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Technical ProposalEl Jefe-01

Viking Reference: 252520, 226139, 180716, 177473, 97497, 92987, 297790.

Table of Contents

1. .............................................................................................................PROJECT ABSTRACT 4

1.1. .......................................................................................................................Proposal briefing 41.2. ....................................................................................................................... WELLPROFILE 51.3. .........................................................................................................MECHANICAL STATUS 61.4. .................................................................................................................... CASING DESIGN 61.5. ................................................................................................... POTENTIAL WELL ISSUES 71.6. .................................................................................................................. FLUID PROGRAM 91.7. ....................................................................................................PROJECT SUPPORT TEAM 9

2. ............................................................................................................... FLUID PROPERTIES 10

2.1. ....................................................................................................Recommended Concentration 122.2. .................................................................................................................... Estimated volumes 13

3. ............................................................................... 16 SECTION INTERVAL DISCUSSION 14

3.1. .......................................................................................................................Primary Products 153.2. .................................................................................................................... Potential Problems 153.3. ..............................................................................................Fluid maintenance and comments 163.4. ...................................................................................................................Mud quality control 163.5. .................................................................................................................... SCE Requirements 163.6. .....................................................................................................................Recommendations 17

4. ........................................................................... 12 SECTION INTERVAL DISCUSSION 18

4.1. .......................................................................................................................Primary Products 204.2. .................................................................................................................... Potential Problems 204.3. ..............................................................................................Fluid maintenance and comments 214.4. .................................................................................................................... SCE Requirements 224.5. .....................................................................................................................Recommendations 23

5. ............................................................................. 8 SECTION INTERVAL DISCUSSION 24

5.1. .......................................................................................................................Primary Products 255.2. .................................................................................................................... Potential Problems 255.3. ..............................................................................................Fluid maintenance and comments 265.4. .................................................................................................................... SCE Requirements 275.5. .....................................................................................................................Recommendations 28


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6. ................................................................................................................Terms and Conditions 29

7. ........................................................................................... PROPOSED WINDOW DENSITY 30

ANNEXES ...................................................................................................................................... 31

7.1. .........................................................................................................................HYDRAULICS 317.2...............................................THREE DECISIONS FOR LOST CIRCULATION INCIDENTS 357.3. ..................................................................... LOST CIRCULATION PILLS FORMULATION 367.4. ...............................................................................................CAVINGS ANALYSIS CHART 377.5. ...................................................................................................PARTICLE DISTRIBUTION. 387.6. ........................................................................... STANDARD OPERATING PROCEDURES. 39


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1. PROJECT ABSTRACT

1.1. Proposal briefing

Enclosed is our recommended procedure for Drilling Fluid Services in the referencedwell. The information in this proposal includes well data, calculations and materialrequirement.

This proposal is based on our experience in similar wells in the area and informationprovided by PetroMejor.

Halliburton appreciates the opportunity to present this proposal for your considerationand we look forward to being of service to you. Our Services for your well will becoordinated through the Service Center listed below.

If you require any additional information or additional designs, please feel free tocontact myself or our field representatives listed below.

Prepared and Submitted by:Danny Castellanos, Luis DuranTechnical Professional

OPERATIONS MANAGER: Lenin Tigrera

ACCOUNT REPRESENTATIVE: Daniel BarrosTECHNICAL MANAGER: Christian BajukPHONE NUMBER: 593 - 23971700


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1.2. WELLPROFILE


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1.3. MECHANICAL STATUS

Hole diameterTop MD

(ft)End MD (ft) Bit Size (in) Length (ft)

Max. angle

16 0 5569 16 5569 20

12 5569 9307 12.25 3738 20

8 9307 11333 8.5 2026 10

1.4. CASING DESIGN

Description End MD (ft) CSG ID (in) CSG OD (in) Bit Size (in)

CSG 13 3/8 5569 12.347 13.375 16

CSG 9 5/8 9307 8.681 9.625 12.25

7Liner 11333 6.276 7.000 8.5


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1.5. POTENTIAL WELL ISSUES

Note: hole cleaning and lost circulation cases ALLWAYS must be considered like a potential issue atany well section. In appendix below you will find detailed information about it.

Depth(ft)

Mud type Exp.Density(ppg)

Exp.Fracturegradient

Potential issues Baroid Solutions

0 / 5569 AQUAGEL CALCIUMNITRATE

8.6 /10.7

Unknown

Hole cleaning.

Bombearpldoras de altaviscosidad

Bit balling / Claysticking / Gumbo

Running CasingProblems

Pldora conTensioactivo

Aumentardilucin

Incrementardensidad

Pump high viscosity

sweeps. Circulate toensure hole cleaning.

Pump sweep with highconcentration of AKTAFLO-S. Increase surfactantconcentration in activemud system.

Follow recommendationsof AFO Monitoring Servicesrelated to running casingspeed, circulation stations,higher pressure or tighthole.

5569 /

9307 CLAYSEAL9.6 /11.8 Unkown

Seepage losses/Severe lost circulationcases

Hole cleaning

Hole instability

Increase bridging materialconcentration LCM W/(20-100 PPB). Add directly tothe active system LCMmaterial while drilling thiszone.

Pump high density sweepsto improve hole cleaning.Circulate periodically tooptimize annulus cleaning.

Increase mud density inactive system as required.


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Running CasingProblems

STEEL SEAL, BAROTROLadditions.

Follow recommendationsof AFO Monitoring Servicesrelated to running casing

speed, circulation stations,higher pressure or tighthole.

9307/11333

CLAYSEAL9.6 /10.0

Unknown

Seepage losses/Severe lost circulationcases

Hole instability

Hole cleaning

Oil/gas influx

Running linerProblems

Increase concentration ofbridging material LCMW/(20-100 PPB).

Increase sealant materialconcentration: STEELSEAL. Increase mud

density in active system asrequired

Circulate periodically inorder to ensure holecleaning. Pump highdensity sweeps to improveannulus cleaning.

Increase mud density inactive system as required.

Follow recommendations

of AFO Monitoring Servicesrelated to running casingspeed, circulation stations,higher pressure or tighthole.


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1.6. FLUID PROGRAM

1.7. PROJECT SUPPORT TEAM

Hole

diameterFluid Type

Density

(ppg)Flow Rate (gpm)

BHT,oF

16 AQUAGEL 8.410.5 850 120

12 CLAYSEAL 9.611.5 700 200

8 CLAYSEAL 9.610.3 550 220

Title Name Cell Number Office Number Email address

Technical Professional Danny Castellanos +593994371732 3971700 Ext 2670 [email protected]

Operations Leader Lenin Tigrera +593997745511 3971700 Ext 3344 [email protected]

Lead Field Rep. Ali Sotillo +584163184965 3971700 Ext 3342 [email protected]

Lead Field Rep. Reinaldo Gomez +584249625690 3971700 Ext 3342 [email protected]

Field Rep. Hector Salazar +584162869530 3971700 Ext 3342 [email protected]

Field Rep. Lenin Solorzano +593995364644 3971700 Ext 3342 [email protected]

Lab Technician Rodolfo Ponce +5731254482899 3971700 Ext 2911 [email protected]

Service Coordinator - Coca Diego Baldeon +593999045658 3971700 Ext 1652 [email protected]

Business Development Daniel Barros +593994015849 3971700 Ext 2665 [email protected]

Technical Manager Christian Bajuk +593998272178 3971700 Ext 2653 [email protected]

Country Manager Hector Cruz +593999909512 3971700 Ext 2651

[email protected]
mailto:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]:[email protected]


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2. FLUID PROPERTIES

OBJECTIVES AND METHODS

Maintain a good hole cleaning during all sections.

No stuck pipe incidents.

No drilling or completion fluids spills that can cause environment damage.

To provide a fluid that minimize interactions between fluid and formations reducing problems such asbit balling, hole instability, high torque, drag, washouts, etc.

To maintain enough stock of chemicals including contingence materials for covering any eventualityduring drilling.

To guaranties adequate conditions in order to perform cement jobs.

No lost time incidents related with drilling or completion fluids.

To promote HSE policies, especially PPE use.

To assure good communication in order to coordinate logistic.

To work as a team with solid control equipment, environmental management and with all companiesinvolved in the operation


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16SECTION

Surface5569 ft (MD).

AQUAGELCALCIUM NITRATE MUD

Properties Units Min Max Properties Units Min Max

Density Ppg 8.6 10.7 3 / 6 rpm 6 / 8 14 / 19

Funnel Viscosity sec/qt 31 46 MBT ppb eq. N/C

Plastic Viscosity cP 8 12 pH 8.4 9.0

Yield Point lbf/100_ft2 14 20 API Filtrate mL/30min N/C

12 SECTION

5569 ft - 9307 ft (MD)

EZ MUD DPCLAYSEAL


Density Ppg 9.6 11.8 3 / 6 rpm 6 / 7 17 / 19

Funnel Viscosity sec/qt 40 70 MBT ppb eq. 7.5 < 25.0

Plastic Viscosity cP 13 29 pH 8.5 9.1

Yield Point lbf/100_ft2 18 33 API Filtrate mL/30min< 8.0

< 5.5

8 SECTION

9307 ft11333 ft (MD)

EZ MUD DPCLAYSEAL


Density Ppg 9.6 10.0 3 / 6 rpm 5 / 7 11 / 13

Funnel Viscosity sec/qt 46 51 MBT ppb eq. 2.0 < 7.5

Plastic Viscosity Cp 14 19 pH 8.5 9.4

Yield Point Lbf/100_ft2 19 30 API Filtrate mL/30min < 6.0< 5.0


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LITHOLOGY PROGNOSIS

2.1. Recommended Concentration

Product

16"Section

12-1/4"Section

8-1/2"Section

Conc.Lb/BBl

Conc.Lb/BBl

Conc.Lb/BBl

AKTAFLO-S 0.50 1.00 0.50 1.00

AQUAGEL 2.00 4.00

ALDACIDE G 0.10 0.30 0.10 0.30

BARAZAN D PLUS 0.10 0.20 0.50 0.75 0.50 1.00

BAROFIBR FINO 0.20 0.40 0.30 1.00

BAROLUBE GOLD SEAL 3.00 4.00

BAROID 20.00 30.00 97.00 183.00

BAROTROL PLUS 0.50 1.00 2.00 3.00

CaCO3 - fine ( D50:10 mic) 5.00 10.00 50.00 70.00

CaCO3 - medium(D50:50 mic) 5.00 15.00 30.00 50.00

CARBONOX 0.50 0.50

Caustic Soda 0.05 0.20 0.30 0.40 0.30 0.50

CLAYSEAL PLUS 2.00 3.00 3.00 4.00 3.00 4.00

FILTER-CHEK 1.50 2.00 1.50 2.00

PAC L 0.50 1.50 0.75 1.50

PAC R 0.20 0.50 0.75 1.00

X-TEND 0.01 0.20


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2.2. Estimated volumes

5,569 5,569 9,307 9,307 11,333

5683 Ft 13 3/8 3738 Ft 9 5/8

5569 Ft 16 Pulg 3738 Ft 12 1/4 Pulg 2026 Ft 8 1/2 Pulg

500 500 500

842 12 1/3 ID 681 8.68

1385 16 Pulg 545 12 1/4 Pulg 142 8 1/2 Pulg

2134

8 1/2 Pulg.

2260

12 1/4 Pulg.

2134Required volume, bbl 2999

9 5/8

CLAYSEALFluid system CLAYSEAL

13 3/8 LINER 7

2999 2260

810

Previous casing length, ft

Open hole length, ft

Previous casing volume, bbl

Interval 8 1/2Interval 12 1/4

Surface volume, bbl

Total Volume, bbl:

Previous section volume, bbl

Interval 16

Dilution volume, bbl

Open hole volume, bbl

1114 374

16 Pulg.

AQUAGEL - CALCIUM

NITRATE

Hole size

Casing diameter

Depth

El Jefe 01


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3. 16 SECTION INTERVAL DISCUSSION

For the previous problems presented drilling on Sankofa PM-117 field this proposal include like solution the

implementation of the AQUAGELCalcium Nittrate Fluid System to drill this interval.

The exelent response of the AQUAGEL Calcium Nittrate Fluid System reducing hidratation rate of the high

reative clays offer a exelent solution for running casing issues and foaming Gumbo.

For the firsts feet and previous the second BHA change, approximately to 500 ft depth or until be sure no more

fluid losses are showed, a short circuit system with AQUAGEL pre-hydrated.

For previous well experience, pills of 20 bls with 20 ppb to 40 ppb of LCM can be pumped every single drilled

from conductor to first BHA change in case of evidence of lost circulation. Like contingency can be prepared 160

bls of LCM with 60 ppb to 80 ppb of concentration ready to be pumped in case of severe loss of circulation.

AQUAGEL concentration will be diluted in order to reach programmed properties. AKTAFLO and SAPP to avoid

plugging of lines when Gumbo Clay is drilled will be added to the system.

Once directional BHA run in hole the AQUAGEL system will be changed for the AQUAGEL CALCIUM

NITRATE Drilling Fluid System to be used all the section long.

AQUAGEL (Bentonite) in a 1015 ppb concentration will be mixed in reserve tanks in order to use it as viscous

pills, once directional BHA is working sweeping pills will be pumped every three stands. CALCIUM NITRATE

concentration will be diluted in order to reach programmed properties.

AQUAGELCALCIUM NITRATE Drilling Fluid System helps to keep good rheological properties, to get an

adequate filter cake to stabilize wellbore and to minimize superficial loss circulation problems.

After 500 ft or until be sure no more fluid losses are showed, AQUAGEL CALCIUM NITRATE Drilling Fluid

System is characterized for initial low rheological values (YP: 3 - 5 [lb/100 ft2]), this minimizes flow line plugging

and bit balling problems and allows to reach good ROP.

Appropriate hole cleaning will be reached using a minimum recommended flow rate of 850 950 gpm and using

sweep pills (can be weighted and prepared with BAROLIFT) according to hole cleaning simulation provided for

DFG Plus Software.

AKTAFLO will be added constantly in order to minimize bit balling issues. AKTAFLO is a no-ionic surfactantthat reduces interfacial tension between water, solids and clay, in this way Gumbo problem will be minimized.

Dispersants like SAPP could be added for maintaining low rheological values and minimize flow line plugging.

It is important to clean flow line and possum belly during drilling time and during each connection, this minimizes

flow line plugging and clay accumulation. Add dispersants like CARBONOX to keep low rheological values in

the system 0.2 ppg, pump disperse pills with SAPP (24 ppb), to help to clean the system.

Before running 13 3/8 casing it is recommended to increase the mud weight to compensate the ECD and tospot a higher lubricity and viscous pill with bridging material to cover Orteguaza Formation at bottom.


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3.1. Primary Products

3.2. Potential ProblemsLost Circulation: Total lost circulation problems at the beginning of the section can be reduced through a pill

containing: 15 ppb AQUAGEL, 15 ppb WALL NUT, 15 ppb KWIK SEAL, 60 ppb CaCO3 40-100/200. This pill

has to be pumped and left on bottom hole about 3 hours. Once drill string is on bottom hole again, drilling should be

begun with controlled parameters until to go deeper and to check if fracture has been sealed. Products and

concentrations can be changed depending on circumstances, refer to 7.2 LOST CIRCULATION PILLS

FORMULATION section.

Bit Balling: It is important to prevent this problem with HSI optimization and adequate hydraulic. In the case

of bit balling it should be treated using dispersed pill as following: 50% mud, 50% water, 10 ppb SAPP, 3-5%volume of AKTAFLO, 15 ppb WALL NUT, trying to increase pill effectiveness, once the pill achieves bottom

increase RPM of the string and flow rate during the time pill pass through the bit. Recommended volume isabout 30 bbl. AKTAFLO - S concentration is determinate from accretion test performed with severalformations.

Hole Cleaning: Hole cleaning must be optimized pumping sweep pills every two stands or according DFG

simulation.

Product Function Description

AKTAFLO-S Surfactant Alquil fenol oxietilenado

AQUAGEL Viscosifier Montmorillonita sdic modified

BARAZAN D PLUS Viscosifier Biopolmer Xnthic

BAROID Densifier Agent Barium Sulfate

CARBONOX Dispersant Leonardite

CAUSTIC SODA Alkalinity source Sodium Hidroxide

BARO-TROL PLUS Shale Estabilizer Sulfonated Asfalt

Clayseal Plus Shale Inhibitor Exfoliated Poliamine

X-TEND II Extendedor de bentonita Copolmero de poliacrilato/poliacrilamida


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3.3. Fluid maintenance and comments

Bentonite must be premixed in fresh water in order to improve its efficiency, if necessary add ash soda

to mix water to precipitate hardness excess and thus optimize gel performance.

pH values must be maintained between 9.0 9.5 through Caustic soda or lime additions as required.

Maintain an adequate SCE performance in order to prevent excessive dilution rates.

Fluid Density must be as low as possible according to well behavior. In case a mud weight increase is

needed, it will be agreed with the customer representative; on location will have enough contingency

material available.

Prior to run Surface casing, it is recommended to circulate until ensuring hole cleaning and if needed,

pump high viscosity sweep in order to optimize annulus cleaning.

3.4. Mud quality control

During normal drilling operations one complete mud check should be run every 8 hours with a lagged sample

tested. This is a total of four complete checks made over a 24-hour period. Timing for mud checks and cost

cut-off should be worked out with the drilling foreman. Unusual circumstances and/or non-circulating periods

should dictate deviations from this schedule.

All rheological properties (i.e. 6-speed readings and gel strengths, including 30-minute gels) should be taken at

-speed readings from latest mud check on daily report.

3.5. SCE Requirements

Multiple, linear motion shale shakers are recommended in order to maximize the system solids removal

efficiency. Run all available solids control equipment to prevent solids build-up.

All shale shakers should be "screened up" with finer mesh screens whenever possible without the loss of

drilling fluid off the end of the shakers.

The shale shakers should be continuously monitored for the proper distribution of drilling fluid across the

screens to fully utilize the entire surface area of the screens. The drilling fluid should cover 2/3 to 3/4 of the

length of the screens. Damaged screens should be promptly changed.


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If near size particle blinding occurs, an attempt should be made to "screen-up to alleviate this problem. If

"screening-up" does not solve this situation, then coarser mesh screens must be installed until past this

formation.

Mud Conditioner or Mud Cleaner

It is recommended to use a mud cleaner to accomplish the maximum removal of drill solids. The screen should

be as fine as possible while utilizing the mud cleaner for this purpose. This will maximize the drill solids

removal efficiency while maintaining drilling fluid properties within the prescribed parameters.

3.6. Recommendations

Flow rate for 16section about 900 - 1000 gpm

First 500 ft drilled or until have no more fluid losses to drill with controlled parameters < 500 gpm, to

minimize superficial fractures. After finish to drill every stand reciprocate the pipe cleaning the hole for at least 12 minutes to ensure

the hole cleaning specially having lower flow rates.

Ensure good jet cellar operation.

After each drilled stand, ream it twice using maximum flow rate and RPM in order to smooth drilledhole

Pump viscous, heavy or sweeping pills with BAROLIFT according DFG Software simulations.

Before wiper trip it is necessary to circulate viscous or sweeping pills with BAROLIFT during therecommended period of time according to DFG Software or until shakers are clean.

Spot a heavy and viscous pill before casing run.

Use screens with mesh as fine as possible.

Before running casing increase mud weight to ECD.

It is important that all mud engineers, rig personnel, mud logging people and supervisor check pitslevel and flow rate in case an influx or lost present.


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Halliburton Baroid recommends using CLAYSEAL system that it is design with the necessary requirements to

drill this section.

In addition to the problems related to shale is recommended for this interval, EZ-MUD DP borehole

stabilizing dry synthetic polymer contains high molecular weight partially hydrolyzedpolyacrylamide/polyacrylate (PHPA) copolymer

The use of EZ-MUD DP dry polymer assists and promotes the following:

Stabilize reactive clay and shale formations

Keep trench excavation open during the construction

Produce high viscosity solids-free slurry

Enhance rheological properties of a low-solids drilling mud

Enhance core recovery in continous wireline coring operations

Flocculate non-reactive solids in reserve pit at low concentrations

Reduce torque and drag.

In addition like advantages with the use of EZ-MUD DP are:

Can disperse easily with minimal shear

Efficient shale/clay stabilizer and viscosifier

Helps impart high degree of lubricity

Compatible with other drilling fluid additives when added in proper sequence

Non-fermenting

No petroleum distillates involved

Breaks down chemically with bleach (sodium hypochlorite)

NSF/ANSI Standard 60 Certified

Using CLAYSEAL allows to capsulate and to inhibit clay and shale which minimizes dilution, material use

and tight hole and reaming problems during trips. This system provides wellbore stability, inhibition for drilled

shale and good conditions during trips and casing runs.

Basically CLAYSEAL is a non dispersed system that combines capsulation and inhibition properties of EZ

MUD DP with stabilization and inhibition provided for CLAYSEAL. EZ MUD DP is highly effective stoppingclay minerals dispersion, hydration and swelling in this way it provides excellent shale stability. EZ MUD DP

combats superficial swelling of drilled clays directly.


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CLAYSEAL system has all the advantages of a system with low solids content. Drilled solids keep theirintegrity due to capsulation and they are easily removed through primary solids control equipment. This low

solids content system provides higher ROP and minimizes mechanical parts wear.

It is necessary to add constantly EZ MUD DP and CLAYSEAL as shale inhibitor in order to maintain good

inhibition and encapsulation properties. At the beginning of the section EZ MUD DP concentration should notexceed 0.2 ppb in order to avoid mud losses through shakers then concentration must be increased to

programmed concentration. This product will be used before Napo formation, in order to control Tiyuyacu and

Tena plastics and reactive clays.

Initial CLAYSEAL concentration will be recommended concentration and it will be maintained while drilling.

BAROTROL, BAROFIBRE & STEEL SEAL were included in the mud formulation to provide sealing

capacity to the system to help in hole stability. The hole stability problems observed in the drilling of shaleshow the importance of maintaining enough quantity of sealing agents which along with the mud density will

provide hole stability by sealing shale micro-fractures.

Additionally use Sized Calcium Carbonate (40-100, 200) as complement of BAROTROL, BAROFIBRE &

STEEL SEAL. Calcium Carbonate particles will bridge in shale micro fractures or sandstone porous helpingin Wellbore stability, reducing fluid loss and creating an good quality filter cake that minimize stuck pipepossibilities.

These additions also will help in minimizing differential sticking possibilities in addition with BAROLUBEG.S. additions, while helping in hole stability.

Before running 9 5/8 casing it is recommended to increase the mud weight to compensate the ECD and tospot 60 bls of a higher lubricity and viscous pill with bridging material to cover the bottom.

Sweeps Program

Pump Viscous and/or Heavy Pills with mud from the active system with minimum 40 bbl and monitoringcuttings return. BAROLIFT can be used as a complement in these pills. DFG Hole Cleaning Simulations will

be run daily to determine pills schedule, evaluate any change in mud properties or drilling parameters.

It is very important to monitor constantly shape, size and quantity of cavings in conjunction with Mud

Logging. Right interpretation of these parameters could help us to take decisions about mud weight, sealingand bridging agentsconcentrations.


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Producto Funcin Descripcin

AKTAFLO-S Surfactant Alquil fenol oxietilenated

BARAZAN D PLUS Viscosificifier Xanthic Biopolmer

ALDACEDE G Biocide Glutaraldehide

Barofibre Fine LCM Additive Celuloce fibre

BARO-LUBE GOLD

SEALLiquid lubricant Mixture of lubricants and surfactants

BAROID Densifier Agent Barium Sulfate

CALCIUM CARBONATE Densifier Agent Calcium Carbonate


BARO-TROL PLUS Shale Estabilizer Sulfonated Asfalt

CLAYSEAL PLUS Shale Inhibitor Exfoliated Poliamine

FILTER-CHEK Filtration Control Agent Modified starch

PAC L Filtration Control Agent Polianionic Celulose

PAC R Filtration Control Agent / Viscosifier Polianionic Celulose

4.2. Potential Problems

Lost circulation: It is necessary to use bridging material as CaCO3and to pump plugging pills if it is necessary,

refer to 7.2 LOST CIRCULATION section.

Hole instability: this problem is reduced using an adequate density program and sealing agents as STEEL SEAL as

required.

Stuck pipe: this problem could be reduced using bridging, sealing and lubricants agents.

Inhibition:CLAYSEAL PLUS addition will provide enough inhibition for reactive clays and shale. EZ MUD DP

(PHPA) and CLAYSEAL PLUS concentration was optimized by Linear Swell Meter Test.


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Tight hole:this issue is solved using an adequate mud density, besides to improve filtration rate control adding at

the same time sealing and bridging materials for this formation.

Formation damage:this mud system provides a unique environment which has been designed to protect reservoir.

Used products have been proved as reservoir friendly.

Hole Cleaning: It is important to monitor returns and to run DFG simulation in order to optimize sweep pills

frequency.


If cutting sticking on shakers is observed Clayseal Plus concentrations will be increased.

If hole cleaning needs to be optimized, by increasing low rpm readings and Tau zero, small amountsof Barazan D Plus should be added to the active system.

In case of formation instability symptoms are detected, add Barotrol Plus directly into active system in

order to seal micro fractures.

Optimize SCE performance in order to keep LGS concentration and fluid properties according mud

program during the interval.

At the beginning of section it is recommended to use on shale shakers 84 mesh screens since drillingfluid is cold and may have a high and unusual viscosity, once mud temperature increase, programmed

shaker screens will be placed to minimize solid incorporation.

It will be used DFG drill ahead softwareand AFO Monitoring recomendations to monitor hole

cleaning and predicting rheology and density profiles in function of bottom hole temperature.

If formation instability is detected while drilling this interval, it is recommended to add sealant

material (Barotrol Plus). Minimum concentration to be used will be 2 ppb of asphalt and sized

calcium carbonate, if these concentrations need to be increased it will be decided depending on hole

conditions in agreement with costumer representative.

Fluid displacement


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Activities to be performed prior to fluid displacement:

1) A complete equipment cleaning (pits, shakers, SCE, flow line, trip tank, suction lines and mixing devices)

must be performed.

2) Perform a safety meeting prior to mud discharge/preparation. Assign roles.

3) Build Clauseal fluid system according to mud program.

4) Build spacers I, II and III.

Procedures during fluid displacement:

1) RIH until to the top of cement. Pump spacers I,II and III.

2) Perform suction pit change and starting pumping Clayseal system, rotate drill string while displacement is

performed, keeping pump rate constant. Suction pit level will be maintained constant transferring in first place

OBM from auxiliary pits. Fluid displaced will be transferred to storage tanks, when diesel returns will be

transferred by ditch to slug pit.

3) In case of having a mud logging unit, this will control together with driller total pump strokes, informing to

mud engineer and derrick man in order to be prepared to Clayseal mud returns.

4) Once Clayseal fluid returns to surface will be enabled all mud active circuit until normalize in/out mud

weight.

4.4. SCE RequirementsMultiple, linear motion shale shakers are recommended in order to maximize the system solids removal





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If near size particle blinding occurs, an attempt should be made to "screen-up to alleviate this problem. If"screening-up" does not solve this situation, then coarser mesh screens must be installed until past this

formation.





Before tripping, running casing, etc. we recommend that the shaker screens be cleaned with a high- pressure

water spray after circulation has stopped. This will greatly increase screen life and prevent dried drilling fluid

and cuttings from blinding the screens when drilling resumes.


Minimum flow rate 850 [gpm].

After each drilled stand, ream twice using maximum flow rate and RPM in order to smoothen drilled hole.

Pump viscous weighted sweep pills with BAROLIFT every 300 ft or according DFG Software

simulations. Previous to trip it is necessary to circulate a weighted pill with BAROLIFT during recommend time

according to DFG Software simulation.

Perform wiper trips maximum every 30 drilling hours.

After each trip in clays zone before reaching the bottom of the hole (30 ft previous bottom) pump an anti-bit balling pill in order to clean bit before drilling. This pill can be prepared using 15 ppb WALL NUT.

Increase the mud weight to compensate the ECD.

To spot a higher lubricity and heavy weighted pill reaching casing point and if extra loggings run isprogrammed.


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For these section Clayseal will be used, it is design for reservoir zones due to its low solids content and

friendly formation products characteristics. Furthermore its bridging design allows a minimum invasion.

Right Sizing CALCIUM CARBONATE with adequate hardness and good quantity will ensure minimum

invasion and cake deposition on external well face.

The selective calcium carbonate micron size will be used to bridge the porous reservoir formation. It isimportant to maintain the concentration of a defined range of bridging solids; as a result, continuous additions

will be made while drilling.

Filtrate value must be below 6 cc, other way to control filtrate value will be constant addition of Calcium

Carbonate from different screen size (200 and 40-100). A Cleaning Sweeps program will be prepared previous

beginning of this interval.

Clayseal rheology will guarantee hole cleaning and reduce washout occurrence. System helps to maintain lowfiltrate values, too.

Clayseal should be prepared as a new system, free of drilled solids. At the same time invasion volumes are

reduced due to high rheological values that reduce filtrate flow tendency.

The DRIL-N system recommended to drill this interval is formulated with BARAZAN, FILTERCHECK,

Calcium Carbonate, Caustic Soda, ALDACIDE-G is used as preservative. This mud system provides an

environment which has been designed to improve reservoir protection. PAC could be added if mud conditionsare required.

Additionally, filtration rate and seal quality are controlled through right CARBONATE distribution inside

system (Carbonate particles are deteriorated on shakers and bit nozzles).It is recommendable to add Carbonates mesh 40-100 and 200 periodically (every hour) in order to have a great

quality bridging.

CLAYSEAL PLUS is used to treat shale; it provides shale stabilization and inhibition.

Before running 4 1/2 liner it is recommended to increase the mud weight to compensate the ECD and to spot

60 bls of a higher lubricity and viscous pill with bridging material to cover the bottom.

Sweeps Program

Pump tandem pills of heavy or sweeping pills with mud from the active system and monitoring cuttings return.

DFG Hole Cleaning Simulations will be run daily to determine pills schedule, evaluate any change in mudproperties or drilling parameters.

It is very important to monitor constantly shape, size and quantity of caving in conjunction with Mud Logging.Right interpretation of these parameters could help us to take decisions about mud weight and bridging agents

concentrations.


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Producto Funcin Descripcin

ALDACEDE G Biocide Glutaraldehide

BARAZAN D PLUS Viscosificifier Xanthic Biopolmer

Barofibre Fine LCM Additive Celuloce fibre

CALCIUM CARBONATE Densifier Agent Calcium Carbonate


CLAYSEAL PLUS Shale Inhibitor Exfoliated Poliamine

FILTER-CHEK Filtration Control Agent Modified starch

PAC L Filtration Control Agent Polianionic Celulose

PAC R Filtration Control Agent / Viscosifier Polianionic Celulose

5.2. Potential Problems

Lost circulation: It is necessary to use bridging material as CaCO3and to pump plugging pills if it is necessary.

Hole instability: this problem is reduced using an adequate density program and sealing agents as STEEL SEAL as

required.

Stuck pipe: this problem could be reduced using bridging, sealing and lubricants agents.

Inhibition:CLAYSEAL PLUS addition will provide enough inhibition for reactive clays and shale. EZ MUD DP

(PHPA) and CLAYSEAL PLUS concentration was optimized by Linear Swell Meter Test.

Tight hole:this issue is solved using an adequate mud density, besides to improve filtration rate control adding at

the same time sealing and bridging materials for this formation.

Formation damage:this mud system provides a unique environment which has been designed to protect reservoir.

Used products have been proved as reservoir friendly.

Hole cleaning: It is important to monitor returns and to run DFG simulation in order to optimize sweep pillsfrequency.


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If cutting sticking on shakers is observed Clayseal Plus concentrations will be increased.

If hole cleaning needs to be optimized, by increasing low rpm readings and Tau zero, small amounts

of Barazan D Plus should be added to the active system.

In case of formation instability symptoms are detected, add Barotrol Plus directly into active system in

order to seal micro fractures.

Optimize SCE performance in order to keep LGS concentration and fluid properties according mud

program during the interval.

At the beginning of section it is recommended to use on shale shakers 84 mesh screens since drilling

fluid is cold and may have a high and unusual viscosity, once mud temperature increase, programmed

shaker screens will be placed to minimize solid incorporation.

It will be used DFG drill ahead softwareand AFO Monitoring recomendations to monitor hole

cleaning and predicting rheology and density profiles in function of bottom hole temperature.

If formation instability is detected while drilling this interval, it is recommended to add sealant

material (Barotrol Plus). Minimum concentration to be used will be 2 ppb of asphalt and sizedcalcium carbonate, if these concentrations need to be increased it will be decided depending on hole

conditions in agreement with costumer representative.

Fluid displacement

Activities to be performed prior to fluid displacement:

1) A complete equipment cleaning (pits, shakers, SCE, flow line, trip tank, suction lines and mixing devices)must be performed.

2) Perform a safety meeting prior to mud discharge/preparation. Assign roles.


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3) Build Clauseal fluid system according to mud program.

4) Build spacers I, II and III.

Procedures during fluid displacement:

1) RIH until to the top of cement. Pump spacers I,II and III.

2) Perform suction pit change and starting pumping Clayseal system, rotate drill string while displacement is

performed, keeping pump rate constant. Suction pit level will be maintained constant transferring in first place

OBM from auxiliary pits. Fluid displaced will be transferred to storage tanks, when diesel returns will be

transferred by ditch to slug pit.

3) In case of having a mud logging unit, this will control together with driller total pump strokes, informing to

mud engineer and derrick man in order to be prepared to Clayseal mud returns.

4) Once Clayseal fluid returns to surface will be enabled all mud active circuit until normalize in/out mud

weight.

5.4. SCE Requirements

Multiple, linear motion shale shakers are recommended in order to maximize the system solids removal








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If near size particle blinding occurs, an attempt should be made to "screen-up to alleviate this problem. If

"screening-up" does not solve this situation, then coarser mesh screens must be installed until past this

formation.





Before tripping, running casing, etc. we recommend that the shaker screens be cleaned with a high- pressure

water spray after circulation has stopped. This will greatly increase screen life and prevent dried drilling fluid

and cuttings from blinding the screens when drilling resumes.


Flow rate 550 [gpm].

After each drilled stand to ream twice using maximum flow rate and RPM in order to smoothen drilledhole.

To pump weighted pills with Calcium Carbonate according DFG Software simulations, and holeconditions.

Previous to trip it is necessary to circulate a weighted pill with BAROLIFT during recommend timeaccording to DFG Software.

Make wiper trips maximum every 30 hours of drilling. Perform cleaning stations even inside the casing according DFG simulations for cuttings beds

accumulations if it is necessary.


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6. Terms and Conditions

The cost in this analysis is good for the materials and/or services outlined within. In order to meet your

needs under this proposal with a high quality of service and responsive timing, Halliburton will be allocating

limited resources and committing valuable equipment and materials to your area of operations. Accordingly,the discounts reflected in this proposal are available only for materials and services awarded on a first-call

basis. Alternate pricing may apply in the event that Halliburton is awarded work on any basis other than as a

first-call provider.

The unit prices stated in the proposal are based on our current published prices. The projected equipment,

personnel, and material needs are only estimates based on information about the work presently available to

us. At the time the work is actually performed, conditions then existing may require an increase or decrease

in the equipment, personnel, and/or material needs. Charges will be based upon unit prices in effect at the

time the work is performed and the amount of equipment, personnel, and/or material actually utilized in the

work. Taxes, if any, are not included. Applicable taxes, if any, will be added to the actual invoice.

It is understood and agreed between the parties that with the exception of the subject discounts, all services

performed and equipment and materials sold are provided subject to Halliburtons General Terms andConditions contained in our current price list, (which include LIMITATION OF LIABILITY and WARRANTY

provisions), and pursuant to the applicable Halliburton Work Order Contract (whether or not executed by

you), unless a Master Service and/or Sales Contract applicable to the services, equipment, or materials

supplied exists between your company and Halliburton, in which case the negotiated Master Contract shall

govern the relationship between the parties. A copy of the latest version of our General Terms and

Conditions is available from your Halliburton representative or at:

http://www.halliburton.com/hes/general_terms_conditions.pdf

For your convenient review, and we would appreciate receiving any questions you may have about them.

Should your company be interested in negotiating a Master Contract with Halliburton, our Law Department

would be pleased to work with you to finalize a mutually agreeable contract? In this connection, it is also

understood and agreed that Customer will continue to execute Halliburton usual field work orders and/or

tickets customarily required by Halliburton in connection with the furnishing of said services, equipment, and

materials.

Any terms and conditions contained in purchase orders or other documents issued by the customer shall be

of no effect except to confirm the type and quantity of services, equipment, and materials to be supplied to

the customer.

If customer does not have an approved open account with Halliburton or a mutually executed written

contract with Halliburton, which dictates payment terms different than those set forth in this clause, all sums

due are payable in cash at the time of performance of services or delivery of equipment, products, or

materials. If customer has an approved open account, invoices are payable on the twentieth day after date

of invoice.

Customer agrees to pay interest on any unpaid balance from the date payable until paid at the highest lawful

contract rate applicable, but never to exceed 18% per annum. In the event Halliburton employs an attorney

for collection of any account, customer agrees to pay attorney fees of 20% of the unpaid account, plus all

collection and court costs.
http://www.halliburton.com/hes/general_terms_conditions.pdfhttp://www.halliburton.com/hes/general_terms_conditions.pdf


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7. PROPOSED WINDOW DENSITY

8.6

8.8

9.2

9.4

9.6

9.8

10.0

10.1

10.2

10.3

10.5

10.6

10.7

10.9

9.8

10.1

10.3

10.5

10.8

11.0

11.6

11.8

9.6

9.7

9.9 10.0

0

500

1000

1500

2000

2500

3000

3500

4000

4500

5000

5500

6000

6500

7000

7500

8000

8500

9000

9500

10000

10500

11000

11500

8 8.2 8.4 8.6 8.8 9 9.2 9.4 9.6 9.8 10 10.2 10.4 10.6 10.8 11 11.2 11.4 11.6 11.8 12

FLUID DENSITY PROPOSEDEL JEFE 01

CSG 13 3/8" @ 5569'

CSG 9 5/8" @ 9307'MD

LNR 7" @ 11333' MD


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ANNEXES

7.1. HYDRAULICS

HOLE CLEANING SIMULATION 16 SECTION

This section drilled with 850 gpm show cuttings loads with 3.51% along all the section like average. And

cuttings loads for intervals over 5.11%. Baroid recommend having cuttings loads values lower than 3%. Under

this circumstancesis recommend:


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Increase the flow rate over 1100 gpm while drilling.

After every stand drilled to make two runs with the at lease the same rpm used drilling the stand and

for a period of time no lower of 14 min. this will help to reduce the cuttings load along the annular

section.

To pump sweep pills by train with 30 bls before every tripping out or whe the cuttings loads on theannular space show ranges over 3.0% of cuttings accumulation and circulate the time recommended

for the AFO Monitoring team.

HOLE CLEANING SIMULATION 12.25 SECTION


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cuttings loads for intervals lower 2.99%. Baroid recommend having cuttings loads values lower than 3%. Good

hole cleaning parameters. Under this circumstancesis recommended:

To keep the flow rate over 700 gpm while drilling.

To pump sweep pills by train with 30 bls before every tripping out and circulate the time

recommended for the AFO Monitoring team.

HOLE CLEANING SIMULATION 8.5 SECTION


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cuttings loads for intervals lower 1.14%. Baroid recommend having cuttings loads values lower than 3%. Good

hole cleaning parameters. Under this circumstancesis recommended:

To keep the flow rate over 700 gpm while drilling.

To pump sweep pills by train with 30 bls before every tripping out and circulate the time

recommended for the AFO Monitoring team.


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7.2. THREE DECISIONS FOR LOST CIRCULATIONINCIDENTS

Severity % losses, (bbl/h) Formaciones tpicas

A. Severe 6090% (> 50 bbl/h) Fracts

B. Parcial 1060% (1050 bbl/h) Sandstone, fracts, conglomerate

C. Seepage < 10% (< 10 bbl/h) Sandstone, conglomerate, depleted zone


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7.3. LOST CIRCULATION PILLS FORMULATION

AVAILABLES MATERIALS ON LOCATION FOR LOST CIRCUALTION

FINE MEDIUM COARSE

CaCO3-325 (110 lb/sx) CaCO3-200 (110 lb/sx) BARACARB 150 (110 lb/sx)

BAROFIBRE-F (25 lb/sx) BAROFIBRE-C (40 lb/sx)

BAROFIBRE-C / KWIK SEAL /

WALLNUT

(40 lb/sx)

STEEL SEAL-50 (50 lb/sx) STEEL SEAL-100 (50 lb/sx) CaCO3-40/100 (110 lb/sx)

TABLE 1.1 (hourly addition)

BARACARB 40 - 100 5 sx/hr

BAROFIBRE C 2 sx/hr

WALLNUT 1 sx/hr

TABLE 3.2 (100 Bbl @ 100 lpb)

Carbonato 200 20 lpb

Carbonato 40-100 20 lpb

BAROFIBRE C 20 lpb

WALNUT 20 lpb

Carbonato 325 20 lpb

TABLE 1.2 (50 Bbl @ 45 lpb)

CaCO3 40-100 25 lpb

BAROFIBRE C 10 lpb

WALLNUT 10 lpb


CaCO3 40-100 30 lpb

BAROFIBRE C 10 lpb

WALLNUT 10 lpb


CaCO3 40-100 30 lpb

BAROFIBRE C 15 lpb

WALNUT 15 lpb


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7.4. CAVINGS ANALYSIS CHART


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7.5. PARTICLE DISTRIBUTION

According to formation requirements, the optimal Particle distribution recommended for this job are calculated

with a D50 of 24.4 um for the interest zone.. This values are reached with a mixture of 40% of BARACARB

5, 40% of BARACARB 50 and 20% of STEEL SEAL 50


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7.6. STANDARD OPERATING PROCEDURES.According to field requirements, and the most common issues observed Baroid has a Standard operating

procedures, these are included and attached in the field proposal.

Anhydrite/Gypsum Drilling

Barite Plugs / Barite Sag

Bit Balling

Carbon Dioxide (CO2)

Cement, Drilling

Depleted Sands/Differential Sticking

DRIL-N Systems

Filter Cake/Filtration Control

Fluid Displacements

Fractured Limestone, Drilling

Gas Hydrates

Hole Cleaning

Hole Stability

Horizontal Drilling

High Temperature Wells

Hydrogen Sulfide (H2S)Lost Circulation

Mechanical Sticking

Permafrost, Drilling

Quality Assurance

Safety

Salt Drilling

Shale Drilling

SlidingSlim Hole Drilling

Solids Control

Stuck Pipe

Torque and Drag

Documents

Techincal Proposal - Drilling_Fluid_Program_EL JEFE 01