Drilling Fluids Operations Manual

ARPO

ENI S.p.A.Agip Division

ORGANISINGDEPARTMENT

TYPE OFACTIVITY'

ISSUINGDEPT.

DOC.TYPE

REFER TOSECTION N.

PAGE. 1

OF 155

STAP P 1 M 6160

The present document is CONFIDENTIAL and it is property of AGIP It shall not be shown to third parties nor shall it be used forreasons different from those owing to which it was given

TITLE

DRILLING FLUIDS OPERATIONS MANUAL

DISTRIBUTION LIST

Eni - Agip Division Italian Districts

Eni - Agip Division Affiliated Companies

Eni - Agip Division Headquarter Drilling & Completion Units

STAP Archive

Eni - Agip Division Headquarter Subsurface Geology Units

Eni - Agip Division Headquarter Reservoir Units

Eni - Agip Division Headquarter Coordination Units for Italian Activities

Eni - Agip Division Headquarter Coordination Units for Foreign Activities

NOTE: The present document is available in Eni Agip Intranet (http://wwwarpo.in.agip.it) and aCD-Rom version can also be distributed (requests will be addressed to STAP Dept. inEni - Agip Division Headquarter)

Date of issue:

f

e

d

c

b Issued by G. Ferrari C. Lanzetta A. Galletta28/06/99 28/06/99 28/06/99

REVISIONS PREP'D CHK'D APPR'D

28/06/99

ARPO


IDENTIFICATION CODE PAGE 2 OF 155

REVISIONSTAP -P-1-M-6160 0

INDEX

1. MANUAL USER’S GUIDE 5

1.1 INTRODUCTION 5

1.2 GUIDE TO USING THE MANUAL 6

1.3 UPDATING, AMENDMENT, CONTROL & DEROGATION 8

2. GUIDE TO DRILLING FLUID PROGRAMMING 9

2.1 DEVELOPMENT OF THE DRILLING FLUID PROGRAMME 10

2.2 CHOICE OF DRILLING FLUIDS 112.2.1 Non-Circulating, Start-Up Drilling Fluids 112.2.2 Circulating, Start-Up Drilling Fluids 112.2.3 Drilling Formations With Gradients Less Than 1.0kg/cm2/10m 112.2.4 Drilling Fluids For Non-Reactive Formations 112.2.5 Drilling Fluids For Reactive Formations 122.2.6 Drilling Fluids For Temperatures Greater Than 200oC 122.2.7 Inhibitive And/Or Environmentally Friendly Speciality Fluids 13

2.3 CHARACTERISTICS OF THE FLUID SYSTEM 14

2.4 EXAMPLES OF DRILLING FLUID CHOICE 162.4.1 Concomitant Problems 162.4.2 Type Of Drilling Fluid Preferred 16

2.5 CHOICE OF THE FLUID SYSTEM (Dependent On Its Main Variables) 16

2.6 DRILLING FLUID CHARACTERISTIC PROGRAMMING 17

2.7 WATER-BASED FLUIDS 182.7.1 Optimum Values Of Marsh Viscosity, Solids And Gel 182.7.2 Optimum Values Of Plastic Viscosity And Yeld Point 19

3. FLUID CHARACTERISTICS 20

3.1 NON-INHIBITIVE WATER BASED FLUIDS 20

3.2 INHIBITED WATER-BASE FLUIDS 37

3.3 OIL BASED FLUID 50

3.4 INHIBITED AND/OR ENVIRONMENTAL FLUIDS 55

4. FLUID MAINTENANCE 72

4.1 WATER BASED FLUIDS MAINTENANCE 734.1.1 Analysing Flow Chart For Water Based Fluid Reports 734.1.2 Maintenance Problems 744.1.3 Chemical Treatment of Contaminents 774.1.4 H2S Scavengers 784.1.5 Poylmer Structures/Relationship 79

4.2 OIL BASED FLUIDS MAINTENANCE 804.2.1 Analysing Flow Chart For Oil Based Fluid Reports 804.2.2 Maintenance Problems 81

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5. SOLIDS CONTROL 84

5.1 SOLIDS REMOVAL EQUIPMENT SPECIFICATIONS 84

5.2 STATISTICAL DISTRIBUTION OF SOLIDS 84

5.3 EQUIPMENT PERFORMANCE 84

5.4 EQUIPMENT RECOMENDATIONS 855.4.1 Double Shale Shakers 865.4.2 Single Deck Shale Shakers 87

5.5 SCREEN SPECIFICATION 885.5.1 Nomenclature 88

5.6 CYCLONE SYSTEMS 89

5.7 CENTRIFUGE SYSTEMS 905.7.1 PrInciple Of Operation 905.7.2 Centrifuge Processing 91

6. TROUBLESHOOTING GUIDE 92

6.1 LOST CIRCULATION CONTROL TECHNIQUES 93

6.2 LOSSES IN VARIOUS FORMATION TYPES 94

6.3 CHOICE OF LCM SPOT PILLS 946.3.1 LCM Information 956.3.2 LCM Efficiency 95

6.4 TROUBLESHOOTING GUIDE 966.4.1 Loss Of Circulation With Water Based Fluids 966.4.2 Loss Of Circulation With Oil Based Fluids 98

7. STUCK PIPE TREATMENT/PREVENTITIVE ACTIONS 101

7.1 STUCK PIPE TREATMENT/PREVENTION 102

8. DRILLING FLUID TRADEMARK COMPARISONS 105

8.1 DRILLING FLUID PRO DUCT TRADEMARKS 1068.1.1 Weighting Materials 1068.1.2 Viscosifiers 1068.1.3 Thinners 1068.1.4 Filtrate Reducers 1078.1.5 Lubricants 1078.1.6 Detergents/Emulsifiers/Surfactants 1078.1.7 Stuckpipe Surfactants 1088.1.8 Borehole Wall Coaters 1088.1.9 Defoamers/Foamers 1088.1.10 Corrosion Inhibitors 1088.1.11 Bactericides 1098.1.12 Lost Control Materials 1098.1.13 Chemical Products 1098.1.14 Oil Based Fluid Products 1108.1.15 Base Liquids And Corrections 112

9. DRILLING FLUIDS APPLICATION GUIDE 113

9.1 APPLICATIONS GUIDE 114

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10. DRILLING FLUID ANALYSIS 132

10.1 DRILLING FLUIDS 13310.1.1 Density (Fluid Weight) 13310.1.2 Marsh Viscosity 13310.1.3 Viscosity, Yield Point, Gel Strength 13410.1.4 API Filtrate 13510.1.5 HPHT Filtrate 13610.1.6 Oil, Water, Solids Measurement 137

10.2 WATER-BASED FLUIDS 13810.2.1 Sand Content Estimate 13810.2.2 pH Measurment 13910.2.3 Methylene Blue Capacity Determination 14010.2.4 Chloride Content Determination 14110.2.5 Calcium Hardness Determination 14210.2.6 Calcium And Magnesium Determination 14310.2.7 Alcalinity, Excess Lime, Pf, Mf, Pm Measurment 14410.2.8 Excess Gypsum Measurment 14510.2.9 Semiquantitative Determination Of Sulphurs (Hatch Test) 14610.2.10 Fluid Corrosivity Analysis 147

10.3 OIL BASED FLUIDS 14810.3.1 Electrical Stability Determination 14810.3.2 Fluid Alkalinity Determination 14910.3.3 Fluid Chloride Determination 15010.3.4 Calcium Determination 151

APPENDIX A - DRILLING FLUID CODING SYSTEM 152

A.1. CODE GROUPS 152

A.2. EXAMPLE CODING 153

APPENDIX B - ABBREVIATIONS 154

B.1. FLUID CODE ABBREVIATIONS 154

B.2. OTHER ABBREVIATIONS 155

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1. MANUAL USER’S GUIDE

1.1 INTRODUCTION

This manual is not a training document, but is intended to be instructional and aimed atengineers and technicians who are already familiar with drilling fluid technology. It isparticularly intended to meet with Eni-Agip’s operational requirements.

This manual addresses the Company’s fluid operators, drilling engineers and all thoseinvolved in the supervision of the work carried out by contractor companies and in theplanning or evaluation of the drilling fluids to be employed. However, it does not aim to bea comprehensive all encompassing document giving information on the entire subject, butaims to provide sufficient information to support the company’s technicians in better useof fluid technology.

Therefore, this manual does not instruct on how to prepare or maintain drilling fluids, butonly to aid in these tasks by providing the information needed to evaluate the advantagesand limitations of the various fluid systems, hence maximising drilling performance,reducing reservoir damage in an environmentally friendly and cost effective manner.

This document does not describe the decision making process but summarises it throughthe use of flow charts and forms, organised in a logical sequence. The reader may selecta single form or use the entire sequence in order to determine the best solution to theirrequirements. The method adopted herein, will be explained in the following ‘Guide toUsing the Manual’. This document does not include standard industry calculations orcharts relating to volumes and capacities or information relating to drilling fluids which areavailable in industry handbooks.

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1.2 GUIDE TO USING THE MANUAL

This manual aims to:

1) Help in the choice of the most applicable drilling fluids necessary to meet withrequirements for a well in a targeted area (Refer to section 2) and specifically it’ssub-sections relating to the different types of drilling fluids available. The flowchartbelow shows the selection process to be followed.

GATHER

INFORMATION AS PER THE FLOWCHART IN SECTION 2.1

IDENTIFY

THE TYPE(S) OF FLUID AS PER THECHARTS IN SECTION 2.2

VERIFY

THE FEASIBLE CHARACTERISTICS OFTHE SYSTEM IN SECTION 2.3

CHECK

THE CHOICE MADE FROM THEDESCRIPTION OF FLUIDS IN SECTIONS

3.1, 3.2, 3.3 and 3.4

DEFINE

THE CHARACTERISTICS OF FLUIDS AS THEPER CHARTS IN SECTIONS 2.6, 2.7

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2) Provide practical guidelines for:

• Drilling fluid formulations:These are described in sections 3.1, 3.2, 3.3, 3.4 and relate to the description ofthose drilling fluids which are considered the most applicable and economic foruse in various operating conditions. Particular operating conditions may entailmodification to these fluid formulations, hence their characteristics, specificallythe densities.

• Fluid Maintenance:This references the most important aspects of the specific fluid systemsdescribed and not any procedures relating to general maintenance common toall fluid systems.

• Contaminating Effects to Drilling Fluids:Other information on contanminants can be found in sections 4.1 ‘Maintenanceof Water Based Fluids’ and 4.2 ‘Maintenance of Oil Based Fluids’.

• Analysis of Daily Fluid Reports:Use the flow charts relating to the fluids described in sections 4.1.1 and 4.1.2where drilling fluid maintenance problems are identified. These charts follow thegeneral rules in problem solving summarised as follows in the analysis of dailyfluid reports.

IS THERE A PROBLEM ?

YES/NO

IF YES, WHAT IS THE PROBLEM ?

ANSWER

WHAT HAS BEEN DONE TO SOLVE IT ?

EVALUATE

WHAT ELSE CAN BE MADE TO SOLVE ITWHICH HAS NOT BEEN MADE YET ?

TAKE ACTION

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3) Provide information about solids removal equipment, which may aid in the choice ofequipment type and the size. The solids removal equipment in the description of thefluid systems provides equipment recommend nations, see section 5.

4) Describe problems relating to lost circulation and stuck pipe, section 6. Regardinglost circulation, a troubleshooting guide describes remedial actions for various typesof losses, in addition to some information concerning lost control materials. Forstuck pipe, recommendations on preventive measures are included and treatment tobe undertaken.

5) Provide information about drilling fluid products, section 8.1 ‘Comparable Charts ofCompetitive Drilling Fluid Product Trademark’ compares similar products and theirfunctional performances and consequently the various products, at differentconcentrations. This indicates the different product concentrations and costs.Therefore technical and/or economical analysis of these different products shouldbe carried out the concentrations necessary in similar operational conditions andresults.

6) Provide analysis procedures in section 10 ‘Drilling Fluid Analysis’ provides analysisprocedures which complies with API RP 13B-1 regulations dated June 1, 1990. Theprocedures with state listed on order to simplify the execution of various analysisshowing the results achieved the conversion factors.

1.3 UPDATING, AMENDMENT, CONTROL & DEROGATION

This manual is a ‘live’ controlled document and, as such, it will only be amended andimproved by the Corporate Company, in accordance with the development of Eni-AgipDivision and Affiliates operational experience. Accordingly, it will be the responsibility ofeveryone concerned in the use and application of this manual to review the policies andrelated procedures on an ongoing basis.

Locally dictated derogations from the manual shall be approved solely in writing by theManager of the local Drilling and Completion Department (D&C Dept.) after theDistrict/Affiliate Manager and the Corporate Drilling & Completion Standards Departmentin Eni-Agip Division Head Office have been advised in writing.

The Corporate Drilling & Completion Standards Department will consider such approvedderogations for future amendments and improvements of the manual, when the updatingof the document will be advisable.

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2. GUIDE TO DRILLING FLUID PROGRAMMING

This section is integrated with the following sub sections and covers all the various typesof drilling fluids.

The Eni-Agip codes are fully described in Appendix A.

GATHER

INFORMATION AS PER FLOW CHARTSECTION

IDENTIFY

THE TYPE(S) OF FLUID AS PER CHARTSAT SECTION

VERIFY

THE FEASIBILITY CHARACTERISTICS OFTHE SYSTEM AT SECTION

CHECK

THE CHOICE MADE FROM THEDESCRIPTION OF FLUIDS IN DOCUMENTS

DEFINE

THE CHARACTERISTICS OF FLUIDS ASPER CHARTS

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2.1 DEVELOPMENT OF THE DRILLING FLUID PROGRAMME

MAIN

IF REQUIRED AND/OR AVAILABLE

FLOW LINES:

GEOLOGICALINFORMATION

DEPHLITHOLOGY

CHEMICAL PROPERTIESPHYSICAL PROPERTIES

MINERALOHY

GEOGRAPHICALLOCATION

ON/OFF SHORE

ENVIROMENTALPROTECTION

DRILLING PROGRAMME

GRADIENTDRILL TUBING PROFILES

DEVIATION PROGRAMHYDRAULIC PROGRAM

LENGTH

LEGISLATIONWASTE REMOVAL MODALITES

WASTE REMOVAL COSTS

TYPE OF PLANT

LOGISTICSTYPE OF WATER

TARGET WELLDATA

CHARACTERISTICSREQUIRED

PHYSICAL CHAR.SOLIDS REMOVAL EQUIPMENT

MIXING FACILITIESSTORING AREAS

SUPPLYCHARACTERISTICS

REQUIRED

PHYSICAL/CHEMICALCHARACTERISTICS

LAB TESTINGINTERACTIONS

FORMATION/FLUID

TYPE(S) OF FLUID

DRILLING FLUID PROGRAMME

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2.2 CHOICE OF DRILLING FLUIDS

2.2.1 Non-Circulating, Start-Up Drilling Fluids

Systems Agip Code AVA Bariod Dowell MI BH Inteq

Fresh Water FW-GE-LI+FW

AVA SpudMud

FW+Gel Pills FW+Gel Pills FW+Gel Pills FW+Gel Pills

Seawater FW-GE+SW SW SpudMud

SW+H.VISPills

SW+H.VISPills

SW+H.VISPills

SW+H.VISPills

SW-GG AVAGUM LO-LOSS SM(X) LO-LOSS LO-LOSS

2.2.2 Circulating, Start-Up Drilling Fluids

Fresh Water FW-GE AVAGEL Spud Mud Spud Mud Spud Mud Spud Mud

Seawater SW-GE AVAGEL PrehydratedGel

PrehydratedGel

PrehydratedGel

PrehydratedGel

2.2.3 Drilling Formations With Gradients Less Than 1.0kg/cm 2/10m

Aerated FW/SW-AT

Foam Base FW-SF

Mixed AR-MM

Air/Foam-Base

AR-SF

Air-Base AR-AR

2.2.4 Drilling Fluids For Non-R eactive Formations

With Gradient Between 1.03 - 1.5kg/cm 2/10m

Bentonite-Base

FW/SW-GE-PO

AVAGEL-POL

Gel/Polymer Gel/Polymer Gel/Polymer Gel/Polymer

FW/SW-LS AVAFLUID Q-BROXIN FCL Muds Spersene UNI-CAL

FW-LW AVABEX X-TEND II GELEXSystems

Low-Solid/BENEX

With Gradient > 1.5kg/ cm 2/10m

Bentonite-Base

FW/SW-LS-CL

AVAFluid/LIG

Q-Broxin/CC16

FCL/CL Spersene /XP-20

UNICAL/LIGCO

FW/SW-TA Desco Desco Desco Desco Desco

With Gradient >1.5 High Temp erature (+/- 150-200 oC)

Bentonite-Base

FW/SW-CL-RX

AVAREX OC16/DUREN FCL/CL/HI-TEMP

SPER/XP20/RESINEX

LIGCO/CHEMTRO-X

FW/SW-CL-PC

+POLICELLACR

+THERMA-CHECK

+POLYTEMP +POLY RX +PYROTROL

Oil-Base DS-IE AVOIL Invermul Interdril Versadril Carbodril

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2.2.5 Drilling Fluids For R eactive Formations

Systems Agip Code AVA Bariod Dowell MI BH Inteq

With Gradient Between 1.03 - 1.5kg/cm 2/10m

Encapsulators FW-PK

FW/SW-PA AVAPAC PAC Polymer FLR PolymerMuds

Polypac Muds MIL-PACMuds

FW/SW-PC Polivis EZMUD ID-Bond Polyplus New-Drill

Inhibitors FW/SW-KC AVA-PC POT Chloride K Chloride K Chloride K Chloride

FW/SW-BR

FW/SW-SS AVA-Polysalt Salt Saturated Salt Saturated Salt Saturated Salt Saturated

FW/SW-MR AVAKLM KLM KLM KLM KLM

FW/SW-GY AVAFLUID/GYPS

GYP/Q-BROXIN

Gypsum Mud GYP/SPERSENE

Gypsum Mud

FW/SW-LI AVAFLUID/LIME

Lime Muds Lime Muds Lime Muds Lime Muds

Oil-Base DS-IE AVOIL Invermul Interdril Versadril Carbodrill

With Gradient >1.5kg/cm 2/10m

Encapsulators FW/SW-PC POLVIS EZ-Mud ID-Bond Polyplus New-Drill

Inhibitors FW/SW-KB-PC

K/POLIVIS K/EZ-MUD K/ID-Bond K/ Polyplus K/ New-Drill

FW/SW-MR AVAKLM KLM KLM KLM KLM

FW/SW-SS AVAPOLYSALT

Salt Saturated Salt Saturated Salt Saturated Salt Saturated

FW/SW-GY AVAFLUID/GYS

GYP/QBROXIN

Gypsum Mud Gyp/Spersene Gypsum Mud

FW/SW-LI AVAFLUID

/LIMELime Muds Lime Muds Lime Muds Lime Muds

Oil-Base DS-IE AVOIL Invermul Interdril Versadril Carbotec

With Gradient >1.5 And High Temp erature (150-200 oC)


2.2.6 Drilling Fluids For Temperatures Greater Than 200 oC


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2.2.7 Inhibitive And/Or Environmentally Friendly Speciality Fluids

Systems Agip Code AVA Baroid Dowell Mi B.H.Inteq

Format ions With Gradient Between 1.03 - 1.5kg/cm 2/10m

Inhibitors FW/SW-K2 AVA-PC2 K Carbonate K Carbonate K Carbonate K Carbonate

FW/SW-KA AVA-PA K Acetate K Acetate K Acetate K Acetate

FW/SW-GL HF 100 Sansoil Biodrill

FW/SW-CT AVA-CAT CAT I M CAT

Oil-Base LT-IE AVOIL-LT Enviromul Interdril Nt Versaclean Carbodril Sea

LT-IE-50 Baroid 50/50 Interdril 50/50 Carb.Sea50/50

EB-IE Petrofree

OF-IE Novadriill

UT-IE Ultidrill

Format ions With Gradient>1.5kg/cm 2/10m

Oil-Base LT-IE AVOIL-LT Enviromul Interdrill Nt Versaclean Carbotec Sea

OF-IE Novadrill

UT-IE Ultidrill

Format ions With Gradient>1.5 AND HIGH TEMPERATURE ( 150-200 oC)

Oil-Base LT-IE AVOIL-LT Enviromul Interdrill Nt Versaclean Carbodril Sea

OF-IE Novadrill

UT-IE Ultidrill

Drilling Fluids For Temp erature More Than 200 oC

Bentonite-Base

FW/SW-HT-GE AVAGEL-TERM

Duratherm Pyro-Drill

Polymer-Base FW/SW-HT AVATEX Thermadril Polytemp Envirotherm Pyro-Drill

Oil-Base LT-IE AVOIL-LT Enviromul Interdril Nt Versaclean Carbotec Sea

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BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.

AGIPCODE

SYSTEM

TEMPERATURE T1

T2

T3

T4

= 100 °C MAX

= 150 °C MAX

= 200 °C MAX

= 250 °C MAX

DENSITY' Kg/l D1

D2

D3

D4

D5

= 1.2 MAX

= 1.5 MAX

= 1.8 MAX

= 2.1 MAX

= 2.4 MAX

CHARACTERISTICS

OF THE FLUIDS SYSTEMS

CO

ST

S

A

M

B

ENV.

= HIGH

= MEDIUM

= LOW

= ENVIRONMENTALLY IMPACT

FW SW-GE

SW-GG

FW SW-GE-PO

FW SW-LS

FW-LW

FW SW-CL

FW-PK

FW SW-PA

FW SW-PC

FW SW-KC

FW-K2

FW-KA

FW SW-SS

FW SW-GL

FW SW-CT

FW SW-MR

FW SW-GY

BENTONITE

GUAR GUM SUSPENSION

BENTONITICO-CMC

LIGNOSOLFONATE

LOW SOLIDS WITH BENT.EXTENDER

CROMOLIGNIN

AGIPAK (KCMC)

PAC (DRISPAC)

PHPA

POTASSIUM CHLORIDE

POTASSIUM CARBONATE

POTASSIUM ACETATE

SALT SATURATED

CLYCOL

CATIONIC

MOR-EX (KLM)

GYPSUM

X

X

X

X

X

X

X

X

X X

X

X

X

X

X

X

X X

X

X

X X

X X

X X

X

X

X

X

X

X

X

X

X

X

X

X

X

X

X

X

X

X

X

(X)

(X)

(X)

AB B B B B B B B B BT1 D1

B B B B B B B B BT1 D1A M

M MB B B B B B BA A T1 D1

B B B B B BM MD4T2A BB

B B B B BM MB BA BT3 D4

M MB B B B

B

B

B

B

B

B

B

B

B

B

B

B

M/B

B

M/B

B

B

B

B

B

B

B

B

B

B

B

B

A

A

A

A

AA

A

A

A A AA

A

A

M

A

M

A

A

A

M

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A

A A

A

M

M

M

M M

M

M

M

M

B

M

M

M

M

M

B

B

B

B

B

B

B

B

M

T1

T2

T2

T2

T2

T2

T2

T2

T2

T2

D1

D1

D3

D3

D3

D3

D3

D3

D4

D4

D4

M

M

B

A

A

AM

M

M

B

B

B

B

B

T3

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AGIPCODE

SYSTEM

TEMPERATURE T1

T2

T3

T4

= 100 °C MAX

= 150 °C MAX

= 200 °C MAX

= 250 °C MAX

DENSITY Kg/l D1

D2

D3

D4

D5

= 1.2 MAX

= 1.5 MAX

= 1.8 MAX

= 2.1 MAX

= 2.4 MAX

CHARACTERISTICS

OF THE FLUID SYSTEMS

CO

ST

S

A

M

B

ENV.

= HIGH

= MEDIUM

= LOW

= ENVIRONMENTALLY IMPACT

FW SW-LI

FW SW-HT

DS-IE

LT-IE

LT-IE-50

EB-IE

OF-IE

UT-IE

DS-IE-100

LT-IE-100

.

LIME

FOR T. MORE THAN 200 °C

DIESEL INVERT EMULSION

LOW TOXICITY OIL I.E.

E.I. 50/50

ESTER-BASE I.E.

POLYOLEFINE I.E.

ULTRA LT OIL I.E.

100% DIESEL I.E.

100% LT OIL I.E.

X

X X

X

X

MM B A M B M B B B MT2 D4

A MA A A A M M AA A T4 D5

A A M A A AB AD5T4 B

A A A M MA AM AM MT2 D2

A AA A M A

A

A

A

A

A

A

A

A

A

A

A

B

B

B

A

A

M

M

AA

A

A

A

A

A

A A

A A

M

M

A

A

A

A

A A

A

A

A

T2

T3

T4

T4

T2

D3

D4

D5

D4

D5

A

A

B

M

MA

A

A

A

X

X

X

X

X

X

X

B B B B BA A A AM BT4 D3

A

A

A

A

A

A

A

A

A AX

X

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2.4 EXAMPLES OF DRILLING FLUID CHOICE(dependent on the drilling performance needs)

2.4.1 Concomitant Problems

High Deviation (>30 o) X X X X X X X X

Very Reactive Formations X X X X X X X X X X X

High Differential Pressure X X X X X X X X

Risk Of Lost Circulation X X X X X X

High Density (>1.9 SG) X X X X X X X

High Temperature (>150 ) X X X X X

Risk Of Hydrated Gas X X X X

Order of preference: 1>2>3. Vertical reading, i.e., high density, high temperature; 1st OBM, 2nd LS.

2.4.2 Type Of Drilling Fluid Preferred

Oil-Base Fluid (DS, LT, EB, PO) 1 1 1 1 2 1 1

Lignosulfonate Fluid 1 2 1 2 2

Polymer-Base Fluids 2 3 2 3 1 3

Inhibitive Fluids 1 1 1 1 2 3 2

Order of preference: 1>2>3. Vertical reading, i.e., high density, high temperature; 1st OBM, 2nd LS.

2.5 CHOICE OF THE FLUID SYSTEM (Dependent On Its Main Variables)

Inhibition SystemDensity

Max. (kg/I)Temperature

Max. (oC)Maintenance

DifficultyCost

None FW-GE 1.2 100 Low Low

FW-LS 2.2 170 Low Low

Encapsulative FW-CMC 1.2 100 Low Low

FW-PA 1.6+ 150 Medium Medium

FW-PC 1.8+ 150 Medium Medium

Inhibitive FW-PK 1.2 100 Low Low

FW-LI 2.1 130 Medium Low

FW/SW-GY 2.1 170 Medium Low

FW/SW-KC-PC

1.8+ 150 High High

FW-MR 2.1+ 100 High High

DS-IE 2.4 >250 Medium Low/Medium

Note: The systems examined above are only a portion of that available.

Note: The high, medium, or low cost is evaluated with consideration of the inhibition grade.

INCREASE

ARPO




2.6 DRILLING FLUID CHARACTERISTIC PROGRAMMING

Characteristics Surface Phases Intermediate Phases Final Ph ases

Main Problems • Hole Cleaning• Losses

• Gradients• Reactivity

• Formation Damage

Density Minimum to avoidlosses.

More than pore and/orcollapse gradients, lessthan fracture.

As low as possiblecompatibly with poreand/or collapsegradients, less thanfracture gradient.

Plastic Viscosity This value depends upon density and fluid type. Maintain density as low aspossible (in both technical and economic terms).

Yield Point Sufficiently high toclean the hole, but notso high to limit solidsremoval

(+/- 10-15gr/100cmq).

Same parameters asinitial phases

(+/-6-10gr/100cmq).

Same parameters asinitial phases

(+/- 3-8gr/100cmq).

Gels Sufficiently high tosuspend cuttings andyield point.

Formulate them to wellconditions.

Sufficient to avoidsettling withoutstressing the formationwhile tripping.

Sufficient to avoidsettling without stressingthe formation whiletripping.

Api Filtrate

HP/HT Filtrate

Particular controls arenot generally required

(15-20cc/30’), estimatefor each case.

Carefully evaluate theformations and fluiddensity

(average values 4-10cc/30’).

Commonly low to limitseepage formation anddamage.

Cake Suitable to supportunconsolidatedformations.

As low as possible. Less damaging aspossible.

Solids% Dependent on thesystem chosen,optimise HGS, LGS andMBT. Each system hasa different solidstolerance.

Dependent on thesystem chosen,optimise HGS, LGS andMBT. Each system hasa different solidstolerance.

Use of non damagingweighting agents ( whichcan be acidfield) or brineis preferred. MaintainLGS values at minimum.

MBT (kg/m 3) Dependent on the minimum value and/or system tolerance to the drilling fluidchosen.

pH 8<pH<12+; Value 8 min. helps reduce corrosion. The other values dependupon the fluid system chosen.

ChemicalCharacteristics

Dependent on thedrilling fluid chosen.

Compatible to the fluidsand shales of thereservoir.

ARPO




2.7 WATER-BASED FLUIDS

2.7.1 Optimum Values Of Marsh Viscosity, Solids And Gel

ARPO




2.7.2 Optimum Values Of Plastic Viscosity And Yeld Point

ARPO




3. FLUID CHARACTERISTICS

3.1 NON-INHIBITIVE WATER BASED FLUIDS

This section contains descriptions of the various water based drilling fluids, theirapplications and limitations.

The Eni-Agip codes, abbreviations and symbols used in this section are listed in AppendixA and Appendix B.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT O

il

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LGS

Tol

eran

ce

Mai

nten

. Diff

eren

ce

Logi

stic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lubr

ican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud


Cos

t

DESCRIPTION OF THE SYSTEM

BENTONITE BASED FLUID

AGIP CODE

FW-GE

X X B B B B B B B B B BA T1 D1

- Drilling start-up;- Viscose pills; A clay base should be provided to more complex polymer-base fluid;- After prehydrating, sea water can be added;- Specific treatments may adapt characteristics to the needs;- Easily convertible to more complex systems.

BENTONITE (OCMA)CAUSTIC SODA

FRESH WATER40-701-2

MIXING TIME: +/- 25 m /hr

Fun

nel v

isc.

(se

c/qt

)

Pla

stic

vis

c. (

cps)

Den

sity

(S

G)

Yie

ld p

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

rat

io

Ele

ctric

al s

tabi

lity

(vol

t) M

BT

(Kg/

m e

quiv

.)

CHARACTERISTICS OF THE DRILLING FLUID

1.3 1.15

40 60

6

10

5

10

1

3

6

15

12

20

8.5

320

- Highly sensitve to chemical contaminants;- Low solids tolerance;- Unadequate characteristics for situations other than drilling start-up.

3

2

2 2

3

30

509.5

APPLICATION

LIMITATIONS

FORMULATION PRODUCTION kg-l/m 3

ARPO




MAINTENANCE:

- Maintain an adequate solids percentage;- Use water and bentonite to control viscosity and/or vary pH.

CONTAMINANTS REMEDIALS

Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

Na

Cl

%S

and

SAND GROUNDS + + - DESANDERS

SHALES + + ++ + --=/-- =/---- - CENTRIFUGE- DILUTION- CONVERT TO FW-LS

GYPSUM/ANHYDRITE

=/+ =/+

= +/-- + + + +=/-- --

SALT =/+ +/-- + + + +

CEMENT +/-- + + + + + +--

CO 2 -- -- --++ +

H S2

+

SO4- -

- DILUTION- Na CARBONATE- CONVERT TO FW-LS- CONVERT TO FW-GY

- DILUTION, CMC- CONVERT TO FW -SS

- DILUTION- Na BICARBONATE

- DEGAS- ALTERNATE TREATMENT WITH NaOH and Ca(OH)2

- PREVENTIVE TREATMENT WITH SCAVENGER.- HYDROGEN PEROXIDE + NaOH.- DEGAS

-- + ++ + -- -- -- STINKING SMELLGREEN OR BLACK COLOUR

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LGS

Tol

lera

nce

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud


Cos

t

DESCRIPTION OF THE SYSTEM AGIP CODE

DESCRIPTION AND APPLICATION

FORMULATION

GUAR-GUM SUSPENSION SW-GG

X B B B T1 D1

PRODUCT kg-l/m

GUAR GUMBACTERICIDE

SEA WATER10as needed


Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)


1.03 100+ 20 30 15 15 NC 7

ADVANTAGES AND LIMITATIONS

3

3

Yie

ld P

oint

(gr

/100

cm )2

2 2

3

X

- Drilling start-up- Viscose pills in sea water or in presence of electorlytes;- Can be used as Bentonite extender (in low concentrations);- Reduced logistical problems in drlling start-up.

- Fresh water is needed for hydration;- Low cost;- Low concentration usage;- Fermention;- Non resistant to high temperatures;- Suitable for viscose pills only.f

ARPO




PREPARATION- Avoid adding NaOH to the system;- Use a bactericideif not used immediately;- For hydrations, stir at high speed for approx. 1hr;- 'Fish eyes' can be easily observed.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT O

il

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lubr

ican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud


Cos

t



FORMULATION

BENTONITE-AND CMC-BASE FLUID FW-GE-PO

X X B B B B B B B B B BA T1 D1

PRODUCT kg-l/m

BENTONITE CAUSTIC SODA

FRESH/SALT WATER20 - 601 - 3


Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Cal

cium

(gr

/l)

Pf

Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)


1.03 1.15

40 80

5

15

4

15

2

4

8

15

10

2

8.5

9.5


3

3

2

2 2

3

X

20

60

CMC HVCMC LV

0 - 62 - 10

- Drilling start-up when FW-GE characteristics are not sufficient;- Drilling non reactive formations with gradient <1.1 kg/cm2.

- Easy maintenance and low cost;- Highly sensitive to chemical contaminants;- Low solids tolerance.

ARPO




SAND GROUNDS

CONTAMINANTS REMEDIALS

Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

NaC

l

%S

and

+ + - DESANDERS

SHALES + + ++ + --=/-- =/---- - CENTRIFUGE- DILUTION- CONVERT TO FW LS

GYPSUM/ANHYDRITE

=/+ =/+

= +/-- + + + ++

=/-- -- SO4- - - DILUTION

- Na CARBONATE- CONVERT TO FW-LS- CONVERT TO FW-GY

SALT - DILUTION, CMC- CONVERTIRE IN FW SS

=/+ +/-- + + + +

CEMENT - DILUTION- Na BICARBONATE

+/-- + + + + + +--

CO2 - DEGAS-- -- --++ +

H S2 -- + ++ + -- -- -- STINCKING SMELLGREEN OR BLACK COLOUR

MAINTENANCE:

To control RHEOLOGY:- Increase: Bentonite, CMC HV;- Decrease: Solids-Removal, Dilution, Lignosulfonates.

To control FILTRATE:- CMC LV and/or Bentonite.

- PREVENTIVE TREATMENT WITH SCAVENGER.- HYDROGEN PEROXIDE + NaOH- DEGAS

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

ifere

nce

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud


Cos

t



FORMULATION PRODUCT kg-l/m

MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity.

(vo

lt) M

BT

(kg/

m e

quiv

.)



3

3

2

2 2

m /h

LOW-SOLIDS FLUID WITH BENTONITE EXTENDER FW-LW

X XX M MB B B B B B BA A T1 D1

- Low density and high viscocity with a reduced solids-contents;- Reduced transportation problems;- Optimum for drilling start-up or when high mixing time is required.

- Sensitive to chemical contaminants;- Sensitive to chlorides;- Low solids tolerance.

1.03 45 5 8 2 5 153

69.5

8

MAX

0.1

MAX

FRESH WATER

BENT. EXTENDER

BENTONITE

NaOH/KOH

(CMC LV)

30

50

2-10

1-1,2

3 :

0,12

ARPO




MAINTENANCE

CONTAMINANTS REMEDIAL

Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

NaC

l

% S

and

SALT,

SALT WATER

CaSO4

SOLIDS

EXCESS POLYMER

+/- + + + + +

+

+ + + + + + +

=

=

= =

- - - =/-

=/-

+

- - - --

CONVERT TO SW-PO

SODA ASH + EXTENDER

ADD EXTENDER, DILUTE

ADD. BENTONITE

- Prehydrate bentonite before adding extencer;- Extender should be prehydrated before adding to the active system;- Addition ratio is1 kg of extender every 250 kg of bentonite;- Control solids as per range indicated;- Efficiency of shale shakers and cyclones is important;- High quantity of extender is an energic encapsulating agent.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. T

oler

ance

Log

istic

Tol

eran

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

E

q.

Cut

tings

Mud


Cos

t


DESCRIPTION

FORMULATION

LIGNOSULPHONATE-BASE FLUIDS FW/SW-LS

X B B A B B B B B B MM T2 D4

PRODUCT kg-l/m

BENTONITE FCL

FRESH (SALT) WATER

20 - 70

MIXING TIME: +/- 20 m /hr + weighting time

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)


1.1 2.1

38 60

5

45

2

12

1

2

5

15

10

2

9.5

10.5


- Environmental impact concerns;- Lignosulphonates are uneffective in salt saturated fluids;- Optimum pH is 10, this value helps shale dispersion;- Lignosulphonate stabilises the collidal dispersion of shale in water reducing the effectiveness of any encapsulators.

3

3

2

2 2

3

X

20

70

NaOHCMC LV / LIGNIN

1 - 42-10 / 10 - 20

X

- Most versatile fluid. Ideal for exploration wells;- High solids-tolerance. Easy maintenance;- High tolerance to chemical contaminants;- Convertible to Lime or Gypsum-based fluids.

10

7

40 60

1

3

0.5

0.7

BARITE as needed

10 - 30

ARPO




MAINTENANCE:


Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

NaC

l

% S

and

- Dependent on the solids percentage;- Thanks to the system flexibility characteristics may be adapted according to the needs by simply adding additives;- For high temperature and/or high density, use lignin as an alternative to CMC to control filtrate.

SHALE

GYPSUM/ANHYDRITE

SALT

CO2

CEMENT

+ + + +

+ + +

+ + + +

+ + + +

+ + + + +

=/-=/- =/-

=/- =/-

=/-

=

-

+/- +/=

+ +

+/-

=/+

-

-

-

- -

=/+

-

=

- SOLIDS CONTROL- TREATMENT WITH FCL+SODA

- FCL + SODA ASH- ADD CMC LV- CONVERT TO FW-GY

-FCL + SODA ASH-CMC LV-CONVERT TO SS

- FCL + C.SODA and/or LIME

-PRETR. WITH NaHCO3- FCL+CMC

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud


Cos

t




MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)

CHARACTERISTICS OF DRILLING FLUIDS


3

3

2

2 2

m / h3

(CHROME)-LIGNIN-BASE FLUIDS FW/SW-CL

- Development of Lignosulphonate-based fluids at high temperatures: To aid filtrate control add chrome Lignin which integrates the thinning effect of Lignosulphonate.

X (X) X M MB B B B B B B BA

1.08

2.1

40

60

8

40

5

8

1

1

4

10

10

2

30

10

8

40

9.5

11

1

3

0.3

0.7

0.5

1.5

0.2

MAX

60

10

FRESH WATERBENTONITEFCLCLNaOHPOLYMERS (CMC, PAC)BARITE

20 + WEIGHTING TIME

20-7010-3010-300.5-50-10as needed

- Versatile and economical system;- High solids tolerance;- Cr-Lignin is a less effective scavenger than lignosulphonate. Its effectivness is further reduced in sea water and becomes completely uneffective in presence of calcium;- Environmental impact concerns.

T3 D4

ARPO




MAINTENANCE


Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

NaC

l

% S

and

- High solids tolerance;- Up to 150°C, deflocculant effect is due to FCL; over this temperature CL is most commonly employed;- Alkalinity control is highly important to guarantee Cr-Lignin solubility;- Dump if contamination from carbonates or bicarbonates is present.

SHALE + + + + - - - =/- + + - CENTRIFUGE

CEMENT = +/- + + + + + =/+ - + NaHCO3 O Na2CO3

- +FCL + CL + NaOH- DILUTION

- + FCL + CL

CaSO4 = +/- + + + +/- = =/+ + - + Na2SO4 E/0 NaOH- + FCL + CL - CONVER.IN FW-GY

SALT =/+ +/- + + + - - - + - + FCL + CL - CONVER.IN FW-SS - FOR T. >150° C UTILIZZARE DS-IE

= + + + =/- +/- + - + LIME AND/OR C. SODA+/-CARBONATES/BICARBONATES

TEMPERATURE + + + + - + FCL + CL - + DEFLOC. AT HT

- RHEOLOGY

- Decrease: add FCL/CL/ Soda, dilute only in case of excess solids;- Increase: add prehydrated and FCL protected Bentonite carefully. Evaluate the addition of polyacrylates.

- FILTRATE

- Maintain a reduced quantity of Bentonite, add CL, and HPHT polymers.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffre

nce

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

E

q.

Cut

tings

Mud


Cos

t




MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)

CHARACTERISTICS OF THE DRILLING FLUIDS


3

3

2

2 2

m /h3

P.A.C.- BASE FLUIDS (DRISPAC) FW/SW-PA

X X M B B M A A T2 D4 B M B B

- Encapsulating system, optimum base for inhibitive polymer systems;- High concentrations may limit cutting dispersion;- Same application as FW-PO, but has a better efficiency at high concentrations of monovalent salts.

- Encapsulating system which needs the addition of an inhibitive salt for inhibition;- High sensitvity to contaminations from polyvalent salts;- Low solids tolerance.

1.05 45 10 6 3

10 8

6

8.5

20

1.5 60

20

10

5

15

2

16

9.5

20

FRESH/SALT WATERBENTONITEP.A.C.(REGULAR)P.A.C.LVNaOH

25 + WEIGHTING TIME

X

0.4

MAX

BARITE

20-402-50-51,0-1,5as needed

ARPO




MAINTENANCE


Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

NaC

l

% S

and

- Mainly encapsulating, this system needs an adequate concentration of polymer (>3 kg/m3) to limit cutting dispersion and high increase of viscosity;- Easily convertible to a Potassium-base system, both Polymer-base and dispersed;- If a density increase above optimum range is desired, convert the system to a more solids-tolerant one.

SHALE + + + + - - - + +

CEMENT = +/- + + + + + + - PRETREAT WITH SODIUM BICARBONATE

- DILUTION- CONV. TO A MORE INHIBITIVE SYSTEM

CaSO4 = +/- + + + - = =/+ + - ADD. SODA ASH.- CONV IN FW/SW GY- ADD FCL

SALT =/+ +/- + + + - - - + - CONTAMINANT IS DEPENDENT ON OBM- CONV. TO FW/SW-SS

- RHEOLOGY

- Decrease: Deflocculate using a short chain polymer (i.e.: short chain CMC LV, PHPA); Dilute; add CL and/or FCL.

- FILTRATE

- Use PAC Regular/LV and/or CMC LV dependent on rheology desired. High salt content fluids can result economical if employed with starches.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LGS

Tol

eran

ce

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud


Cos

t




MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)



3

3

2

2 2

m /h3

PHPA-BASE FLUIDS FW/SW-PC

X X M B M M M A A T2 D3 B M B B

- Pre-soluble polymers are required to viscosify and encapsulating cuttings;- High solids-tolerance;- Optimum base for a KCI-base fluid;

1.03 45 10 5 2 15 8

8.5

50

1.8 60

30

15 5 20 2

2710.5 20

FRESH/SALT WATERBENTONITEPHPACMC LV (CL)NaOH/KOH

25 + WEIGHTING TIME

X

0.4 MAX

BARITE

3050-7 (10)0.1-0.5as nedeed

- Encapsulating system which needs the addition of an inhibitive salt for inhibition;- High sensitivity to contaminations from polyvalent salts;- Low solids tolerance.

ARPO





Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

NaC

l

% S

and

SHALE + + + + +/- - - + +

CEMENT = +/- + + + + + +

CaSO4 = +/- + + + - = =/+ +

SALT =/+ +/- + + + - - - +

- ADD PHPA

- PRETREAT WITH

- ADD. PHPA LMW. -INCREASE INHIBITION

NaHCO3

- ADD. Na2CO3- CONV IN FW/SW GY- ADD FCL

- CONTAMINANT IS DEPENDENT ON MBT- CONV. TO FW/SW-SS

MAINTENANCE

- Encapsulating system: An adequate concentration of polymer (3>kg/M3) is needed to limit cutting dispersion and high increase of viscosity;- Easily convertible to a potassium-base system;- Polymer may be added wherever but not through the hopper to avoid foam formation;- Can tolerate up to 170°C by using additives.

- RHEOLOGY

- Decrease: Deflocculate using a short chain polymer (i.e.: short chain CMC LV, PHPA); Dilute; If a more energic action is needed, them add CL and/or FCL.

FILTRATE

- Use the most adequate a filtrate reducer according to the usage: (temperature, density, salinity).

ARPO




3.2 INHIBITED WATER-BASE FLUIDS

• This section contains descriptions of the various inhibited water based drilling fluids,their applications and limitations.

• Fluid formation herein described, relating to drilling fluids, are the most simple andeconomical. Particular operating conditions may greatly modify them, so characteristicsare reffered to the density indicated.

• Suggestions relating to fluid maintenance only refer to the most important aspect of thesystem described and do not include those relating to the general maintenance whichare common to all systems.

• Containment effects refer to the fluid type. Other information on contamination can befound in section 4.1 ’Water Based Fluid Maintenance’.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-Dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Logi

stic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

id-r

emov

al e

q.

CU

TT

ING

S

MU

D

BASE FLUID CHARACTERISTICS OF THE FLUID ENV.

CO

ST

O



FORMULATION PRODUCT Kg-l/m

MIXING TIME:

Fun

nel v

isc.

(se

c/qt

)

Pla

stic

vis

c. (

cps)

Den

sity

(S

G)

Yie

ld p

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

rat

io

Ele

ctric

al s

tabi

lity

(vol

t) M

BT

(Kg/

m e

quiv

.)



3

3

2

2 2

m /h3

SALT SATURATED FLUID FW/SW-SS

X X A M B A A B A T2 B M A A

1.2

2.1

15 +WEIGHTING TIME

X

- Lower cost and east availability of NaCl;- Na+ has an inhibition effect only in high concentrations. In low concentrations it helps shale dispersion;- Salt saturated fluid is a special discarding fluid;- High salt content will affect the product performance. Dispersants, i.e. FCL, are low-effective. Dilution is required tp maintain the system.

- Conditioned with NaCl, generally saturated;- Mainly used to drill salt formations. More rarely as an inhibitive fluid in shale formations.;- Viscosified salt solutions are employed as W.O. fluid.

38

80

10

50

4

10

0

2

10

15

5

1

2

38

8.5 9.5

320

320

10 10

BENTONITE PREIDRATATASODA CAUSTICAAMIDOSALE(PAC REG, LOVIS)BARITE

40-603-610-20350(3-6)as needed

D4

ARPO





Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

Cl

% S

and

SHALE + + + + =/- - - + +

CEMENT = +/- +/- +/- + + + +

Ca++ = +/- +/= +/= +/= -/= +

Mg++ = + + + - - -

HIGHTEMPERATURES

+ + + - - +

MAINTENANCE

RHEOLOGY

FILTRATE

- Up to approx. 100 °C Temperature, use starch; For hgiher temperatures, PAC and/or CMC; for temperatures more than 140 °C, estimate the use of oil-based fluid.

- CENTRIFUGE

- PRETREAT WITH

- DILUTE

NaHCO3

- USE PRODUCT TOLERANT TO Ca ++- AVOID DIRECT ADDITION OF ALKALINE AGENTS

- USE PAC - SUBSTITUTE WITH OBM.

- IF DUE TO COMPLEX SALTS pH 8 IS MAX WITH MgO.DO NOT ADD ALKALINE AGENTS IN CIRCULATION.

- Prior to dilution, try to use small concentrations of short chain polymer (i.e. CMC LV), or FCL (prehydrated in fresh water) ;- Rheology is generally maintained by adding prehydrated protected Bentonite (with a polymer or Lignosulphate) and starch; If needed use a Bio-polymer.

- Traditionally maintained with dilution;- In absence of Mg++ salts, keep Pf>1;- System maintenance may result more complex in drilling complex salt formations (i.e. zechstein). In this case contact expert technicians.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-Dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

id-r

emov

al e

q.

CU

TT

ING

S

MU

D


CO

ST

O




MIXING TIME:

Fun

nel v

isc.

(se

c/qt

)

Pla

stic

vis

c. (

cps)

Den

sity

(S

G)

Yie

ld p

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

rat

io

Ele

ctri

cal s

tabi

lity.

(vo

lt) M

BT

(Kg/

m e

quiv

.)



3

3

2

2 2

m /h

AGIPAK (KCMC)-BASE FLUIDFW-PK

X X M B B B M A A T1 D1 B B B B

- A certain inhibition grade is given to the system by replacing the sodium base with the potassium one;- Same applications as FW-PO;- May be used as a dispersed polymer and potassium-base system.

- Slightly encapsulating and inhibitive system;- Can only be used in fresh water, as salt water affects the potassium-base effect;- Low-solid tolerance.

1.03 40

5

4 2

8

10

5

8.5

20

1.15 80

15

15

3

15

2

15

9.5

60

FRESH WATERBENTONITEKCMC / AGIPAC HVKCMC / AGIPAK LVKOH

20-602-62-102-4

25

.

._

3

ARPO





Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf

/ Pm

Mf

Sol

ids

MB

T

Ca

NaC

l

% S

and

SHALE + + + + - - - =/- + +

CEMENT = +/- + + + + + +

CaSO4 = +/- + + + - = =/+ +

SALT =/+ +/- + + + - - - +

- Dilute

-Pretreat with KHCO3

- Add K+- Add FCL E/O CL

- Add K2CO3- + KCMC-LV- Convert to FW-GY

- Convert to SW-PO - Convert to FW-SS

MAINTENANCE

- Low-solids tolerance;- Good operating performance of the solids-removal equipment is needed to limit dilutions;- Easily convertible to a dispersed potassium and polymer base system.

RHEOLOGY

- Decrease: dilution, KCMC-LV has a light deflocculating effect;- Increase: addition of KCMC-HV.

FILTRATE

- Maintain a minimum quantity of bentonite, add KCMC-LV.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-Dis

pers

ed

dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

Use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

id-R

emov

al E

q.

Cut

tings

Mud


Cos

t




MIXING TIME:

Fun

nel V

isc.

(s

ec/q

t)

Pla

stic

Vis

c.

(cps

)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr

/100

cm )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol.)

pH Pm

Mf

NaC

l (gr

/l)

Cal

cium

(gr

/l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)



3

3

2

2 2

m /h3

POTASSIUM CHLORIDE- BASE FLUID FW/SW-KC

X X A M B/M A M M A T2 D3 B A B M

- Conditioned with KCI, which is added preferably to polymer and non-dispersed;- Mainly employed in drilling shales like gumbo;- Drilling formations which, when hydrated have swelling and sloughing tendencies.

1.05

1.8

25 + WEIGHTING TIME

X (X)

- KCl is an available and low-cost salt;- Inhibitive ion concentrations can be easily adapted to the formation reactivity;- K+concentration should be constantly monitored ;- High salt concentration may create disposal problems;- K+destabilises high caolinitecontent formations.

THE CHARACTERISTICS ARE THOSE TYPICAL OF THE BASE SYSTEM EMPLOYED.

- The formulations are those typical of the base systems employed.- Product concentrations are traditionally higher.- A biopolymer is used as a base viscosifier to provide the system with adequate suspending characteristics.

ARPO




MAINTENANCE


Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

Cl

% S

and

Shale + + + + +/- - - + + _

Cement = +/- + + + + + +

CaSO4 = +/- +/= +/= +/= -/= +

Salt =/+ +/- +/- +/- = - - - +

- Adequate concentration of KCI must be maintained and monitored through laboratory tests, as well as by observing the cuttings over the shale shakers;- Fluid maintenance is that of the system to which KCI is added;- System may be optimised by replacing the soda-base products with potassium-base ones;- In sea water higher concentrations of KCI are required.

RHEOLOGY AND FILTRATE

- Refer to the base-system used.

NOTE: KCl-BASE SYSTEM, ESPECIALLY IF POLYMERIC, TRADITIONALLY HAS HIGH RATES OF CORROSION.

- Add. K+

- Pretreat with

- Increase concentration (K+)

KHCO3

- Use products tolerant Ca++

- Generally minimum contamination

- Increase K+- Convert to SS

ARPO




Sea

wat

er

Die

sel

Fre

sh w

ater

LT

oil

Alte

rnat

ive

oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

inhi

bitio

n

For

mat

ion

inhi

bitio

n

LG

S to

lera

nce

Mai

nt. d

iffer

ence

Llo

gist

ic d

iffer

ence

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lubr

ican

t pro

pert

ies

Sol

id-r

emov

al e

q.

CU

TT

ING

MU

D


CO

ST

O




MIXING TIME

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

Exc

ess

lime

(kg/

m3)

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)


ADAVANTAGES AND LIMITATIONS

3

3

2

2 2

m /h3

GYPSUM-BASE FLUIDS FW/SW-GY

X A B A M B B M T3 B B B M

1.1

2.1

20 + WEIGHTING TIME

(X) X D4

- High solids and good cutting inhibition;- Can be weighted up to elevated values;- Can also be used at high temperatures;- Low cost;- Effectiveness can be enhanced by using KOH or Ca(OH)2 as alkaline agent;- Gelation problems may occur to high solids content fluid at high temperatures.

5046-1210-203-7as needed

40

60

10

45

3

8

1

1

5

15

8

2

5

35

9.5

10.5

15

0.2

0.5

1.2

0.6 30

70 10

20

- Used for drilling reactive shales and massive formations of CaSO4:- Gypsum is used as a Ca++ source;- Dispersed, Lignosulphonate base system;- The system may be more inhibitive if used in fresh water.

FRESH/SALT WATERBENTONITE ALCALINE AGENTFC-LIGNOSOLFONATEGYPSUMCMC-LV/LIGNITEBARITE

ARPO





Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

Cl

% S

and

SHALE + + + + =/- - - + +

CEMENT = +/- +/- + + + -

- INCREASE CaSO4 EXCESS- DECREASE MBT

SALT/SALTED WATER

HIGH TEMPERATURE

+ + + - -

MAINTENANCE

- Maintain excess Gypsum ranging from 10 to 20 kg/m3, regulate soluble Ca++ by varying pH from 9 to 10.5. When pH is low, Ca++ is more soluble, and inhibition and maintenance difficulty become higher.

RHEOLOGY

FILTRATE

- CMC LV is an optimum filtrate reducer. The concentration of soluble Ca++ affects the quantity of filtrate reducer needed;- For elevated temperatures use lignite to control the filtrate.

- Use FCL as a thinning agent. If Ca++ is high, gelation problems may occur, especially with high-solids content and temperatures near the system limit (150 °C).

- DECREASE MBT.- DECREASE EXCESS GYPSUM- ADD LIGNIN

+/- +/- +/- + - - =/+ +

- ADD. FCL- DECREASE pH WITH NaHCO3

- MODERATE CONTAMINATION- ADD FCL E CMC-LV- CONVERT TO FW-SS

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

ting

Mud


Cos

t




MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)

CHARACTERISTICS OF THE DRILLING FLUIDS


3

3

2

2 2

m /h3

LIME-BASE FLUIDS FW/SW-LI

X M B A M B M M T2 B B B M

1.1

2.15

20 + WEIGHTING TIME

X X D4

- High-solids tolerance and medium cutting inhibition;- Can be weighted up to high values;- Fairly good resistance to chemical contaminants;- Low cost;- Reduced calcium inhibitive effect due to the pH dispersing action;- Gelation problems may occur near temperature limit (130 °C).

38

65

8

55

4

10

1

1

3

15

10

2

5

40

12

12.5

8

20

2

5

70

20

5

23

- Used for drilling reactive shale formations, even at high temperatures;- Lime is used as the source of Ca++;- Dispersed, lignosulphonate-base system;- Two basic formulations: Low-Lime content and high-Lime content, varying from 5 to 20 kg/m3 of excess Lime respectively.

70-1203-86-128-3020/7as needed

WATERBENTONITE ALCALEFC-LIGNOSOLFONATELIMESTARCH/CMC-LVBARITE

0,1

0,4

ARPO





Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

Cl

% S

and

SHALE + + + + =/- = - + +

CEMENT = = = = +/= + -/=

- INCREASE EXCESS Ca(OH)2- REDUCE MBT

SALT/SALT WATER

HIGH TEMPERATURE

+ + + - -

MAINTENANCE

- Excess lime to be used depends on the formation reactivity;- The relationship betwen Pm/Pf with Pm>3Pf is vital as it provides exact indication of excess lime.

RHEOLOGY

FILTRATE

- CMC LV is an optimum filtrate reducer. The concentration of soluble Ca++ affects the quantity of filtrate reducer needed;- For elevated temperatures use lignite to control the filtrate.

- Increase: Prehydrated, lignosulphonate protected bentonite;- Decrease: Maintain excess lime within optimum values, add lignosulphonate, dilute.

+/- +/- +/- + - - =/+ +

GYPSUM = + + + - -/+ +

- MODERATE CONTAM.

- REDUCE MBT. - RED. Pm AND Pf. - ADD. CMC LV AND LIGNIN

- MODERATE CONTAM.- ADD FCL AND STARCH- CONVERT TO FW-SS

- ADD. NaOH- COVERT TO FW-GY

:

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud


Cos

t




MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)



3

3

2

2 2

m /h3

MOR-REX-BASE FLUID (KLM) FW/SW-MR

X X A B A A A B A T1 B A B M

1.1

2.1

15 + WEIGHTING TIME

(X) D4

- High solids tolerance and ;ood cutting inhibition;- Can be weighted up to high values;- Complex system, expert technicians are needed for maintenance;- Several products are needed for its formulation and maintenance, this may create supply problems;- Gelation problems may occur in high solids content fluids near temperature limit (130 °C).

40(1-3)6-12312-1710-15

40

55

15

50

4

8

1

3

2

15

10

6

5

35

12.5

12.5

15

15

2-3

2-3

2-4

2-4

0.4

0.8

60

MAX

10

15

- Used for drilling reactive shale formations, even at high temperatures;- Calcium and Potassium are added as KOH and Ca(OH)2, while Morex as a deflocculant and calcium chelant polymer;- Optimum application is in freshwater fluids with high ROP and density, but not too high temperatures.

as needed

FRESH/SALT WATERPREHYDRATED BENTONITE(BIOPOLYMER)MOR-REXKOHLIMEMOD. STARCHES/LIGNITEBARITE

ARPO




CONTAMINANTREMEDIAL

Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

Cl

% S

and

SHALE + + + + =/- - - + +

CEMENT = + + + + + +

CaSO4 + + + - -/+ +

SALT

HIGH TEMPERATURE

+ + + - -

MAINTENANCE

- System with floculation controlled by the balance between two salts and a polymer: Highly important to maintain the balance between Pf, Pm and Morex;- Always add Lime and Morex simultaneously in a ratio of 4/2 and 3/2 dependent on the characteristics desired and temperature.

RHEOLOGY

- Flocculation control is due to the ratio Lime/Morex. Do not use dispersers;- Keep MBT below 10%; For high densities and temperatures > 135 °C, do not exceed 4-6%.

FILTRATE

- Use starch as main filtrate reducer up to a temperature of 100 °C, for higher temperatures use starch and lignite in a ratio of 2/1 and 1/1;- Do not add alkaline agent to starch simultaneously as it may cause an increase of viscosity. Pre-solubilised lignite may be convienvent.

+/- + + + - - + +

- Ca++ AND MOR-REX

- ADD. LIME + MOR-REX

- DECREASE MBT

+ WATER + LIGNITE +

- IF Ca++ > 1200 ppm ADD. K2CO3- CONV. TO FW-GY

- DECREASE MBT. - ADD. LIGNITE FORFILTRATE.

- CONV. TO FW-SS

+KOH.

ARPO




3.3 OIL BASED FLUID

This section contains descriptions of the oil based fluids systems, their applications andlimitations.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud


Cos

t


FORMULAtion

MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pom

(cc

H2S

O4

N/1

0)

Mf

CaC

l2 (

%)

Pf Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity

(vol

t) O

/W R

atio

CHARACTERISTICS OF THE DRILLING FLUID @ 120 °F

2

2 2

m /h

DIESEL INVERT EMULSION FLUID DS-IE

A A A M A B M T4 A M A A

1.2

15 + WEIGHTING TIME

X X A D3

40 15 5 2 5 0 10 8 64 28 3 30 70/30 6 600



- Water emulsion in Oil with Oil as the filtrate;- Used for drilling shales, high temperatures, salt formations, deviated wells, water-damaging reservoir, completion fluid;- High density drilling fluids used when fluid recovery and re-use is advantageous.

- The emulsion has a nonionic continuous phase and does not interact with shale layers and the most common chemical contaminants;- Due to high environmental restrictions, the zero charge is needed;- Compared to other drilling fluids or zero discharge areas, it has the advantage of a low dilution ratio and the possibility to be re-used;- Lost circulation control, and Gas kick detection and maintenance may create some problems.

2.2 60 42 8 1.5 6 0 3 40 54 6 8 30 90/10 13 2000

PRODUCT kg-l/m 3

3

DIESELEMULSIFIER/SLIMEFILTRATE REDUCER (IF REQUIRED)BRINE (20-30% CaCl2)VISCOSIFIERWETTING AGENT (IF REQUIRED)BARITE

FORMULATIONS AND QUANTITIES DEPEND ON DENSITY, OIL/WATER RATIO AND SERVICE COMPANY'S FORMULATIONS.FOLLOW THE INSTRUCTION IN THE SPECIFIC MANUAL.

ARPO




REMEDIALS

Den

sity

PV

Yie

ld

Gel

s

F. H

PH

T

PO

M

0/W

EL.

ST

AB

.

CaC

l2

Wat

er

Wet

ting

Asp

ect

Cut

tings

SOLIDS + + + ++ =/- = (?) (PLASTIC)

WATER -/+ + + + + - - - - (+) (PLAST.)

- ADD.WETTING AGENT - DILUTE

- IF O/W OK, + EMULSION.IF O/W K.O., + OLIO X OK

MAINTENANCE

- An Oil-base fluid is traditionally easy to maintain. Pay attention to record dilutions and product quantities required in order to keep correct concentrations;- To avoid problems, constantly monitor any modifications of the characteristics, especially the electrical stability and HPHT filtrate. If any modifications, determine the possible causes and take prompt remedial actions.

RHEOLOGY

- Should be determined at a temperature of 120 or 150oF. Do not use marsh viscosity for maintenance;- Water is the principle viscosifier of Oil-base fluids. Its percent will vary depending on the characteristics required. Other viscosifiers enhance yield point and Gels. Viscosity is also given by solids, thus it is essential to decrease the water content in the fluid by increasing density.

FILTRATE

-The main filtrate reducer is given by the quality of emulsion. Other filtrate reducers may be needed for high temperatures or for very low HPHT filtrate values.

CONTAMINANTS

CaCl2 > 35% + - (PLAST.) +/- +/- =/+ - LIGHT CONTAM.- CONV. TO DS/LT-IE

ARPO




)

Sea

Wat

er

Die

sel

Fre

sh W

ater

LT O

il

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

D

ensi

ty

Lub

rican

t Pro

pert

ies

Sol

id-r

emov

al E

q.

Cut

tings

Mud


Cos

t


FORMULATION

MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pom

(cc

H2S

O4

N/1

0)

Mf

CaC

l2 (

%)

Pf Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity.

(vo

lt) O

/W R

atio


2

2 2

m /h

DIESEL INVERT EMULSION, FILTRATE RELAXED FLUID DS-IE-RF

A A A M A B M T4 A M A A

1.2

15 + WEIGHTING TIME

X X A D3

40 15 5 2 5 2 15 8 64 28 3 30 80/20 6 600


- Same advantages as a conventional Oil-base fluid with higher penetration rates;- Due to a minor emulsion concentration, the range of temperature is limited to max 350 °F;- Same environmental restrictions as DS-IE.


- Water emulsion in Oil with Oil as the filtrate- Same applications as the conventional Oil-base fluid. Thanks to its characteristics of high filtrate it helps improve penetration rates in permeable formations.

2.2 60 42 8 1.5 6 8 20 40 54 6 8 30 90/10 13 1000

PRODUCT kg-l/m 3

3

DIESELEMULSIFIER/SLIMEFILTRATE REDUCER (IF REQUESTED)BRINE (20-30% CaCl2)VISCOSIFIERWETTING AGENT (IF REQUIRED)BARITE

FORMULATIONS AND QUANTITIES DEPENDS ON DENSITY, WATER/OIL RATIO AND ON THE SERVICE COMPANY'S FORMULATIONS.FOLLOW THE INSTRUCTIONS IN THE SPECIFIC MANUAL.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud


Cos

t



MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c.

(cps

)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pom

(cc

H2S

O4

N/1

0)

Mf

CaC

l2 (

%)

Pf Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity

(vol

t) O

/W R

atio


3

2

2 2

m /h

100% DIESEL INVERT EMULSION FLUID DS/LT-IE-100

A A A M A A A T4 A A A A

1.4

20 + WEIGHTING TIME

X A D5

12 5 2 3 0 10 18 82 0 100/0 2000+

FILTRATE REDUCERWETTING AGENT

3

DIESEL/LT OILEMULSIFIER/SLIME

VISCOSIFIERBARITE / CaCO3

FORMULATIONS AND QUANTITIES DEPEND ON DENSITY, AND SERVICE COMPANY'S FORMULATIONS.FOLLOW THE INSTRUCTIONS ON THE SPECIFIC MANUAL.

X



- 100% Diesel or low toxiticity Oil, Oil-base fluid;- A small quantity of emulsifier helps tolerate up to 10% water invasion;- Non-damaging Oil-base fluid system, purposely designed for coring and drilling Oil mineralised formation.

- The lack of water and energic emulsifiers limits damages to the Oil-mineralised formation;- Easily convertible to a simple Oil-base fluid or to a packer-fluid;- Purposely prepared, it is not possible to recover the original oil-based fluid, because of the high concentrations of surfanctants;- If prepared with Diesel it shows the same environmental restrictions as DS-IE.

ARPO




3.4 INHIBITED AND/OR ENVIRONMENTAL FLUIDS

This section contains descriptions of inhibited and environmentally friendly fluid systems,their applications and limitations.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rica

nt P

rope

rtie

s

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud


Cos

t



MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c.

(cps

)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)


3

3

2

2 2

m /h3

POTASSIUM CARBONATE-BASE FLUID FW-K2

X X A M B A A B A T2 D3 B A B B

1.1

1.8

20 + WEIGHTING TIME



- Conditioned with non-dispersed K2CO3 which has been added to KCMC and KPAC;- Used for drilling reactive shales;- Drilling formations which, when hydrated, have sloughing and/or swelling tendencies;- Can be used as a completion fluid or as a no-solids drilling fluid up to a density of 1,58 sg.

- Non-corrosive;- No environmental limitations as per KCl;- At >100 °C CO2 is freed;- Can interfere with the cement plug;- If used as a W.O. fluid, then avoid using in presence of Lime waters;- K+ has a destabilising effect on caolinic formations.

40

50

8

36

4

8

1

2

4

12

6 0

25

10.5

11.5

0 30

MAX

FRESH WATERBENTONITE(K)PAC(K)CMCK2CO3BARITE(BIOPOLYMER)

404-65-720-30

as neededas needed

ARPO





Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

NaC

l

% S

and

SHALE + + + + +/- - - + +

CEMENT = +/- + + + + + +

CaSO4 = +/- + + + - = =/+ +

SALT =/+ +/- + + + - - - +

- ADD PHPA

- PRETREAT WITH

- ADD. PHPA LMW. - INCREASE INHIBITION

NaHCO3

- ADD. Na2CO3- CONV IN FW/SW GY- ADD FCL

- CONTAMINANT IS DEPENDENT ON MBT- CONV. TO FW/SW-SS

MAINTENANCE

- Encapsulating system: An adequate concentration of polymer (3>kg/M3) is needed to limit cutting dispersion and high increase of viscosity;- Easily convertible to a potassium-base system;- Polymer may be added wherever but not through the hopper to avoid foam formation;- Can tolerate up to 170°C by using additives.

- RHEOLOGY

- Decrease: Deflocculate using a short chain polymer (i.e.: short chain CMC LV, PHPA); Dilute; If a more energic action is needed, them add CL and/or FCL.

FILTRATE

- Use the most adequate a filtrate reducer according to the usage: (temperature, density, salinity).

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. D

iffer

ence

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

ings

Mud


Cos

t




MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c.

(cps

)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(%

in v

ol.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)

CHARACTERISTICS OF THE FLUIDS


3

3

2

2 2

POTASSIUM ACETATE-BASE FLUID FW-KA

X X A M M A M M A T3 B A B M (X)

- KAC is a high cost salt (5-6 times KCl);- Less corrosive than KCl;- Disposal difficulties due to a high COD;- Same K+ concentrations as KCI addition of +KAC (+30%) is required.

m /h3

25 + WEIGHTING TIME

- FORMULATIONS ARE TRADITIONALLY THOSE OF THE BASE SYSTEMS USED;

- PRODUCT CONCENTRATIONS ARE GENERALLY HIGH;

- A BIOPOLYMER IS OFTEN USED AS A VISCOSIFIER TO PROVIDE THE SYSTEM WITH ADEQUATE SUSPENDING CHARACTERISTICS.

1.05

2.0

THE CHARACTERISTICS ARE TRADITIONALLY THOSE OF THE BASE SYSTEM USED.

Pf AND Pm EVALUATIONS ALTERED BY ACETATE.

- Conditioned with K-Acetate, preferably to polymers and non-dispersed;- K can be also added to high density and HT systems;- Safe alternative to KCI in environmental sensitive areas;- Same applications as KCl.

ARPO




CONTAMINANTS REMEDIAL ACTIONS

DE

NS

ITY

PV

YIE

LD

GE

LS

FIL

TR

AT

E

pH Pf /

Pm

Mf

SO

LID

S

MB

T

Ca

NaC

l

% S

AN

D

SHALE + + + + =/- - - + +

CEMENT +/- + + + + +

- Deflocculate or disperse.

NaCl/SALT WATER +/- +/- +/- +/- + - +

MAINTENANCE

- More than other K+ base system, it is particulary designed for use in dispersed high density and/or high temperature fluids;

- Estimate the the cuttings over shale shakers and adapt K+ concentrations.

- RHEOLOGY AND FILTRATE

- Controlled as per the base fluid system used.

CaSO4 +/- +/- + + =/- +

HIGH TEMPERATURES

+ + + - -

- Increase K+ concentration.

- Pretreat with KHCO3

- Dilute.

- Adapt K+.- Convert to KCl.- Convert to FW/SW-SS

- Add K2CO3- Use polymers resistant to CA++.

- Reduce MBT, - Disperse with CL/FCL

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-Dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. T

oler

ance

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t P

rope

rtie

s

Sol

ids-

rem

oval

Eq.

Cut

ting

Mud


Cos

t



MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)


3

3

2

2 2

m /h3

HIGH TEMPERATURE (> 200 °C) WATER-BASE FLUIDS FW/SW-HT

X X B B B M M A A T4 B AA B B

1.1

1.8

20 + WEIGHTING TIME

X X D3

30-353-41-210-301-5as needed

38

50

10

55

4

8

1

1

5

12

10

2

30

10

5

30

9.5

10.5

0.3

0.7

30

30

WATERBENTONITE (no peptine added)NaOHSSMA POL.LIGNITEHT POLYMER MIXTURE BARITE



- Designed for elevate temperatures and/or geothermic wells; alternative to DS-IE.- The basic formulation depends on the use of bentonite and a deflocculant polymer (SSMA) suitable for elevate temperatures;- Lower costs and difficulties to control filtrate compared to systems employing sepiolite and/or polymer as viscosifiers.

- Safe alternative to Oil-base fluids in environmental sensitive areas;- Lower maintenance costs compared to HT water-base formulations;- Can also be employed in salt saturated fluids, and in presence of biavelent ions.

ARPO





Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

Cl % S

and

SOLIDS + + + + =/- = - + +/-

CEMENT = = = + + + +

SALT/SALT WATER

HIGH TEMPERATURE

+ + +/= - +/-

+/- + - - +

MAINTENANCE

- Solids control is highly important, therefore always monitor solids percentage, reactivity, and size by means of adequate analyses;- Verify rheology at 120 °F;- Maintain the fluid chemical parameters within the values. At high temperature all reactions may result accelerated.

RHEOLOGY

- Increase: Prehydrated and SSMA protected bentonite;- Decrease: Dilution.

FILTRATE

- Filtrate reducers must be chosen according to temperature and ionic environment, such as: Chromelignin, HT polymer mixture (i.e. Resinex), polyacrylates and polyacriyamides. In case of high concentrations of bivalent ions, use copolymers based on amps.

- DILUTE

- LIGHT CONTAMINATION

- CONV. TO DS/LT-IE

- CONTAMINATION DEP. ON POLYMERS USED- ADD. Na2CO3

+/- +/- =/+

+ - REDUCE MBT- REDUCE Pf AND Mf TO VALUES EQUIVALENT TO OH- IN THE FLUID.

ARPO







MIXING TIME:


3

m /h3

CATION-BASE FLUID FW/SW-CT

X X A M A A A A T2 B AA A A

15 + WEIGHTING TIME

X

- Fluid with cationic polymers which, thanks to their positive charge, are inhibitive and flocculant;- It inhibits the reactive shales without using an inhibitive salt.

D3

- Inhibition is due to the absorption of polymers on the shale surface;- Cationic polymers, though toxic, have fewer environmental restrictions than conventional water-base fluids;- Cationic polymers are not compatible with conventional anionic polymers. Therefore, maintain some anion concentrations (Cl-, from NaCl or KC) in the fluid in order to overcome incompatibility. Always verify incompatibility.

VISCOSIFIERALKALINITY AGENTCATIONIC POLYMERFILTRATE REDUCERDEFLOCCULANTWAIGHTING INHIBITIVE SALT

FORMULATIONS ARE STRICTLY DEPENDENT ON THE CATIONIC POLYMERS CHOSEN. EACH COMPANY HAS A SPECIFIC FORMULATION.

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(kg/

m e

quiv

.)


3

2

2 2

1.1

1.8

45

60

10

40

2

10

1

2

2

10

7

3

30

12

10

30

9

MAX

(50)

(MIN.)

()FOR SOME FORMULATION ONLY

Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. T

oler

ance

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t P

rope

rtie

s

Sol

ids-

rem

oval

Eq.

Cut

ting

Mud


Cos

t

ARPO





Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

Cl

%S

and

SHALE + + + + =/- - - + +

CEMENT = + + + + + +

CaSO4 +

SALT/SALT WATER

HIGH TEMPERATURE

+ + + - - +

MAINTENANCE

- Tolerance between cationic and conventional (anionic) polymers should be verified. Tolerance is traditionally possible for formulations with a certain content of chloride ion;- Never use lignosulphonates or other anionic polymers, even in presence of chlorides. Do not increase pH above 9.5 value.

RHEOLOGY

- System maintenance may be difficult due to the poor availability of compatible products with cationic polymers;- Generally a biopolymer and/or HEC is used as a viscosifier;- Solids control is highly important.

- ADD.CATIONIC POLYMER

- ADD. CH3COOH

- DILUTE

- ADD. NaHCO3

- NO CONTAMINATION

- REDUCE MBT. - DEFLOCCULATE

- NO CONTAMINATION

+/- +

FILTRATE

- The most used filtrate reducers are: Modificated starches, kaolinte, prehydrated and PVA (Polyvinil alcohol) protected bentonite;- PAC can be employed in presence of electrolytes.

ARPO





DESCRIPTION OF THE SYSTEM CODICE AGIP



MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c.

(cps

)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pm

Mf

NaC

l (gr

/l)

Ca

(gr/

l)

Pf

O/W

Rat

io

Ele

ctric

al S

tabi

lity

(vol

t) M

BT

(g/m

equ

iv.)

CHARACTERISTICS OF THE FLUID

3

3

2

2 2

m /h

GLYCOL-BASE FLUID FW/SW-GL

X X M B B A A M A T2 M A B B

20 + WEIGHTING TIME

X D2

1.1

1.8

CHARACTERISTICS, ESPECIALLY THE PV, ARE DEPENDENT ON THE % OF GLYCOL AND BASE SYSTEM USED (TRADITIONALLY PHPA).

3

BENTONITE CAUSTIC SODAPHPA and/or PACGLYCOLMODIFIED STARCH and/or Na POLYACRYLATESBIOPOLYMERBARITE

10-3038/310-4006/22as needed


- Polymer-base fluid conditioned with glycol which may contain inhibitive ions;- Designed as an environmentally safe alternative to conventional oil-base fluid and as a shale formation inhibitor;- May help with problems relating to the formation of 'Hydrated gases'.

N.B. This system is being developed.

- In product usage percentages of 3-5%. It behaves as a lubricant, in percentages varying from 10 to 40%. It is comparable to FW-KC for its inhibition characteristics;- Very high costs, considering low solids tolerance;- Not a competitive alternative to oil-base fluid, and even when OBM cannot be employed, preferably estimate to use other systems before choosing the glycol-base fluid.

Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. T

oler

ance

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

ting

Mud

Cos

t

ARPO





Den

sity

PV

Yie

ld

Gel

s

Filt

rate

pH Pf /

Pm

Mf

Sol

ids

MB

T

Ca

Cl

%S

and

SHALE + + + + =/- - - + +

CEMENT = + + + + + +

CaSO4 = + + + +

SALT/SALT. WATER

HIGH TEMPERATURE

+ + + - - +

MAINTENANCE

- Fluid maintenance is that of the base system used;- Determination of glycol content may result difficult;- If glycol percentage increases, Then PV increases dramatically, thus limiting the solids content allowed in the system (density and LGS limits).

RHEOLOGY

- Prior to dilution, try to use small concentrations of short-chain polymer (i.e. CMC LV), or chrome-free lignosulphonate.

FILTRAT

- Use starch up to approx. 100 oC, for higher temperatures PAC and/or CMC for temperatures more than 140-150 oC, Napolyacrylate is recommended.

- DEFLOCCULATE

- PRETREAT WITH

- DILUTE

NaHCO3

- USE PRODUCT TOLERANT Ca++ - ADD. Na2CO3

- USE HT BASE SYSTEM

- REDUCE MBT.

- CONTAMINATION DEPEND ON BMT, AND POLYMER TYPE.

+/- +/- +/- + - - +

N.B.This system is being developed. The information given is general and subject to modification.

ARPO








MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pom

(cc

H2S

O4

N/1

0)

Mf

CaC

l2 (

%)

Pf Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity

(vol

t) O

/W R

atio



3

2

2 2

m /h3

LOW TOXICITY OIL, INVERT EMULSION DRILLING FLUID LT-IE

A A A M A B M T4 A M M A

1.2

15 + WEIGHTING TIME

X A D3

40 15 5 4 5 0 10 8 64 28 3 30 70/30 6 600

LOW-AROMATIC CONTENT MINERAL OILEMULSIFIER/SLIMEFILTRATE REDUCER (if required)BRINE (20-30% CaCl2)VISCOSIFIERWETTING AGENT (if required)BARITE

- Exactly the same as DS-IE, except for the mineral oil base fluid which is low-aromatic, hydrocarbon content, and low toxiticity.

2.2 60 42 8 1.5 6 0 3 40 54 6 10 30 90/10 13 1500

FORMULATION AND QUANTITIES DEPEND ON DENSITY, WATER/OIL RATIO, AND SERVICE COMPANY'S FORMULATIONS IN THE SPECIFIC MANUAL.

- May be more advantageous than DS-IE if used in some areas where off-shore discharge is allowed for the max percentage of cuttings from traditional oil-base fluids;- In areas where disposal percentage is near zero or 'zero', LT oil-base fluid is not convenient;- Higher product concentrations compared to DS-IE.

Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. T

oler

ance

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud

Cos

t

ARPO




REMEDIAL

Den

sity

PV

Yie

ld

Gel

s

HP

HT

F.

PO

M

0/W

El.

Sta

b.

CaC

l2

Wat

er

Wet

ting

Cut

tings

Asp

ect

SOLIDS + + + ++ =/- = (?) (PLAST.)

WATER -/+ + + + + - - - - (+) (PLAST.)

CaCl2 > 35%

HIGH TEMPERATURE

- - + - - =

- ADD FILTRATE REDUCERS

+ - (+) (PLAST.) +/- +/-

-

CONTAMINANTS

OIL - - - - - = + - -

- ADD. WETTING AGENT

- DILUTE

PERCENTAGE

- ADDEMULSIFIERS

- ADD. FRESH WATER


-IF O/W IS OK,

THAN RESTORE ADDITIVE

-IF O/W IS NOT OK

THAN ADD LT OIL+ ADDIT. %

MAINTENANCE

- Refer to DS-IE for maintenance procedures;- Control if oil percentage of cuttings from oil-base fluid is within the values to allow the discharge. Take all actions to maintain this percentage low;- Optimise solids-removal equipment;- Maintain the lowest oil/water ratio, compatible to the characteristics required.

PERCENTAGE

-IF O/W IS OK,

THAN RESTORE ADDITIVE

-IF O/W IS NOT OK

-IF O/W IS OK,THEN RESTORE ADDITIVE PERCENTAGE

- IF O/W IS NOT OK THEN ADD WATER + ADDIT.%

ARPO






FORMULATION

MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pom

(cc

H2S

O4

N/1

0)

Mf

CaC

l2 (

%)

Pf Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity

(vol

t) O

/W R

atio

CHARACTERISTICS OF THE DRILLING FLUID @ 120°F

2

2 2

m /h3

50/50 O/W INVERT EMULSION DRILLING FLUID LT-IE-50

A A M A M M A T2 A M M A

1.45

15 + WEIGHTING TIME

X A D2

+/- 40 10 4 10 0 8 20 40 40 1 20 50/50 4 +/-

PRODUCT

LOW AROMATIC CONTENT, MINERAL OILEMULSIFIER/SLIMEBRINE (20-25% CaCl2)VISCOSIFIERBARITE

80 50 15 8 0 10 25 2.5 25 10 500

kg-l/m 3

FORMULATIONS AND QUANTITIES DEPEND ON DENSITY, WATER/OIL RATIO, AND SERVICE COMPANY'S FORMULATIONS.REFER TO INSTRUCTION IN THE SPECIFIC MANUAL.



- LT-IE fluid, purposely designed with a high water content to reduce cuttings from oil-base fluids and discharge them offshore within the limits allowed;- Used in off-shore areas where discharge of fluid is allowed with +/- 10% residual oil.

- Easier control of low-residual oil from cuttings compared to conventional LT-IE ;- Highest inhibition grade of any water-base fluid ;- Difficult maintenance as it is not possible to decrease density above 1.4 - 1.5 values when solids tolerance is low;- Unstable to high temperatures.

Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. T

oler

ance

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

Sol

ids-

rem

oval

Eq.

Cut

tings

Mud

Cos

t

ARPO




REMEDIAL

Den

sity

PV

Yie

ld

Gel

s

F. H

PH

T

PO

M

0/W

EL.

Sta

b.

CaC

l2

Wat

er

Wet

ting

Asp

ect

Cut

tings

SOLIDS + + + ++ =/- = (?)

(PLAST.)

WATER -/+ + + + + - - - - (+) (PLAST.)

CONTAMINANTS

OIL - - - - - = + - -


- DILUTE

-IF O/W RATIO IS OK, THEN RESTORE ADDITIVE%.

-IF THE O/W IS NOT OK, THEN ADD LT OIL + ADDITIVE%.

- IF O/W IS OK, THEN RESTORE ADDITIVE %.

-IF THE O/W IS NOT OK, THEN ADD WATER + ADDITIVE %.

MAINTENANCE

- Generally maintained as an oil-base fluid;- Unstable due to the high water percentage and more difficult to maintain than a conventional oil-base fluid;- Low electrical stability. Emulsion quality is evaluated from HPHT filtrate by verifying the absence of water.

RHEOLOGY

- Very high rheology;- High viscosity may allow a high percentage of residual fluid, and oil from cuttings. To reduce viscosity, increase the O/W ratio. However, this may also increase oil from cuttings, find a right balance between the two factors.

FILTRATE

- HPHT filtrate provides stability to the system. Its maintenance is highly important. Avoid overtreatment with emulsifiers or filtrate reducers for excessive viscosity.

ARPO




Sea

Wat

er

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

bitio

n

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt D

iffre

nce

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t P

rope

rtie

s

Sol

id-r

emov

al E

q.

Cut

tings

Mud


Cos

t



MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c.

(cps

)

Den

sity

(S

G)

Yie

ld P

oint

(gr

/100

cm )

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pom

(cc

H2S

O4

N/1

0)

Mf

CaC

l2 (

%)

Pf Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity

(vol

t) O

/W R

atio


3

2

2 2

m /h3

INVERT EMULSION, ESTER-BASE FLUID EB-IE

A A A M A B M T2 A AA B A

1.5

15 + WEIGHTING TIME

X A D3

+/-35 13 10 0

2 1 1580/20

4 600

802

5 2 25 8 1000

613148252566665c.n.

ESTERWATEREMULSIFIERFILTRATE REDUCER (if required)LIMEVISCOSIFIERTHINNER/SCaCl2BARITE



- Ester-base emulsion;- Thanks to no-aromatic content and biodegradability, cuttings can be discharged as per water-base fluids;- In off-shore areas where discharge of cuttings from oil-base fluids is restricted as well as for the high costs on-shore transportations, it is a valid alternative to water-base fluids.

- All advantages of an oil-base fluid but lower environmental restrictions;- Can be used up to 150 °C and a max density of 1,8 kg/l;- High cost.

ARPO







MIXING TIME:

Fun

nel V

isc.

(se

c/qt

)

Pla

stic

Vis

c. (

cps)

Den

sity

(SG

)

Yie

ld P

oint

(gr

/100

cm

)

Gel

10"

(gr

/100

cm )

Gel

10'

(gr/

100c

m )

AP

I Filt

rate

(cc

/30'

)

AP

I HT

HP

(cc

/30'

)

Sol

ids

(% in

vol

.)

Oil

(% in

vol

.)

Wat

er (

% in

vol

.)

San

d (%

in v

ol)

pH Pom

(cc

H2S

O4

N/1

0)

Mf

Ca

Cl2

(%

)

Pf Exc

ess

Lim

e (k

g/m

3)

Ele

ctric

al S

tabi

lity

(vol

t) O

/W R

atio


3

2

2 2

m /h3

INVERT EMULSION, POLIOLEFINE-BASE FLUID PO-IE

A A A M A B A T3 A AA B A

1.32

15 + WEIGHTING TIME

X A D4

+/- 30 5 2 5 0 5 1 25 70/30 +/-

70 600

POLIOLEFINEBRINE (CaCl2))EMULSIFIERWETTING AGENTLIMEVISCOSIFIERFILTRATE REDUCERBARITE



- Polyolefine-base emulsion;- Thanks to no-aromatic-content and biodegradability, cuttings can be disposed of 'zero' discharge;- In off-shore areas where discharge of cuttings from oil-base fluids is restricted as well as for the high costs on-shore transportations, it is a valid alternative to water-base fluids.

- All advantages of an oil-base fluid but lower environmental restrictions;- Better compatility to rubber parts compared to DS/LT-IE;- Can be used up to 180 °C an max density of approx. 2.2 kg/l;- High cost;- H igher viscosity than a conventional DS/LT-IE.

580275156176AS NEEDEDAS NEEDED

Se

a W

ater

Die

sel

Fre

sh W

ater

LT

Oil

Alte

rnat

ive

Oil

Non

-dis

pers

ed

Dis

pers

ed

Cut

ting

Inhi

biti

on

For

mat

ion

Inhi

bitio

n

LG

S T

oler

ance

Mai

nt. T

oler

ance

Log

istic

Diff

eren

ce

Con

vert

ible

Re-

use

Tem

pera

ture

Den

sity

Lub

rican

t Pro

pert

ies

So

lids-

rem

oval

Eq

.

Cut

tings

Mud

Cos

t

ARPO




4. FLUID MAINTENANCE

In this section are flow charts related to the reading of water based fluid daily drillingreports. These charts are should be read according to the general decision process asfollows:

IS THERE A PROBLEM ?

YES/NO

IF YES, WHAT IS THE PROBLEM ?

ANSWER

WHAT HAS BEEN DONE TO SOLVE IT ?

EVALUATE

WHAT ELSE CAN BE MADE TO SOLVE ITWHICH HAS NOT BEEN MADE YET ?

TAKE ACTION

ARPO




4.1 WATER BASED FLUIDS MAINTENANCE

4.1.1 Analysing Flow Chart For Water Based Fluid Reports

Note: Inadequate characteristics may cause well problems. It is important tounderstand what and how many variations are needed to solve anyproblems occur .

LEGEND: ( + increase; - decrease; = unchanged.)

GELS

PROGRESSIVE

YIELD POINT +

FILTRATE =/-

CAKE =/-

SOLIDSCONTAMINATION

CHEMICALCONTAMINATION

EXCESSVISCOSIFIER

ESTIMATE:

PVDENSITY% SOLIDSLGS/HGSMBT

ESTIMATE:

Solids RemovalEquipment

and notes onDilution

ESTIMATE:

pH

PM,PF,MF

Cl-

Ca++

Mg++

etc....- READ COMMENTS

- ANALIZE WELL PROBLEMS

- MATERIALS USED

- ANALIZE ANY VARATIONS OFCHARACTERISTICS WITHIN 24 HOURS.

FLAT (es.: 2/4)and/or as per

Programme

FILTRATE +

CAKE +

(es.: 1/15)

FLASH

( es.: 6/12)

ARPO




4.1.2 Maintenance Problems

CA

US

ER

EM

ED

IAL

AC

TIO

NS

EFF

EC

T O

N F

LUID

MA

INTE

NA

NC

E P

RO

BLE

MS

OF

WA

TER

-BA

SE

FLU

IDS

+ + +

+ + +

+ + +

+

(+)

Ca

OH

Ca

SO

4

Cl

DENSITY

PV

YIELD

GELS

FILTRATE

pH/Pf

SOLIDS

IONS

OTHER

GY

PS

UM

/AN

HY

DR

IDE

NaC

l, F

OR

MA

TIO

N:

SA

LT D

OM

E, S

ALT

LE

VE

LS,

FO

RM

AT

ION

OR

M

AK

E-U

P W

AT

ER

.

CE

ME

NT

AN

D/O

R L

IME

CO

NT

AM

INA

TE

D B

AR

ITE

PR

ET

RE

AT

OR

TR

EA

T W

ITH

BIC

AR

BO

NA

TE

;P

OLY

ME

R-B

AS

E F

LUID

S N

EE

D P

RE

TR

EA

TM

EN

T.

MO

NIT

OR

EX

CE

SS

LIM

E T

O C

ON

TR

OL

CO

NT

AM

INA

TIO

N

RE

MO

VA

L, D

O N

OT

RE

LY O

NLY

ON

Ca+

+.

US

E D

ES

AN

DE

RS

OR

CE

NT

RIF

UG

E T

O R

EM

OV

E

CO

NT

AM

INA

NT

PA

RT

ICLE

S;

AD

D D

EF

LOC

CU

LAN

TS

AN

D F

ILT

RA

TE

RE

DU

CE

RS

.D

ILU

TE

; DU

MP

TH

E C

ON

TA

MIN

AT

ED

PIL

L, I

F

FLO

CC

ULA

TIO

N C

AN

NO

T B

E C

ON

TR

OLL

ED

.C

ON

VE

RT

TO

LIM

E F

LUID

.IN

SO

ME

CA

SE

S (

i.e. C

aCl2

SO

LUT

ION

S A

ND

PO

LYM

ER

S)

US

ES

AC

IDS

SU

CH

AS

HC

l.S

OD

IUM

CA

RB

ON

AT

E C

AN

ALS

O B

E U

SE

D, B

UT

RE

MO

VE

S

CA

LCIU

M A

ND

NO

T O

H-.

PR

ET

RE

AT

/TR

EA

T W

ITH

SO

DIU

M C

AR

BO

NA

TE

IF R

ED

UC

ED

QU

AN

TIT

IES

; C

ON

VE

RT

TO

A F

LUID

TO

LER

AN

T

OF

GY

PS

UM

: F

W-G

Y, F

W-S

S,

DS

-IE

.

DIL

UT

E W

ITH

FR

ES

H W

AT

ER

.U

SE

TH

INN

ER

S A

ND

FIL

TR

AT

E R

ED

UC

ER

FO

R S

ALI

NE

E

NV

IRO

NM

EN

T.

CO

NV

ER

T T

O S

ALT

FLU

ID O

R S

ALT

SA

TU

RA

TE

D F

LUID

.E

ST

IMA

TE

TO

DU

MP

IF

CO

NT

AM

INA

TIO

N IS

LIM

ITE

D T

O A

P

ILL.

HIG

H V

ISC

OS

ITY

WIT

H

FLO

CC

ULA

TE

D F

LUID

.P

OLY

ME

R-B

AS

E F

LUID

S M

AY

H

AV

E A

ST

RO

NG

VIS

CO

SIT

Y.

HIG

H V

ISC

OS

ITY

WIT

H

OR

WIT

HO

UT

PIT

V

OLU

ME

INC

RE

AS

E.

HIG

H V

ISC

OS

ITY

WIT

H

PR

OG

RE

SS

IVE

IN

CR

EA

SE

.

ARPO




CA

US

ER

EM

ED

IAL

EFF

EC

T O

N F

LUID

MA

INT

EN

AN

CE

PR

OB

LEM

S O

F W

ATE

R-B

AS

E F

LUID

S

MgC

l2, F

RO

M

FO

RM

AT

ION

:W

AT

ER

WIT

H M

gCl2

C

OM

PLE

X S

ALT

S, S

EA

W

AT

ER

.

VIS

CO

SIT

Y IN

CR

EA

SE

WIT

H/W

ITH

OU

T V

OLU

ME

IN

CR

EA

SE

.D

IFF

ICU

LTY

TO

MA

INT

AIN

pH

.

HIG

H V

ISC

OS

ITY

, P

AR

TIC

UL

AR

LY

YIE

LD

AN

D G

ELS

AT

10"

.U

NE

FC

ET

VE

T

RE

AT

ME

NT

S.

FO

RM

AT

ION

CO

2:T

HE

RM

AL

DE

GR

AD

AT

ION

OF

P

OLY

ME

RS

:C

ON

TA

MIN

AT

ED

B

AR

ITE

,O

VE

RT

RA

TM

EN

T W

ITH

B

ICA

RB

ON

AT

E O

R

CA

RB

ON

AT

E, N

aC

O3

A

DD

ED

BE

NT

ON

ITE

.

+ +

+-/

- M

g

Cl

CO

NT

AM

INA

TIO

N D

IFF

ICU

LT T

O R

EC

OG

NIZ

E, E

SP

EC

IALL

Y IN

C

OLO

RE

D F

ILT

RA

TE

S.

INC

RE

AS

E p

H W

ITH

NaO

H, I

F C

ON

TA

MIN

AT

ION

IS D

UE

TO

H

CO

3 A

ND

Ca+

+ IS

PR

ES

EN

T T

HE

FLU

ID;

US

E C

a(O

H)2

, IF

Ca+

+ I

S N

OT

PR

ES

EN

T O

R U

SE

CaS

O4

IF p

H

INC

RE

AS

E IS

NO

T D

ES

IRE

D;

US

E c

AC

l2 F

OR

BR

INE

OR

CH

LOR

IDE

CO

NT

EN

T F

LUID

S.

AT

TE

NT

ION

: DU

MP

AL

L C

ON

TA

MIN

AN

TS

TH

OR

OU

GH

LY, A

S

SM

ALL

CO

NC

EN

TR

AT

ION

MA

Y C

RE

AT

E P

RO

BLE

M T

O F

LU

ID

MA

INT

EN

AN

CE

, AV

OID

OV

ER

TR

EA

TIN

G W

ITH

SE

QU

ES

TR

ING

IO

N (

Ca+

+).

PA

Y A

TT

EN

TIO

N T

O H

IGH

TE

MP

ER

AT

UR

E, H

IGH

DE

NS

ITY

A

ND

/OR

PO

LY

ME

R-B

AS

E F

LU

ID.

TR

EA

T W

ITH

CA

US

TIC

SO

DA

FO

R L

IGH

T C

ON

TA

MIN

AT

ION

AN

D

MA

INT

AIN

pH

>/=

10.

CO

NV

ER

T T

O A

FLU

ID T

OLE

RA

NT

OF

MA

GN

ES

IUM

(S

ALT

S

AT

UR

AT

ED

, LO

W p

H, M

IXE

D S

ALT

SA

TU

RA

TE

D O

R O

IL-B

AS

E

FLU

ID)

IF C

ON

TA

MIN

AT

ION

IS S

EV

ER

E.

AT

TE

NT

ION

: CO

NT

INU

ED

AD

DIT

ION

S O

F M

g(O

H)2

TO

TH

E

SY

ST

EM

WIL

L R

ES

ULT

IN A

GR

EA

T V

ISC

OS

ITY

INC

RE

AS

E.

DENSITY

PV

YIELD

GELS

FILTRATE

pH/Pf

SOLIDS

IONS

OTHER

+ +

=/+

Mf+

ARPO




CA

US

ER

EM

ED

IAL

EF

FE

CT

ON

FLU

ID

MA

INT

EN

AN

CE

PR

OB

LEM

S O

F W

AT

ER

-BA

SE

FLU

IDS

H2S

FR

OM

FR

OM

AT

ION

TH

ER

MA

L O

R B

AC

TE

RIA

LD

EG

RA

DA

TIO

N

ST

INK

ING

WE

LLV

ISC

OS

ITY

IN

CR

EA

SE

.

DIF

FIC

ULT

Y T

O C

ON

TIN

UE

D

RIL

LIN

G A

FT

ER

TR

IPP

ING

, D

IFF

ICU

LTY

TO

RU

N T

OO

LS

IN H

OLE

, HIG

HL

Y

GE

LAT

INIZ

ED

BO

TT

OM

PIL

L.

HIG

H T

EM

PE

RA

TU

RE

+ +

+-

s--

RE

DU

CE

DIL

L S

OLI

DS

CO

NC

EN

TR

AT

ION

; IN

CR

EA

SE

D

ISP

ER

SE

R C

ON

CE

NT

RA

TIO

N; U

SE

FIL

TR

AT

E R

ED

UC

ER

S

AD

EQ

UA

TE

TO

TE

MP

ER

AT

UR

E,

BY

KE

EP

ING

HP

HT

FIL

TR

AT

E

AT

VA

LU

ES

SU

FF

ICIE

NT

TO

PR

EV

EN

T F

LUID

DE

HY

DR

AT

ION

W

HIL

E T

RIP

PIN

G.

DIS

PLA

CIN

G A

PR

ET

RE

AT

ED

FLU

ID P

ILL

IN T

HE

OP

EN

HO

LE

MA

Y R

ES

ULT

CO

NV

EN

IEN

T.

IF F

RO

M F

RO

MA

TIO

N,T

RE

AT

WIT

H S

CA

VE

NG

ER

S;IN

RIS

KY

A

RE

AS

PR

ET

RE

AT

AN

D/O

R M

AIN

TA

IN A

LKA

LIN

ITY

.IF

FR

OM

TH

E T

HE

RM

AL

DE

GR

AD

AT

ION

, RE

PLA

CE

PR

OD

UC

TS

.IF

FR

OM

BA

CT

ER

IAL

DE

GR

AD

AT

ION

, P

RE

TR

EA

T W

ITH

B

AC

TE

RIC

IDE

.

DENSITY

PV

YIELD

GELS

FILTRATE

pH/Pf

SOLIDS

IONS

OTHER

+ +

-/-

+ +

VIS

CO

SIT

Y I

NC

RE

AS

E

(DE

SIT

Y IN

CR

EA

SE

FO

R

UN

WE

IGH

TE

D F

LUID

S)

VIS

CO

SIT

Y I

NC

RE

AS

E

(DE

SIT

Y IN

CR

EA

SE

FO

R

UN

WE

IGH

TE

D F

LUID

S)

+=

=/ +

+

+=

/ + +

+ +

-M

BT

INE

RT

SO

LID

S

CLA

Y G

RO

UN

DS

SO

LID

S-R

EM

OV

AL

EQ

UIP

ME

NT

, DIL

UT

ION

AN

S/O

R IN

HIB

TIO

N

NO

T A

DE

QU

AT

E T

O P

EN

TR

AT

ION

RA

TE

S, R

EM

ED

IAL

AC

TIO

NS

a)

AD

EQ

UA

TE

AB

OV

E P

AR

AM

ET

ER

S; b

) U

SE

A

SO

LID

S-T

OLE

RA

NT

FLU

ID;

c) R

ED

UC

E P

EN

ET

RA

TIO

N R

AT

ES

.

SO

LID

S-R

EM

OV

AL

EQ

UIP

ME

NT

, DIL

UT

ION

AN

D/O

R

INH

IBIT

ION

NO

T A

DE

QU

AT

E T

O F

RO

MA

TIO

N O

R

PE

NE

TR

AT

ION

RA

TE

S.

RE

ME

DIA

L A

CT

ION

: A

S P

ER

S

OLI

DS

-CO

NT

RO

L, M

OR

EO

VE

IT IS

IMP

OR

TA

NT

TO

PR

OV

IDE

O

R A

DE

QU

AT

E F

LUID

INH

IBIT

ION

.

ARPO




4.1.3 Chemical Treatment of Contaminents

Contaminants Contaminant Ion Corrective Scavengers Quantitative (kg/M 3)To Remove 1gr/L

Of Contaminant Ion

Gypsum OrAnhydrite

Calcium (Ca++) • Soda Ash (Na2CO3)

• SAPP (Na2H2P207)

• Sodium Bicarbonate(Na2CO3)

2.64

2.77

2.09

Cement /Lime Calcium (Ca++) +Hydroxil (OH-)

• SAPP

• Sodium Bicarbonate

2.77

2.09

Hard Water Magnesium (Mg++)

Calcium (Ca++)

• A) NaOH and increase Ph To10.5

• B) Soda Ash

3.3

2.65

H2S S-- Maintain Ph Above 10.5

• Zinc Oxide (Zn0)

• Zinc Carbonate (ZnCO3)

• Chelate Zinc

• Ironite Sponge (Fe304)

Refer to indicationgiven for eachproduct.

Carbon Dioxide(CO2)

Carbonates (CO3--)

Bicarbonates (HCO3-)

• Gypsum (CaSO4)

• Lime (CaOH2)

• Lime

2.85

1.23

1.21

ARPO




4.1.4 H2S Scavengers

ProductDescription

AVA Bariod Dowell MI BH Inteq

Fe based H2SScavenger

Ironite Sponge

1.35gr/1grH2S

Pre-treatment30kg/m3

Ironite Sponge

1.35gr/1grH2S


Ironite Sponge

1.35gr/1grH2S


Ironite Sponge

1.35gr/1grH2S


Ironite Sponge

1.35gr/1grH2S


Zinc Carbonate Zinc Carbonate

5gr/1grH2S

Pre-treatment5-8kg/m3

Zinc Carbonate

5gr/1grH2S


Zinc Carbonate

4gr/1grH2S


Zinc Carbonate

5gr/1grH2S


Mil-Gard

6gr/1grH2S


*Zinc Chelate(liquid)

Coat-RD

20gr/1grH2S


IDZAC L

13gr/1grH2S


SV-120

13gr/1grH2S


*Zinc Chelate(powder)

IDZAC L

8gr/1grH2S


Fer-Ox Milgard R

19gr/1grH2S


Zinc Oxide(Polvere)

Oxide Zinc

2.3gr/1grH2S


Sulf-X

2.3gr/1grH2S


Zinc Mixture No-Sulf


Oil DispersantScavenger

SOS 200

14gr/1grH2S


Note: 1ppm = 1mgr/1,000gr: 1gr/1,000kg. etc.

Treatment is referred to H 2S determined in drilling fluid (not to ppm butto detector).

* for non-viscofied fluids.

ARPO




4.1.5 Poylmer Structures/Relationship

STARCH

GUAR GUM

BIOPOLYMERS

CMC HV

HEC

PAC REGULAR

PHPA

POLYACRYLATES

VAMA

SSMA

CMC LV

PAC LOVIS

PHPA LMW

TYPEOF

POLYMER

RACCOMENDEDTREATMENT

Kg/m 3

LIMITATIONS

NOTES

P

P

S

P

S

S

S

P

P

P

P

P

P

P

S

S

P

S

P

P

P

P

10-20

10

1.5-6

1.5-6

3-4

1.5-6

0.7-4.5

0.7-6

0.14-0.9

3-9

1.5-6

1.0-6

0.6-4.5

TEMP. MAX 12O °C ,+ BATTERICIDA

TEMP MAX 100 °C + BATTERICIDA

pH< 10.5

Ca++ < 1200 ppm

TEMP.. MAX 95 °C

Ca++ < 2000 ppm

Ca++< 400 ppm

Ca++ < 400 ppm

Ca++ < 400 ppm

DEFLOCCULANT FOR T. UP 260 °C

Ca++ < 1200 ppm

Ca++ < 2000 ppm

Ca++ < 400 ppm

FUNZIONI

EX

TE

ND

ER

FLO

CC

ULA

NT

I

VIS

CO

SIZ

ZA

NTI

RID

. FIL

TRA

TO

DE

FLO

CC

ULA

N.

POLYMERS: STRUCTURE/FUNCTION RELATIONSHIP

FUNCTION MAIN CHARACTERISTICS

VISCOSITY

VISCOSITY AND THIXOTROPY

VISCOSITY IN BRINE SOLUTIONS

DEFLOCCULANT, DISPERSER,

FLOCCULANT

SURFANCTANT

FILTRATE REDUCER

HIGH MOLECULAR WEIGHT

HIGH MOLECULAR WEIGHT AND MIXED STRUCTURE OR CROSS-LINKING

HIGH MOLECULAR WEIGHT, NON IONIC OR ANIONIC, CAN BE EASILY REPLACED

LOW MOLECULAR WEIGHT WITH ALCALINEpH, NEGATIVE CHARGE

HIGH MOLECULAR WEIGHT WITH IONIC CHARGES ABSORBABLE FROM SHALES

LYOPHIL OR HYDROPHIL GROUP IN THE SAME MOLECULE

COLLOIDAL PARTICLE FORMATION AND/OR SOLIDS BRIDGING ACTION

P P

ARPO




4.2 OIL BASED FLUIDS MAINTENANCE

4.2.1 Analysing Flow Chart For Oil Based Fluid Reports

The stability of oil based fluid characteristics does not allow the same evaluation ofcontaminants carried out on water based fluids.

Problems are dealt with through a comparison of the characteristics by recording changeson a consumption basis, as for example:

dry and fragile cuttings, salinity fall and/or excessive additions of CaCl2 to maintainsalinity, water content increase and/or additions of oils and emulsifiers to maintain W/Oratio at correct levels which may indicate an excessive salinity.

However, evaluation is simplified by the limited amount of problems encountered.

VARIATION OF CHARACTERISTICS

MAINTENANCE PROBLEMS

NOTES ON SOLIDS TREATMENTS

WELL PROBLEMS

ADDITIVES USED TO MAINTAIN

CHARACTERISTICS

ARPO




4.2.2 Maintenance Problems

Effect On Fluid Problems Cause Remedial Actions

• Dull, grainy appearanceof fluid.

• High HP/HT filtrate fluidwith water.

• Barite settling

• Blinding of shakerscreens.

• Extreme cases cancause water wetting ofsolids.

Low emulsionstability

1) Low emulsifiercontent.

2) Super-saturated withCaCl2.

3) Water flows.

4) Fluid from mud plantor wrong make up.

1) Add emulsifier with lime.

2) Dilute with fresh water ifneeded. Add secondaryemulsifier.

3) Add emulsifiers and limeif needed recover o/wratio.

4) Maximise agitation.Check electrolytescontent, the higher thecontents, the harder theemulsifier is to form

• Flocculation of bariteon sand-content test.

• Sticky cuttings on theshaker screens.

• Blinding of the shakerscreens.

• Barite settling.

• Dull, grainy appearanceof fluid.

• Low electrical stability.

• Free water in HP/HTfiltrate.

Water wetting ofsolids.

1) Inadequateemulsifiers.

2) Water-base fluidcontamination.

3) Super-saturated withCaCl2.

1) Add secondary emulsifierfor water wetting ofsolids or wetting agents.

2) As indicated in point 1.

3) Dilute with fresh waterand add secondaryemulsifier.

• High HP/HT filtrate withwater.

• Low ES. Fill on bottom-hole.

• Sloughing shale.

High filtrate 1) Low emulsifiercontent.

2) Low concentration offiltrate reducer.

3) High bottom holetemperature

1) Add emulsifier and lime.

2) Add adequate filtratereducer.

3) Increase concentration ofemulsifier if a relaxedfiltrate system, convert toa conventional system.

ARPO





• High PV, high yp,increase of solidsand/or water.

High viscosity 1) High solid percentage 2) Water contamination3) Overtreatment with

emulsifiers, especiallyprimary emulsifier.

1) Dilute with oil; optimisesolids-removalequipment; addemulsifiers.

2) Add emulsifiers.3) Dilute with oil.

• Fill at drill pipe changeand after tripping;torque and drag

• Increase of cuttingsover shakers

SloughingShales

1) Drilling underbalance.2) Excessive filtrate. 3) Activity too low. 4) Inadequate hole

cleaning.

1) Increase fluid weight.2) Increase emulsifier

content, add filtratereducers.

3) Increase CaCl2 contentsto match formationactivity.

4) Add viscosifiers.

• Low YP and gels, baritesettling in theviscometer cup.

Barite settling 1) Poor oil wetting ofbarite.

2) Too low gels.

1) Add secondary emulsifierand/or wetting agent;slow addition of barite.

2) Add most adequateviscosifier.

• Pit volume decrease.• Return losses.

Lost Circulation 1) Hydrostatic pressureis more thanformation pressure.

1) Add mica or granulars.Never add fibrous orsynthetic materials (i.e.Nylon).

• Problem of mixing fluid. Low settling ofbarite.Very thin fluidwith no yield orgels.Dull, grainy fluid.

1) Inadequate shear.2) Very cold.3) Poor wetting of barite. 4) CaCI2 >350,000 ppm.

1) Maximise shear.2) Lengthen mixing time.3) Slow addition of barite. If

not sufficient increasepercentage of secondaryemulsifier.

1. Dilute with fresh water.Once emulsion isformed, adjust CaCl2 ifneeded.

ARPO





• Soft cuttings, blindingtendencies of shakerscreens. Decrease ofwater content.

Too low activitycan result in holeinstability.

1) Too low concentrationof CaCl2.

1) Allow concentration tobalance by itself if notsevere, report CaCl2 inpercentage. Reportwhere water migrationstops as the balancepoint. Recover thecorrect o/w ratio with theabove percentage.

• Dry and fragile cuttingsfall of salinity and/orexcessive additions ofCaCI2 to maintainsalinity, water contentincrease or severaladditions of oil to keepO/W ratio.

Too high activity.Embrittlement ofcuttings helpsthe build up offine solids.Formation canbe weakened.

1) Excessiveconcentration ofCaCI2.

1) Allow concentration tobalance by itself if notsevere, add oil andsurfactants until balancepoint has been reached.

ARPO




5. SOLIDS CONTROLThis section provides information relating to solids removal equipment aiding to theselection of choice and size of equipment required.

5.1 SOLIDS REMOVAL EQUIPMENT SPECIFICATIONS

Hole Diameter Max. ROP Feed Rate Of Fluid To BeProcessed

Drilled Solids Of Fluid ToBe Processed

26" +/- 30m/hr +/- 4500ltr/min 25-40t/hr171/2" +/- 30m/hr +/- 3800ltr/min 12-30t/hr121/4" +/- 30m/hr +/- 3000ltr/min 5-12t/hr81/2” +/- 15m/hr +/- 1500ltr/min 0.5-1t/hr

5.2 STATISTICAL DISTRIBUTION OF SOLIDS

Figure 5.A - Statistical Distribution Of Solids

5.3 EQUIPMENT PERFORMANCE

Centrifuge D-Silter D-Sander Shale Shaker

Feature BariteRecoveryCentrifuge

HighVolume

HighSpeed

ConeSize

Feed Rate(per unit

l/min)

ConeSize

Feed Rate(per unit

l/min)

ScreenMesh

CutPoint

Microns

ProcessedVolume(l/min)

Usage BariteRecovery,

LGSRemoval

LargeVolumes

LiquidPhase

Recovery

2”

4”

60-80

180-340

5”6”8”10”

3003705001900

20 x 2030 x 3030 x 4040 x 36

465541381300

3800360034003000

G’ 500-700 +/- 800 2100-3000 12” 1900 50 x 5060 x 6080 x 60

279234178

280026502300

Cut PointMicrons

6-10 perLGS, 4-7 per

HGS

5-7 2-5 100x100120x120150x150

140117104

1500950750

FeedRates l/min

40-80 380-750 150-300 200x200 74 450

RPM 1600-1800 1900-2200 2500-3300

0%

20

40

60

80

100

Total solids Drill solids Barite

CENTRIFUGE

CYCLONES

SHALE SHAKERS

Solids Size (Micron)

0 25 50 75 100 125 150 175 200 225 250 275

% Solids

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5.4 EQUIPMENT RECOMENDATIONS

STANDARD SHALE SHAKERS

PREMIUM SHALE SHAKERS

D-GASER

D-SANDER

MUD CLEANER

CENTRIFUGES:

-BARITE RECOVERY

- HIGH VOLUME

- HIGH SPEED

LOW

GR

AV

ITY

W

ATE

R-B

AS

E F

LUID

S(<

1.3

s.g

.)

HIG

H D

EN

SIT

Y

WAT

ER

-BA

SE

MU

D(>

1,3

)

PO

LYM

ER

FLU

IDS

PO

LYM

ER

-BA

SE

F

LUID

S W

ITH

IN

HIB

ITIV

E S

ALT

S

LOW

DE

NS

ITY

OIL

-BA

SE

FLU

IDS

HIG

H D

EN

SIT

YO

IL-B

AS

E F

LUID

S

SOLIDS-REMOVAL

RECOMMENDED EQUIPMENT PER FLUID TYPE

x

(x)

x

x

(x)

x

x

x

x

x

x

(x)

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

x

D-SILTER x

(*) * * * * *

SCALPING SHALE SHEKERS* NOT OBLIGATORY( )

D-GASER D-SANDER D-SILTER(MUD CLEANER)

CENTRIFUGE/S

SOLIDS-REMOVAL EQUIPMENT

x

SCALPING SHALE

SHAKERS

HIGH PERFORMANCE SHALE SHAKERS

(PREMIUM)

FROM WELL

ALTERNATIVEMAIN

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5.4.1 Double Shale Sh akers

Figure 5.B - No Backflow Plated ShaleShaker

Description:

Two-layer screen shale shaker with a courseupper screen and a fine lower screen.

Advantages:

Simple and economical to use and maintaincoarse screen removes most of the cuttings,thus limiting the wearing out of the finescreens.

Limitations:

Fluid losses from the lower screen. Wetcuttings due to the short stay on screens.

Recommended for:

• Marginal well plants, with low cost waterbase fluids and lower costs of wastedischarge.

• Same as scalping shale shaker used insingle deck, high performanceconfigurations.

Figure 5.C - Backflow Plated Shale Shaker

Description:

Two-layer screen shale shaker with aninclined plate located between them whichallows fluid to flow back to the beginning ofthe fine lower screen.

Advantages:

Same as the no-backflow plated shale shakerwith better use of the lower finer screen.Cuttings removed by the fine lower screenare drier than those of the no-backflow platedshale shaker system. Fairly goodperformance with reduced sizes

Limitations:

Replacement of the lower screens may bedifficult. Cuttings are not as dry of a singledeck shale shaker integrated with a scalpingshale shaker.

Recommended for:

• As a primary shale shaker, especiallyfor water based fluids and non-cascading plants (scalping, single deck,premium shale shaker).

COARSE SCREEN

FINE SCREEN

COARSE SCREEN

FINE SCREEN

BACKFLOW PLATE

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5.4.2 Single Deck Shale Shakers

Figure 5.D - Multiple Screens

Description:

Single deck, linear shaker with two morescreens of different weave placedsequentially from the finer to the coarser. Thescreens can be positioned forwards orbackwards.

Advantages:

Efficient and especially reliable with cuttingsfrom hard formations or oil based fluids. Ifused properly, cuttings discarded are dry.

Limitations:

All cuttings are processed by the fine screenwhich wears out more often, especially ifcuttings are plastic (drilled clays with waterbased fluid). This problem can be solved byusing a another shale shaker placed in frontin sequence acting as a scalping shaleshaker.

Recommended for:

• Use as a primary shale shaker for oilbased fluids.

• With the use of very fine screens theirefficiency can be exploited by using abank of shale shakers sufficient for thecapacity required. This processes thevolume of fluid an efficient cost.

Figure 5.E - Underflow Screens

Description:

Single deck, single screen with the initialsection completely underflowed by fluid.

Screen vibration allows cuttings to overflowup the final inclined section.

Advantages:

Designed to obtain very dry cuttings. 8-30sized screens are installed when it is used asa scalping shaker.

Limitations:

Is solely a speciality shale shaker to reduceresidual oil, from cuttings.

If used with water based fluids and plasticformations, the screens can be easilyplugged.

Recommended for:

• Exclusive use with oil based fluids andwhen cutting discharge is allowed withan oil residue percentage which can beachievable.

FINE SCREENCOARSE SCREEN

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5.5 SCREEN SPECIFICATION

Type Of Screen Mesh Per Inch Wire Diameter(ins)

Mesh Opening(Microns)

Flow Area(%)

Square Mesh Screens

S10 10 X 10 0.025 1905 X1905 56.3S20 20 X 20 0.017 838 X838 43.6S40 40 X 40 0.010 381 X 81 36.0S80 80 X 80 0.0055 178 X 78 31.4S120 120 X 120 0.0037 117 X 17 30.9S150 150 X 150 0.0026 105 X 5 37.9S200 200 X 200 0.0021 74 X 4 33.6

Rectangular Mesh S creens

B20 8 X 20 0.032/0.02 762 X 3362 45.7B40 20 X 30 0.015/0.015 465 X 89 39.1B60 20 X 40 0.014 310 X 910 36.8B80 20 X 60 0.013/0.009 190 X 1037 34.0B100 40 X 60 0.009 200 X 406 31.1B120 40 X 80 0.0075 457 X 140 35.6

5.5.1 Nomenclature

Derrick Nomenclature

Description Panel SWG 3 layered, derrick standard screens, non-repairable.

PWP 3 layered screens mounted on a rigid support, repairable withfitted plugs or silicon. The support takes up 35% of the flow area.

GBG 3 layered screens bonded to a non-rigid support, temporarilyrepairable. The support takes up 10% of the flow area.

Pyramid Corrugated screens on a rigid support gives approx. a 50%increase in flow area.

Screen DC Coarse mesh screens.

DF Fine mesh screens.

DX Extra fine mesh screens

HP High performance screens.

SCGR Rectangular mesh screens

Example: GBG HP 200 - Multiple, high performance screen mounted on a non-rigid support. 200indicates that the equivalent mesh size does not correspond exactly to mesh number.

Derrick Nomenclature

Description BLS 3 layered screens with plastic strips between the coarse screen and the others.

BXL 3 layered screens mounted on a plastic grid.

S Square meshed screens.

B Rectangular meshed screens.

Example: The letter designation is followed by a number which, as in ‘BLS’, ‘BXL’ and ‘S’ screens,indicates the mesh number. For ‘B’ designation, it is the sum of the mesh in both directions.

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5.6 CYCLONE SYSTEMS

Figure 5.F - Typical Viscosity/Cyclone Performance (4”)

Equipment Treatment CapacityRequired

Weight Diff erenceEntrance/Discharge

Feed Pressure Volume DischargedFrom Equipment

Desander 1.25 (Max. Perf. Q) 0.3-0.6kg/l 30-45psi +/- 1.5m3/hDesilter 1.5 (Max. Perf Q) 0.3-0.4kg/l 30-45psi +/- 3.5m3hMud-Cleaner 1.5 (Max. Perf. Q) 0.3-0.4kg/l 30-45psi +/- 1m3/h

Figure 5.G - Calibration Of Water Discharge Cyclones

Figure 5.H - Typical Cyclone Malfunctions

VISCOSITY/CYCLOPE PERFORMANCE (4")

0 10 20 30 40 50 60 70 80 900

20

40

60

80

100

SOLIDS SIZE (MICRON)

EF

FIC

IEN

CY

GR

AD

E (

%) PV 6 cps, YP 1 gr/100cm2

PV 25 cps, YP 5 gr/100cm2

EXCESSIVE OPENING

SPRAY DISCHARGE

PROPER FUNCTIONING EXCESSIVE CLOSING

DROP DISCHARGE

NO DISCHARGE

PROPER FUNCTIONING

AIR CONE

SPRAY DISCHARGE

'A'

'B'

'C'

WASHING AWAY-CONE HOLED IN "A"- PARTIALLY PLUGGED CONE IN "B"- TOO HIGH IN "C".

FLOOD- CONE OR COLLECTOR PLUGGED IN "B".

DRY DISCHARGE- HIGH SOLIDS PERCENTAGE- CLOSED DISCHARGE.

'B'

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5.7 CENTRIFUGE SYSTEMS

Figure 5.I - Centrifuge Operating Principle

5.7.1 PrInciple Of Operation

a) Fluid to be processed is delivered to the centrifuge through the feed pipe.

b) The rotating bowl creates a very high centrifugal force which increases thegravitational separation effects of the of fluids and solids.

c) The solids being heavier gather on the drum walls and when build up aremoved by the scroll to the solids discharge port.

d) The liquids move through the unit to the liquid discharge port nozzles.

The liquids decanting effect and solids dehydration depends on the following:

• ‘g’ centrifugal force.• Settling time of the solids on the drum.

Increasing Feed Rate/H ‘G’ Micron Solids Solids Fluid %

Feed Capacity + = + +

RPM = + - -

RPM Difference BetweenRotor/Scroll

= = = +

Height Of Underflow Ports = = + +

Table 5.A- Effects Of Variables

DECANTATION OF SOLIDS

(POND)

DEHYDRATION OF SOLIDS

(BEACH)

LIQUID DISCHARGE SOLIDS DISCHARGE

FEED PIPE

ROTATING BOWL SCROLL

OVERFLOW PORTS SOLIDS DISCHARGE

FLUID FEED

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5.7.2 Centrifuge Processing

Figure 5.J - Unweighted Fluid-Parallel Processing

Figure 5.K - Weighted Fluid-Sequential Processing

LGS DISCHARGE

PROCESSED FLUID

FLUID TO BE PROCESSED

LGS DISCHARGE

LGS DISCHARGE

BARITE RECOVERY

FLUID TO BE PROCESSED

PROCESSED FLUID

LOW "G" HIGH "G"

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6. TROUBLESHOOTING GUIDE

This section is a troubleshooting guide which addresses loss of circulation, describingremedial actions to be taken for the various types of losses and includes someinformation on the use of LCM and the appropriate procedures.

ARPO




6.1 LOST CIRCULATION CONTROL TECHNIQUES

Figure 6.A - Lost Circulation Control Flow Chart

ALM

OS

T TO

TAL

mor

e th

an 5

0%

SP

OT

PIL

LS

WIT

H L

CM

HIG

H

FIL

TR

AT

ION

M

IXT

UR

E

GE

L C

EM

EN

T

DO

BC

AE

RE

TE

D F

LUID

S

ST

IFF

-FO

AM

SE

EP

AGE

LO

SS

less

than

50%

SU

RFA

CE

AR

EAS

HIG

HLY

P

ER

ME

ABLE

FRA

CTU

RE

S

HIG

H V

ISC

OS

ITY

F

LUID

AN

D H

IGH

G

ELS

HIG

H V

ISC

OS

ITY

F

LUID

- LC

M IN

CIR

CU

LAT

ION

- H

IGH

FIL

TR

AT

ION

FLU

ID

SP

OT

PIL

L W

ITH

LC

M

HIG

H/V

ER

Y H

IGH

FIL

TR

AT

ION

M

IXT

UR

E

TOTA

L

FRA

CTU

RE

S

HIG

H

FIL

TR

AT

ION

M

IXT

UR

E

CE

ME

NT

/GE

L C

EM

EN

T

SLU

RR

IES

DO

BC

CAV

ER

NS

GE

L-C

EM

EN

T

SLU

RR

IES

CE

ME

NT

+

GE

LSO

NIT

E

DO

BC

HY

DR

AU

LIC

ALL

Y-I

ND

UC

ED

FR

AC

TUR

ES

LOW

DE

NS

ITY

FL

UID

S

SE

T T

IME

LO

W

LOA

DIN

G

HIG

H

FIL

TR

AT

ION

M

IXT

UR

E

DO

B

DO

BC

AE

RE

TE

D F

LUID

S

ST

IFF

-FO

AM

HIG

H D

EN

SIT

Y

FLU

IDS

FLU

ID T

HIN

NIN

G

AN

D/O

R

UN

WE

IGH

TIN

G

HIG

H F

ILT

RA

TIO

N

MIX

TU

RE

FRA

CTU

RE

S

AE

RE

TE

D F

LUID

S

ST

IFF

-FO

AM

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6.2 LOSSES IN VARIOUS FORMATION TYPES

Loss Determination In Various Fo rmat ion Types

Unconsolidated Fo rmat ions Sands, gravel beds, etc. Gradual increase in loss which maydevelop and increase with penetration.

If permeability is less than 4/5 darcy, theloss is maybe due to formation fracture.

Natural Fractures Every type of elastic rock. Gradual increase in losses which maydevelop and increase with penetration

Cavernous Or M acrov ugularFormat ions

Limestones, dolomites,reef, volcanic rocks.

Sudden and severe, to complete loss, ofreturns.

The bit may fall from a few centimetres tosome metres at the moment of loss.Perforations may be 'disturbed' before thelosses.

Induced F ractures May occur to all formations.

It is likely to occur topreferred plans of fractures.

Sudden and sever to complete losses.

Fluids with density more than 1.3 SG mayhelp create fractures.

Fracture may occur during, orsubsequent, to rough drilling.

If it occurs in one single well and does notoccur to the nearby wells, fracture may bethe cause

6.3 CHOICE OF LCM SPOT PILLS

Figure 6.B - LCM Spot Pill Selection Chart

RESULTS

GOOD NO GOOD NONE

MACROFRACTURES/CARSIMS FRACTURES GRAVEL SAND PORES

CEMENT

"PLASTIC" PLUGS

PERLITE

GRANULAR

(COTTON) FLAKE

FIBROUS

CELLOPHANE

MICA

GOOD IF USED WITH...

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6.3.1 LCM Information

Materials Type Granulometry(mm)

SeepageLoss

PartialLoss

TotalLoss

Can BeAcidised

Can BeUsed In

OBM

CaCO3 Granular 50% @ +/- 0.05 X X X X

CaCO3 Granular 50% @ +/- 0.1 X X X

CaCO3 Granular 50% @ +/- 0.6 a3 X X X X

Fine Nuts Granular 0.16 - 0.5 X X

MediumNuts

Granular 0.5 - 1.6 X X

Coarse Nuts Granular 1.6 - 5 X X X

Fine Mica Lamellar 2 - 3 X X X

Coarse Mica Lamellar 4 - 6 X X X X

VegetalFibres

Fibrous 5 - 15 X X

Cellophane Lamellar 10 - 20 X X

6.3.2 LCM Efficiency

Figure 6.C - Fracture Dependent Efficiency Of LCM

0 1 2 3 4 5 60

10

20

30

40

50

60

0

10

20

30

40

50

60

FRACTURE WIDTH (mm)

Kg/

m3

OF

LC

M

FIBROUS LAMELLAR GRANULAR

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6.4 TROUBLESHOOTING GUIDE

6.4.1 Loss Of Circulation With Water Based Fluids

Treatment Formulation Operat ional Remarks

Stand-By/Set Time Allow 4-8 hours set time. Planfurther action to be taken.

High Viscosity Fluids Add contaminants (lime, salt,etc.) to circulating fluids (lime,salt, etc.) by increasing viscosityand filtrate.

Viscosity at +/- 100sec.

LCM In Circulation Approximately:

• Fine mica 2%• Fine granulars 2%

Shale shakers max., 10-12 mesh.

High Filtration Fluids • Bentonite 5%• Caustic Soda/Lime 10%• Diatomite 10%• Filtrate 30-50 cc

Do not use with unstableformations.

Spot Pills With LCM Volume, from 15 to 80 m3 of highfiltration fluid conditioned with 6-8% of LCM adequate for loss.

Displace loss zone if there isexcessive solids loading in theannulus. Squeeze slowly with a lowpressure (50psi). Displace bymeans of bit with no nozzle or withnozzles >14/32".

High Filtration Mixtures

(200-400cc API)

• Attapulgite 3-6%• (bentonite 1.5-6%)• Lime 0.15%• Diatomite 15%• *Mica 1-1.5%• *Granular 1-2.5%• *Fibrous 0.3-1%*(chosen dependent on loss).

RIH or EDP on top loss, squeezewith low pressure (starting with +/-50psi @ 150ltr/min). Do not exceedfracture pressure and maintain for6-8hrs.

Very High Filtration Slurries(>600cc API)

• Diatomite 30%• Lime 15%• Attapulgite 0-4%• *Granular 1-2.5%• *Fibrous 1%• *Lamellar 1%*(chosen dependent on loss)

Same application procedure ashigh filtration slurries withtemperature >60oC. It may developmechanical resistance.

ARPO





Diaseal M ( Filtrate > 1000ccAPI)

Formulation for the prep arat ion of1m3 final Diaseal M

Density Diaseal Barite Waterkg/l sacks t m3

1.08 6 0 0.91.45 5 0.2 0.81.80 4 1.0 0.72.15 3 1.5 0.6

Same application procedure ashigh filtration slurries.

GEL Cement (PrehydratedBentonite)

Formula for preparing slurries ('G'cement)

Bent Water Slurry Densit yYield

% weight% l/100kg kg/l0 44 75.7 1.92 84 116.5 1.63 104 136.9 1.514 112 157.25 1.45

A higher slurry must beprepared. The percentagesindicated, provide mechanicalresistance. Formation of slurrieswith higher percentages ofBentonite may improve LCMcharacteristics while decreasingmechanical resistance

Cement Gilsonite Formulation for preparing slurries('G' cement)

Bent Water Slurry Densit yYield

% weight% l/100kg kg/l0 44 75.7 1.950 61 139.5 1.51

100 78 203.9 1.37200 112 330.25 1.25

Good mechanical resistanceassociated with material controlaction of gilsonite. As forcement plugs, it is advisable todrill the loss zone and carry outthe remedial procedure whenfinished.WOC for at least 8hrs.

DOBC Squeeze (Diesel OilBentonite)

Materials required for final vol. 1m3

• Diesel 0.72m3

• Cement 450kg• Bentonite 450kg

Apply DOBC/DOB squeezeprocedure. RIH or EDP on topof loss zone. Plastic plugvolume to equal, or be greaterthan, the hole below the losszone first and second plug, bothabout 1m3 diesel.

DOB Squeeze Materials required for final vol.1m3

• Diesel 0.70m3

• Bentonite 800kg

When plug exits drill string,close annular preventer andpump fluids into annulus whiledisplacing the plug from the DP.Drillpipe/ annulus ratio is 2:1,about 600 l/min from drillpie and300 l/min from annulus. Afterdisplacing half the plug, reducepump rate by half. Afterdisplacing 3/4 of the plug,attempt a 'hesitation squeezepressure' with 100-500psi.Underdisplace plug by onebarrel, POOH, allow 8-10hrs settime.

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6.4.2 Loss Of Circulation With Oil Based Fluids


Additions Of Colloid Reduce HP/HT filtrate withasphalt filtration control additives.Add CaCO3 to +/- 5-15 microns.

Seepage loss is commonly due tolow colloid contents of oil based.

Spot Pills With LCM Volume, from 5 to 10m3, addedwith LCM adequate for the lossand compatibility with the oilbased fluid with a percentagevarying from 5 to 10%.

Displace loss zone if there isexcessive solids loading in theannulus, squeeze slowly with lowpressure (50psi). Displace bymeans of bit with no nozzles or withnozzles >14/32".

Diaseal M ( Filtrate > 1000 ccAPI)

Formulation for preparing finalvol. 1m 3 of Diaseal M

Density Diaseal Barite Wate rkg/l sacks t m3

1.08 5 0.2 0.91.45 4 0.7 0.81.80 3 1.1 0.72.15 2 1.6 0.6

Spot pill volume is double the holevolume and at least 1.5m3. Toavoid contamination 3-4m3,separating pills are advisable afterand before.Final pressure should be equivalentto the max. density.If the pill viscosity is too high, addwetting agent.LCM may be added.

Plastic Plug WithOrganophil Clay

Formulation for preparing finalvol. 1m 3

Density 1.2 1.45 2.15(kg/l)Water 0.67 0.72 0.54 (m3)FCL 9 7 7 (kg)NaOH 4 4 4Org.clay 550 712 285 (kg)Barite 1540 (kg)

Spot pill volume should be doublethe hole volume or at least 1.5m3.To avoid contamination, 3-4m3,separating pills in front and behindare advisable.Final pressure should be equivalentto the max. density.If the pill viscosity is too high, add awetting agent.LCM may be added.

ARPO





Fresh Water Barite Plug Formulation for preparing 1m3

Density 2.16 2.4 2.64(kg/l)Water 0.64 0.57 0.5 (m3)SAPP 2 2 2 (kg)NaOH 0.7 0.7 0.7 (kg)*(FCL) (6) (6) (6)*(NaOH)(1.4) (1.4) (1.4)Barite 1530 1850 2155

* as alternative to SAPP andSoda.

• Determine the height of theplug, commonly 130-150m issufficient.

• Choose the desired density, thelower the density, the faster thesetting time.

• Calculate the plug volume byadding 10 barrels.

• Calculate the amount ofmaterials required.

• Evaluate displacement• Mix with cement unit.• Use bit with nozzles.• Under displace leaving two

barrels.• Pull out above plug and

Circulate as long as you can, inorder to allow plug to settle.

Note:• The use of fresh water is

advisable, as sea water doesnot allow a proper settling.

• Maintain mix water pH at 8-10.

• For preparing a pumpable fluid,follow the indications hereingiven using galena.

Oil Based Fluid Barite Plug Formulation for preparing 1m 3

Density 2.4 2.64 kg/lOil 0.51 0.49 (m3)EZ MUL 20 17 (kg)Water 27 26 (L)Barite 1930 2530 (kg)

Water Based Fluid WithGalena

Formulation for preparing 1m3

Density 2.88 3.36 3.84 kg/lWater 0.58 0.51 0.51 (m3)Bent 23 8 5 (kg)Na2CO3 4 5 5.7 (kg)SAPP 2 2 5.7 (kg)Galena 1325 1995 3320 (kg)Barite 955 838 ....... (kg)

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Oil Based Fluid With Galena Formulation for preparing 1m 3

Base Fluid (In vermul)Oil 0.85 (m3)Water 0.15 (m3)Driltreat 35 (kg)Suspentone 52 (kg)Gelitone II 10 (kg)Duratone HT 35 (kg)

Formulation for preparing 1m3Density 3.36 3.6 4.32 kg/lBase 0.59 0.55 0.43 (m3)FluidDriltreat --- --- 14 (kg)

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7. STUCK PIPE TREATMENT/PREVENTITIVE ACTIONS

This section gives recommendations on preventive measures to avoid stuck pipe inaddition to appropriate treatments to solve the problem.

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7.1 STUCK PIPE TREATMENT/PREVENTION

STUCK PIPEC

IRC

OLA

TIO

N

RO

TAT

ING

DO

WN

IN H

OLE

OU

T O

F H

OLE

FREE DRILLSTRING

STUCKPIPE TYPE

PARAMETERS

TREATMENT/PREVENTIVE ACTIONSCAUSE

TREATMENT

- WORK DRILL STRING UP AND DOWN

CLAY-BASE WATER FLUIDS:

- DENSITY UP TO 1.35 Kg/l, USE DIESEL OR LT OIL CONDITIONED WITH SURFANCTANT (PIPELAX, OR PRESANTIL ETC..);- DENSITY MORE THAN 1.35 Kg/l, PREPARE A SPOT PILL WITH WEIGHTED OIL (EZ-SPOT, PRESANTIL W, ORGANOPHIL CLAY PILLS, ETC...);

POLYMER-BASE FLUIDS:

- IN ORDER TO DISGRAGATE THE CAKE, USE SOLUTIONS OF CaCl2 AND/OR NaOH (pH>12);

- MECHANICAL RELATED TREATMENT.IF POSSIBLE, LOWER THE FLUID GRADIENT BY UNWEIGHTING THE FLUID OR DECREASING THE HYDROSTATIC LOAD BY MEANS OF UNWEIGHET PILLS OR OPEN HOLE PACKER AND A VALVE TESTER.

OIL-BASE FLUIDS:

DIFFRENTIAL PRESSURE

YES NO NO NO - HIGHLY PERMEABLE FORMATIONS- EXCESSIVE CAKE- DRILL STRING JAMMED- DEPLETED LEVELS.

PREVENTIVE ACTIONS:

- MINIMIZE THE FLUID WEIGHT AT THE LOWEST VALUE ALLOWED;- REDUCED SURFACE CONTACT BETWEEN DRILLPIPE AND FORMATION (SPIRAL DC, HIGHLY STABILIZED DRILL STRING ASSEMBLY, etc.);- MAINTAIN THE CAKE THICKNESS BY ADEQUATE FILTRATE AND SOLIDS PERCENTAGE.

N.B.REDUCED STUCKPIPE BROBLEMS WITH: OIL-BASE FLUIDS, BUT INCREASED TREATMENT DIFFICULTIES IN DISGREGATING CAKE.

EZ SPOT FORMULATION FOR PREPARING 1 m3

DENSITY Kg/l

EZ SPOTGASOLIOACQUABARITE

0,9 1,2

80580260396

1,44

80540220710

1,68

80490210995

1,92

805101101310

2,16

804401001620

80650270--

ORGANOPHIL CLAY PILLS FOR PREPARING 1 m3

DENSITY Kg/l

DIESELORGANOPHIL CLAYBARITESURFANCTANT (i.e. PRESANTIL)

1,4

7907064030

1,5

7705078030

1,6

7404590030

OPERATIONAL REMARKS

MINIMUM VOLUME= 2.3 TIME DC-HOLE VOLUME (Vi)

DISPLACEMENT PROCEDURE:

- DISPLACE 1ST SEPARATING PILL + 1.3 Vi;

- ALLOW 40-60 MINUTES SET TIME;

- DISPLACE 1/2 Vi.

- ALLOW 2-3 HOURS SET TIME.

- REPEAT TREATMENT IF NEEDED;

- MAX NUMBER OF TREATMENTS ALLOWED = 4 (STATISTICAL FIGURE).

IF NEEDED ADD 1% SURFANCTANT (i.e. PRESANTIL)

ARPO




STUCK PIPE

CIR

CO

LAT

ION

RO

TA

TIN

G

DO

WN

IN H

OLE

OU

T O

F H

OLE

FREE DRILL STRING

STUCK PIPE TYPE

PARAMETERS

TREATMENT/PREVENTIVE ACTIONSCAUSE

COLLAPSING DUE TO

ACCUMULATION OF CUTTINGS

NO NO NO - POOR HOLE CLEANING- LOADING/RHEOLOGY NOT ADEQUATE PENETRATION RATES:

- IT MAY OCCUR IN HIGH ANGLE HOLES (35-60 DEGREES).

COLLAPSING NO

NO

NO

NO - SHALE SWELLING;

- STRESSED BRITTLE SHALES;- UNSUFFICIENT FLUID WEIGHT;- FLUID AND/OR DRILL STRING MECHANICAL EFFECT.

PREVENTIVE ACTIONS- UTILIZE HIGH FEED RATES;

- MAINTAIN ADEQUATE RHEOLOGY, ESPECIALLY FOR HIGH ANGLE HOLES WHERE VISCOSITY SHOULD BE LOW ENOUGH AND SHARE SPEEDS SHOULD BE EQUIVALENT TO THE ANNULUS BY MAINTAING FAST/FLAT GELS IN ORDER TO LIMIT CUTTING SETTLING AT THE MOMENT OF CIRCULATION ARREST. BY MEANS OF EXAMPLE: LOW READINGS AT 100 RPM;HIGH READINGS AT 6 AND 3 RPM AND GELS AT 10".

- EVALUATE SOLIDS-REMOVAL GRADE IN ORDER TO DEFINE THE CORRECT VALUES OF READING. THEREFORE, ANALIZE SOLIDS RECOVERY ON THE SURFACE DEPENDENTKY ON HOLE VOLUME, BY CONSIDERING THE DIFFICULTIES ENCOUNTERED WHILE TRIPPING AS THE INDEX OF CUTTING QUANTITY INTO THE BOREHOLE.

- RE-ESTABLISH CIRCULATION WITH PRESSURE PEAKS AND DRILL STRING MOVEMENTS. CAUTION SHOULD BE EXERCISED TO AVOID FRACTURES TO THE FORMATION BELOW THE STUCK POINT;

- ONCE CIRCULATION IS RE-ESTABLISHED, PUMP VISCOUS PILLS BY WORKING DRILL STRING UP/DOWN;

- DOG LEGS CANNOT BE USED;

- IF CIRCULATION CANNOT BE RE-ESTABLISHED, THEN UTILIZE WASHING PIPES.

PREVENTIVE ACTIONS

- REDUCE FILTRATE;- ADD ASPHALT COATERS;- REDUCE TURBOLENT FLOW AGAINST WALLS;- EMPLOY FORMATION INHIBITION FLUIDS;- INCREASE INITIAL GELS WHILE DECREASING FINAL ONES;- SLOWLY INCREASE DENSITY. IF INSTABILITY IS NOT DUE TO OVERPRESSURE, THE BENEFICIAL EFFECT WILL BE TEMPORARY.

TREATMENTS AS A COLLAPSING

TREATMENT

ARPO




STUCK PIPE

CIR

CO

LAT

ION

RO

TA

TIN

G

DO

WN

IN H

OLE

OU

T O

F H

OLE

FREE DRILL STRING

STUCK PIPE TYPE

PARAMETERS

TREATMENT/PREVENTIVE ACTIONSCAUSES

KEY SEAT YES YES (YES) NO - INCLINATION VARIATIONS;- DEVIATED WELLS;- SLOW ROP.

DOG LEGGING

YES

YES NO NO - SUDDEN VARIATIONS OF

INCLINATION;

- TRIPPING DOWN IN HOLE WITH A MORE RIGID DRILL STRING.

UNDEGAGE HOLE

YES NO NO - UNDERGAGE DRILL STRINGNO

(YES) NO NO - TOO THICK CAKENO

(YES) NO NO - PLASTIC DEFORMATION OF SALINE FORMATIONS OR GUMBO SHALES.

NO

- WORK DRILL STRING UP AND DOWN;

- DISPLACE A PILL:A) FLUID CONDITIONED WITH 5-6% LUBRICANT OR 10-20% EXAUST OIL OR DIESEL.B) ACID PILL IF CARBONATE FORMATION.

PREVENTIVE ACTIONS- RE-RUN WITH KEY SEAT WIPER OR UNDERGAUGE STABILIZER ON THE TOP DC.

- RE-RUM DOWN IN HOLE WHERE THE KEY SEAT IS PRESUMABLY LOCATED;

- ADD LUBRICANTS TO THE FLUIDS.

TREATMENT- AS PER KEY SEATING

PREVENTIVE ACTIONS:- SLOWLY RUN IN HOLE AVOIDING WEIGHT LOSS OF DRILL STRING. RE-RUN IF NEEDED;

- ADD LUBRICANT TO THE FLUID.

PREVENTIVE ACTIONS:

TREATMENT

INTERVENTO- AS PER KEY SEATING

- WORK DRILL STRING UP/DOWN;- RE-ESTABLISH CIRCULATION- USE AN ANTI-STUCK PIPE PILL IN ORDER TO DESGREGATE THE CAKE, IN ADDITION TO LUBRICANTS.

PREVENTIVE ACTIONS- CONTROL CAKE THICKNESS AND QUALITY.

TREATMENT

- WORK DRILL STRING UP/DOWN;- RE-ESTABLISH CIRCULATION;- USE ANTI-STUCK PIPE PILL IN ORDER TO DISGREGATE THE CAKE, IN ADDITION TO LUBRICANT.

PREVENTIVE ACTIONS- MAINTAIN AN ADEQUATE FLUID WEIGHT.

TREATMENT

- CHECK STABILIZER BIT DIAMETER;

- RE-RUN THE DRILLING ZONE.

ARPO




8. DRILLING FLUID TRADEMARK COMPARISONS

Comparison of similar products and functional performances are compared in this section.This comparison evaluates the various products with the differing concentrations requiredagainst their relevant costs. Technical and/or economical analyses of all differing productsshould be carried out with the concentrations required in similar operational conditionsand results.

ARPO




8.1 DRILLING FLUID PRODUCT TRADEMARKS

Code Description AVA Bariod Dowell MI BH Inteq

8.1.1 Weighting Materials

0101 Barite Barite Baroid Barite M-I Bar Mil-Bar

0105 Siderite Baraweight Siderite

0107 CalciumCarbonate

AVACARB Baracarb Ca Carbonate Lo-Wate WO 30

0108 Ematite AVAEMATITE Barodense Id-Wate Fer-Ox Mil-Dense

8.1.2 Viscosifiers

0201 Bentonite AVAGEL Aquagel Bentonite M-I Gel Mil-Gel

0203 Attapulgite Dolsal B Zeogel Salt Gel Salt Gel Salt Water Gel

0204 Sepiolite Dolsal Geltemp Durogel

0413 HEC Natrasol 250 Baravis Idhec HEC WO 21

0415 Biopolymers

BiopolymersPUR

Visco XC 84 Barazan Idvis XC-Polymer

Flo-Vis

XC Polymer

0420 BentoniteExtender

AVABEX X-Tend II DV 68 Gelex Benex

0423 PHPA HMWeight

Polivis EZ-Mud Id-Bond Poly-Plus New Drill

8.1.3 Thinners

0501 Fe-CrLignosulfonate

AVAFLUIDG71

Q-Broxin FCL Spersene Uni-Cal

0502 ModifiedLignite

0503 Cr-Free Lignite AVAFLUID-NP Q-B II Chrome-FreeLS

Spersene CF Uni-Cal CF

0506 Caustic Lignite CC 16 Caustilig Ligcon

0507 Lignite AVATHIN Carbonox Tannathin Ligco

0508 PotassiumLignite

AVAK-LIG K-Lig K-17

0509 Cr Lignite AVALIG Chrome Lignite XP-20

0510 Phosphates AVASAPP Barafos STP Phos/SAPP STP

0511 Tannins AVARED Quebracho Quebracho

0512 Cr Tannins Desco Desco Desco Desco Desco

Cr-FreeTannins

Desco-CF Desco CF Desco CF

0424 PHPA LMW Polifluid Thermathin ID Thin 500 Tackle New-Thin

0513 HTDeflocculants

AVAZER-5000 Mil-Temp

Ca Modified LS Lignox Rheomate Aquathinz

ARPO





8.1.4 Filtrate Reducers

0401 Technic CMCHV/LV

CMC Cellex CMC CMC CMC

0403 Semipurif.CMC HV/LV

CMC-S CMC S CMC S

0405 Purified CMCHV/LV

CMC-P CMC P CMC P Driscose

0407 K-CMC LV/HV Agipak

K-PAC R/LV Agipak

0409 Purified PACR/LV

Visco 83 PAC IDF-FLR Polypac Drispac

0411 Semi PurifiedPAC R/LV

Policell Barpol IDPAC Milpac

0416 NaPolyacrylates

Policell ACR Polyac Polytemp SP 101 New-Trol

0418 Pregelat.Starches

Victogel AF Impermex IDFLO LT MY-LO-Gel

Flo-Trol

Milstarch

0417 Non-Ferm.Starches

Victosal Dextrid IDFLO Polysal Permalose HT

0419 HT Starches AVATEMP IDFLO HTR Thermpac UL

Burastar

0421 HT PolysterMixture

AVAREX Baranex IDF HI-Temp Resinex Filtrex

8.1.5 Lubricants

0301 Envir. FriendlyLubricant.

Ecolube Tork Trim II

Stick Less

Idlube Lube 167

Lube 100

Mil-Lube

0303 EP Lubricants AVALUB EP EP Mudlube Easy Drill EP Lube Lubrifilm

0302 VariousLubricants

AVA Green-Lube

Lubrabeads Graphite Walnut Shells

8.1.6 Detergents/Emulsifiers/Surfactants

0307 Detergents AVADETER Condet Drilling Deter. DD MD

0308 Non-ionicEmulsifiers

TCS 30 Aktaflo E IDMULL 80 DME DME

0309 non-ionicSurfactant.

AVAENION Aktaflo S Hymul DMS DMS

AnionicSurfactant

Trimulso

Clay Seal

Salinex Atlosol

ARPO





8.1.7 Stuckpipe Surfactants

0310 Oil-SolubleSurfanc.

AVATENSIO Skotfree IDFREE (UW) Pipe-Lax Mil-Free

0618 Oil FluidConcentrate.

Spotting Oilfree

AVATENSIOW

Envirospot IDFREE Pipe-Lax W

Pipe-Lax Env

Black Magic

8.1.8 Borehole Wall Coaters

0303 Oil-DispersableAsphalt

Stabilube AK 70

BXR-L

Asphalt Stabihole Protectomagic

0304 Water-Dispersable

Asphalt

AVATEX Barotroll Holecoat II ProtectomagicM

0306 SulphonateAsphalt

Soltex Soltex IDTEX W Soltex Soltex

Gilsonite AVAGILS-W Barbalok IDTEX Soltex

8.1.9 Defoamers/Foamers

0909 Stereate Al Stearal

0912 SiliconDefoamers

AVASIL SDI IDF AntifoamS

Defoam X LD 8

0911 AlcoholDefoamers

AVADEFOAM BaradefoamW300

IDF Defoamer Magconol WO Defoam

0913 Foamers AVAFOAM Quik-Foam HI Foam 440 Ampli foam

8.1.10 Corrosion Inhibitors

0901 PO Scavenger SodiumSulphite

Barascav D Idscav 210 OxygenScavanger

Noxigen

0907 Fe-Base Hydr.Sul. Sc.

Ironite Sponge Ironite Sponge Ironite Sponge Ironite Sponge Ironite Sponge

0918 Zn-Base Hydr.Sul. Sc.

ZincCarbonate

No-Sulf Idzac Sulf X Milgard

Filming Amines Incorr Barafilm Idfilm 220 Conqor 303 Aquatec

Filming DP Incorr-Q5 Barafilm Idfilm 120 Conqor 202 Amitec

0903 Anti-Scale AVA AS-1 Refer to specific literature

ARPO





8.1.11 Bactericides

0914 Paraformaldeide Paraform-aldeide

Paraform-aldeide

Paraform-aldeide

Paraform-aldeide

Paraform-aldeide

0915 LiquidBactericide

AVACID F25 Aldacide G IDCIDE Bacbane III Mil-Bio

8.1.12 Lost Control Materials

0701 Granular Granular Wallnut Wallnut Shells Nut Plug Mil-Plug

0702 Mica AVAMICA Micatex Mica Mica Mil-Mica

0703 Fibrous Lintax Fibertex Mud-Fiber Fiber Mil-Fiber

0704 Cellophene Jel-Flake CellopheneFlakes

Flake Mil-Flake

0705 Mixed Intamix Baroseal ID Seal Kwik-Seal Mil-Seal

0706 High Filtration Diascal M Diaseal M Diaseal M Diaseal M Diaseal M

0707 Diatomite Diatomite IDF D-Plug

0708 Acidified Intasol Baracarb Calcio Carbon

8.1.13 Chemical Products

1001 Caustic Soda

1002 CausticPotassium

1003 Hydrated Lime

1004 SodiumCarbonate

1005 PotassiumCarbonate

1006 BariumCarbonate

1007 SodiumBicarbonate

Common to all suppliers.

1008 PotassiumBicarbonate.

1009 Gypsum

1010 Sodium Chloride

1011 Calcium Chloride

1012 PotassiumChloride

1013 Sodium Bromure

1014 CalciumBromure

ARPO





8.1.14 Oil Based Fluid Products

System Name AVAOIL Invermul Interdrill Versadril Carbo-Drill

0601 PrimaryEmulsifiers

AVAOIL-PE Invermul Emul Versamul Carbo-Tec

0602 SecondaryEmulsion

AVAOIL-SE EZ-Mul FL Versacoat Carbo-Mull

0603 Wetting Agents AVAOIL-WA Driltreat OW Versawet Surf-cote

0605 OrganophilClays

AVABENTOIL Geltone II Vistone Versagel Carbo-Gel

0608 Asphalt FiltrateReducers

AVAOIL-FR-HT

AK 70 S Versatrol Carbo-Trol

Non-AsphaltFiltrate Reducers

AVAOIL-FC Duratone NA Versalig Carbo-Trol(A9)

0610 Thinners AVAOIL-TN OMC Defloc Versathin

RheologyModifiers

AVAOIL-VS RM-63 IDF Truvis Versamod Charbo-Thix

System Name AVAOIL-LT Enviromul Interdrill NT Versaclean Carbo-SEA


AVAOIL-PE-LT

Invermul NT Emul Versamul Carbo-Tec

0602 SecondaryEmuls.

AVAOIL-SE-LT

EZ-Mul NT FL Versacoat Carbo-Mull

0603 Wetting Agents AVAOIL-WA-LT

Driltreat OW Versawet Surf-cote

OrganophilClays

AVABENTOIL Geltone II Vistone Versagel Carbo-Gel

0605 OrganophilClays/HT

Versagel HT

0608 Asph. Filtr.Reducers

AK 70 S Versatrol Carbo-Trol

Non-Asph. Filtr.Red.

AVAOIL-FC-LT

Duratone NA Versalig Carbo-Trol(A9)

0610 Thinners AVAOIL-TN-LT

OMC Defloc Versathin

RheologyModifiers

AVAOIL-VS-LT

RM-63 IDF Truvis Versamod Charbo-Thix

ARPO





System Name AVA Core Baroid 100 Trudrill Versacore Carbo-Core


EZ Core Trumul Versamul Carbo-Tec


AVAOIL-SE Trusperse Carbo-Mull

0603 Wetting Agents AVAOIL-WA Trusperse Versa SWA


AVABENTOIL-HY

Geltone III Truvis VG 69 Carbo-Gel

0608 Asph. Filtr.Reducers

AVAOIL-FR-HT

AK 70 Trudrill S Versatrol Carbo-Trol

Non-Asph. Filtr.Red.

AVABIOFIL-HT

Baracarb Truloss Lo-Wate/Fazegel

Carbo-Trol(A9)

0610 Thinners Defloc

RheologyModifiers

AVAOIL-VS Truplex Versa HRP Carbo-Vis HT

System Name AVABIOL Petrofree Ultidrill Novadrill


AVABIO PRI. EZ Mul NTF Ultimul Novatec-P


AVABIO Sec. Ultimul II Novatec-S

0603 Wetting Agents AVABIO Wet Ultisperse Novawet


AVABIO Bent Geltone II Ultitone VG 69

0608 Asphalt FiltrateReducers

Vestrol

Non-AsphaltFiltrate Reducers

AVABIOFIL-HT

Duratone HT Ultiflo Versalig

0610 Thinners AVABIO Thin OMC 2/42

RheologyModifiers

AVABIO VIS- Ultivis Novamod

ARPO





8.1.15 Base Liquids And Corrections

0801 Fresh Water

0802 Sea Water

0803 Brine

0804

0811 Diesel

0812 Fuel Oil

0813 Exhaust Oil

0814 Low Toxicity Oil Lamium/AVAOIL base

Lamium BFF. Lamium

0815 Glycol GP AVABIOLUBE Gem-GP HF 100 N

0816 Glycol CP AVAGLICO Gem-CP Staplex Gliddrill-LC Aquacol TMAquacol TM-DAquacol TM-S

0817 Oil Base AVAOIL base

0818 Synthetic Base Synthec

0819

0820 KLA-Cure

Clay Inhibitor KLA-Gars

ARPO




9. DRILLING FLUIDS APPLICATION GUIDE

This document is an extract from a more comprehensive guide published by World Oilrelating to some of Eni-Agip's most important contractors, namely AVA, Baroid, BakerHughes Inteq, MI, Schlumberger, Dowell and IDF.

The product functions and systems, for which these products are employed, contained inthis section, are provided by the contractors named above.

ARPO




9.1APPLICATIONS GUIDE

LegendA = Alkaline AgentB = BactericideCA = Ca PrecipitantCO = Corrosion InhibitorD = DefoamerE = EmusifierFI = Filtrate ReducerFL = FlocculantFO = FoamerLO = Loss Control Agent

LU = LubricantP = Pipe Freeing AgentPA = Polar ActivatorSH = Shale InhibitorSU = SurfactantTE = HT Stabilising AgentTH = ThinnerV = ViscofierW = Weighting Agent

APPLICATION GUIDE TO DRILLING FLUID PRODUCTS

PRODUCTS FLUID SYSTEMS FUNCTIONS

NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E-B

AS

E

PO

LYM

ER

S

LOW

SO

LID

S

SA

LT S

AT

UR

AT

ED

WO

RK

OV

ER

OIL

-BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

-AE

RA

TE

D

AVALIGAVA PVA

AVAREXAVASILAVATENSIO AVOIL-FCAVOIL-PEAVOIL-SE AVOIL-TNAVOIL-VSAVOIL-WA BACBAN IIIBARA-B466BARABLOK

BARA BRINE DEFOAMBARABUF

X X X X X X XX X X X X

X X X X

X X X X X XX X X X X X XX X X X X X

XXX

XXX

X X X X X X XX X X X X X XX X X X X X

X X X X X X XX X X X X

VTESH

FIDP

FIEE

THV

SU

BB

SH

DA

SHTH

TE

FIFI

FI

E

CO

LU

SUFISH

SH

SUSU

TE

FI

X

AVAGUM

AMITECAMPLI-FOAM

X X X X X X XX X X X

XLUFO

LU

LUFO

ALLUMINIUM STERATE

ALDACIDE-CALL-TEMP X XX

BTH FL

ACTIGUM X X X X SH SHX X X

X X X X X SUAKTAFLO-S

X

X X FO

D DD

ANTIFOAM-SAP-21AQUA-MAGIC

X X X X X XX X X

X X X X

DFI

X

LU LU LU

AQUA-SEALASPHALTATTAPULGITE

X X X X XX X X

X X X X

SHSHV SH

FI FIX X X X LU FI

X X

BARACARB X X X X X X COX X

ARPO







PRODUCTS MUD SYSTEMS FUNCTIONS

NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E-B

AS

E

PO

LYM

ER

-BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

.

WO

RK

OV

ER

OIL

-BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

BARADEFOAM W-300BARAFILM

BARAFLOC BARAFOAMBARAFOAM-K

BARAFOSBARA-KLEANBARANEX

BARAPLUG X, XCBARARESIN GRANULEBARARESIN-VIS

BARASCAV-D BARASCAV-L

BARAVISBARAWEIGHTBARAZAN

BARAZAN L

BARODENSE

X X X X X X XX X X X X X X X

X XX

X X

X X X

X X X X X X

X X XX X

X

X X X X X X X

X X X X X X X

X X X X XX

X X X X X X X

X X X X X X X

X X X X X X

DCO

FL FOFO

THSUFI

LOLOV

CO CO

VWV

V

W

CA

TE

A

AIR

AIR

AT

ED

BARACTIVE X PA

BARASCRUB SU

BARITE X X X X X X X WX

BARA-DEFOAM-C X X X X X X XX D

BARACATBARACOR-95

BARACOR 113BARACOR 129BARACOR 450 BARACOR 700BARACOR 1635

X X X X XX X X X X X

X X X X X X X XX X X X X X X

X X

XX X X X X

SHCO

COCOCO

COCO

TE

TE

BARACOR-100 X X X X X X X CO

ARPO







PRODUCT FLUID SYSTEMS FUNCTIONS

NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E-B

AS

E

PO

LYM

ER

-BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

.

WO

RK

OV

ER

OIL

-BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

AIR

AT

ED

BIO-SPOT

BIO-SPOT IIBLACK SPOT MAGIC

BLACK MAGIC LTBLACK MAGIC SFTBRINE-PAC BROMIMULBROMI-VIS

BX-L

CARBO CORECARBO-GEL

CARBO-GEL 2

X X X X X X X

X X X X X X X

X X X X X X X XX X X X X X X X

X

X XX X

X X X X X X

X XX

X

P

PP

PP

CO EV

SH

EV

V

FI

BAROFIBREBAROID

BARO-LUBE BARO-SEALBARO-SPOT

BAROTHIN


X X X X X X

X X X X X X XX X X X X X

X X X

LOW

LU LOP

TH SH FI

BENTONITE X X X X X V SH

BARO-DRILL 1402 X X X X X X SH LU

BARO-TROL X X X X X X SH LU E

BIO-LOSE X X X X X X FIBIO-PAQ X XX X FI FI FI

BLACK SPOT MAGIC CLEAN X X X X X X X X P

CANE FIBER X X X X X X LO

FI FI

BRINE-PAC BROMIMULBROMI-VIS

X

X XX X

CO

EV

CARBO-GEL N X V

ARPO








NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E-B

AS

E

PO

LYM

ER

-BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

.

WO

RK

OV

ER

OIL

-BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

AIR

AT

ED

CARBO-MIXCARBO-MUL CARBO-MUL A

CARBO-MUL HTCARBONOX

CARBO-TECCARBO-TEC HWCARBOTHIX

CARBO-TROLCARBO-TROL A-9CARBO-TROL A9 HT CARBOVIS

CAT-300

CAT-GEL

XXX

XX X X X

XXX

XXX

X

X X X X X

X X X X XX

EE E

ETH

EEV

FIFIFI V

FI

FI

SU

SUFI

FI

FI

E

TE

TE

CARBOSAN-EF X X X X XX BX X X

CAT-HICAT-LO

CAT-THINCAUSTILIGCC-16

CELLEX

CHEK-LOSS

CHEMTROL XCHROMEX

TE

X X X X XX FIX X VX X X X XX FIX

X X X X XX TH

XX X X TH FI TEXX X X TH FI TE

X

X X X FIX VX X X X XX LOXCELLOPHANE FLAKES

CARBO-SEAL X LO LO LO

X X X X XX LOX X X

X X X X FL TE THX XXX X X TE TH FIX

CHROME FREE II X X TH FIX

CLAY-SEAL X X SHXX X XCMO-568 LUX

ARPO








NO

N

DIS

PE

RS

ED

DIS

PE

RS

ED

LIM

E-B

AS

E

PO

LYM

ER

-BA

SE

LOW

SO

LID

S

SA

LT S

AU

RA

TE

D

WO

RK

OV

ER

OIL

-BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

AIR

AT

ED

CON-DETCONQOR 101CONQOR 202

CONQOR 303CONQOR 404CONQOR 505

D-DDE-BLOCK/S

DEFOAM-X DENSIMIX

DEXTRIDDIASEAL M/DIEARTH DIATOMITE

DOLSALDOLSAL B

DRILFOAMDRILLING PAPERDRILTREAT

XX

X X X X X X X X

X X X X X X XX X X X X X X XX X X X X X X X

X X X X X X X XX X X X X X


X X X X X X

X X X X X X X

X X X X X X XX X X X X X X

XX X X X X X

XX

SUCOCO

COCOCO

SUE

D W

FILOLO

VV

FOLOE

E

ELU

V

LU

FI

LUP

DCP-208 X X X X X X SH LU FI

DEFOAMER X X X X X X X X D

DI-PLUG X X X X X X X LO

DRYOCIDEDURATONE HTDUROGEL ECOL LUBEENIONENVIRO SPOT

X X X X X X X XX

X X X X X X X

X X X X X X XX X X X X XX X X X X X X

BFIV

LUEP

TE FI

FI SUSULUFI

ARPO






APPLICATION GIUDE TO DRILLING FLUID PRODUCTS

PRODUCTS FLUID SYSTEMS FUNCTION

NO

N-D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E-B

AS

E

PO

LYM

ER

-BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

AT

ED

WO

RK

OV

ER

OIL

-BA

SE

PR

IMA

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SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

AIR

AT

ED

DRYOCIDEDURATONE HTDUROGEL

ECOL LUBEENION

ENVIRO SPOT ENVIRO THINENVIRO TORQ

E.P. LUBEE.P. MUDLUBEEZ-CORE

EZ-MUD EZ MUD DPEZ MUL-NT

FER-OX

FIBERTEXFILTER-CHECKFILTREX FLAKE

FLO-VIS

FOAM-BLASTER

X X X X X X X XX

X X X X X X X


X X X X X X XX X X X

X X X X X X

X X X X X XX X X X X X

X

X X X X X XX X X X X

X

X X X X X X X X

X X X X X XX X X X X XX X X X X

X X X X X X

X X X

X X X X X X X

BFIV

LUE

P TH

LU

LU LUE

V SHE

W

LOFIFI

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V

D

TE FI

FI SUSU

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EASY DRILL X X X X X X X LU SU SH

EZ MUL-NTE X E

FERROCHROME X X X X X X TH FI E

FLO-TROL X X X VX X X

FLOXIT X X X FL SH

X X X

ARPO








NO

N-

DIS

PE

RS

ED

DIS

PE

RS

ED

LIM

E-B

AS

E

PO

LYM

ER

-BA

SE

LOW

SO

LID

S

SA

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AT

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AT

ED

WO

RK

OV

ER

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-BA

SE

PR

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SE

CO

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AR

Y

SE

CO

ND

AR

Y

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AIR

AT

ED

GRANULAR

HOLECOATH.T.P. IDBOND

IDBOND PIDBRIDGE CUSTOMIDBRIDGE L

IDBRINE P

X X X X X X X X

X X X X X X XX

X X X

X X XX X X X X X XX X X X X X X

X X X XXIDCAP IDCARB 75

IDCARB 150IDCARB CUSTOM IDCIDE L

IDCIDE PIDFAC IDF ANTIFOAM S

X X X X X X X X

X X X X X X X XX X X X X X X XX X X X X X X

X X X X X X X

X X X X X X X

LO

SHFI SH

SHFIFI

COSH W

FIFI B

BSU D

FI LUV

LOLO

AFIFI

LO WLO

W

GELEXGELITEGEL SUPREME

GELTONEGELTONE II

GELTONE III

X X XX X X X X X XX X X X X X X X

XX

XX

VVV

V

V

V

FLFIFI

FI

TE

GEL TEMP X X X X X X V SH

GEM-GP X X X X X SH LU GEM-GP X X X X X SH LU FI

GL 1 DRILL LC X X X X X X SH LU FI

HF 100-N X X X X X X SH LU FI

ARPO







PRODUCTS FLUID SYSTEM FUNCTION

NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E-B

AS

E

PO

LYM

ER

-BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

AT

ED

WO

RK

OV

ER

OIL

-BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

AIR

AT

ED

IDF HYMULIDFILM 120IDFILM 220X IDFILM 520XIDFILM 620IDFILM 820X IDF INSTAVISIDF KWICKCLEANIDFLO IDFLOCIDFLOC CIDFLO HTR IDFLO LTIDF MUD FIBERIDF POLYLIG IDF-POLYTEMPIDF PTS-100IDF PTS-200

X X X X X X XX X X X X X XX X X X X X X

X

X X X X X X X

X X XX

X X X X X X X

XX

X X X X X X X

X X X X X XX X X X X X XX X X X X X X

X X X X XX X X X XX X XX X

SUCOCO COCOCO VSUFI FLFLFI

LOFI

LO FITETE

E

B

FI

THAA

IDF DEFOAMERIDF DI-PLUG IDF DRILL. DETERGENTIDF DV-68IDF FLOPLEX

IDF FLRIDF FLR XLIDF GEL TEMP IDF HI-FOAM 440IDF HI-TEMPIDF HI-TEMP II

X X X X X X XX X X X X X X

X X X X X XX XX X X X X X X

X X X X X X XX X X X X X XX X X

X XX X X X X XX X X X XX

DLO

SUVFL VFIV

FOFIFI

EFL

FI

SUTH

ARPO







PRODUCT FLUID SYSTEM FUNCTION

NO

N-D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E-B

AS

E

PO

LYM

ER

-BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

AT

ED

WO

RK

OV

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-BA

SE

PR

IMA

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SE

CO

ND

AR

Y

SE

CO

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AR

Y

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AIR

AT

ED

IDF TRUFLO 100IDF TRULOSS

IDF TRUMUL IDF TRUPLEXIDF TRUVIS HT

IDF TRUVIS IDF ULTRADRIL OILIDF VISPLEX

IDHEC IDHEC LIDLUBE

IDMUL 80 IDPACIDPAC XL

IDPLEX 100 IDPLEX KIDSCAV 110

IDSCAV 210

XX

XXX

XX

X X


X X X X X XX X X X X XX X X X X X

X XX X

X X X X X X X

X X X X X X X

FIFI

E VV

V V

V V

LU

E FIFI

SU SU

CO

CO

FI

V

IDF PTS-300IDFREE IDFREE (UW)

IDF RHEOPOLIDF SAFEDRIL CONC.IDF SAFELUBE

IDF SM XIDF TRUDRILL S

IDF TRUFLO 100

X X X X XX X X X X X X XX X X X X X X

X X X X X XX X XX X X X X X

X X XX

XX

TEPP

FISHLU

VFI

FI

ASU

VLUD

FI

IDF SEAL X X X LO

ARPO








NO

N-D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E-B

AS

E

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LYM

ER

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SE

LOW

SO

LID

S

SA

LT

SA

TU

RA

TE

D

WO

RK

OV

ER

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-BA

SE

PR

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SE

CO

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AR

Y

SE

CO

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AR

Y

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AIR

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ED

IDVISIDVIS LIDWATE IDZACIDZAC LIMPERMEX INTAMIXINTASOLINTERDRILL DEFLOC INTERDRILL EMULINTERDRILL EMUL HTINTERDRILL ESX INTERDRILL FLINTERDRILL LO FLINTERDRILL LOMULL INTERDRILL LO RMINTERDRILL NAINTERDRILL NA HT


X X X X X X X XX X X X XX X X X X X

X X X X X X XX X X X X X X X

X

XXX

XXX

XXX

VVW

COCOFI

LOLOTH EEE

FIFIE VFIFI

FI

FI

FLTE

EEV

TEFI

IDSCAV 310IDSCAV 510IDSCAV ES IDSPERSE XTIDSURFIDTEX IDTEX WIDTHINIDTHIN 500

X X X X XX

X

X X X X X XX X X X X X XX X X X X X

X X X XX X XX X X X XX

COCO

THSUSH

SHTHTH

FL

FI

FIFIFI

ARPO








NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

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AS

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SO

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S

SA

LT S

AT

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AT

ED

WO

RK

OV

ER

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BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

AIR

EA

TE

D

K-17K-52

KLEEN-UP

K-LIG

KWUIKSEALKWUICK-THK LD-8

LIGCOLIGCON LIGNO-THIN

LIGNOXLINTAX

LIQUI-VIS NT

LO-WATELUBE-106LUBE-100

X X X X X XX X X X X X X X

XX X XX

X X XX X X X XX X X X X X X X

X X X X XX X X X

X X X X X

X XX X X X X X X

XXX

X X X X X X X XX X X X X X

THSH

SU

TH

LOV D

FIFITH

THLO

WLU

FI

FI

FI

THTHFI

SH

SH

E

FL

V

FI LO

* barite solvent.

INTERDRILL OWINTERDRILL RMINTERDRILL S INTERDRILL VISTONEINTERDRILL VIST. HTINTERSOLV H INTERSOLV XFEINVERMUL-NTLJELFLAKE

XXX

XX

X

XX

X X X X X XX

SUVFI VV

CA

ELO

TH

SH FI*

KLA-CURE X X X X SH

KLA-GARD X X X X SH

X X X X X X X LU SU SH

ARPO








NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E-B

AS

E

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LYM

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SE

LOW

SO

LID

S

SA

LT S

AT

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AT

ED

WO

RK

OV

ER

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BA

SE

PR

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SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

AIR

EA

TE

D

M-I CEDAR FIBER

M-I GELMIL-BAR MIL-BEN

MIL-CEDAR FIBERMIL-CLEAN MIL-FIBER

MIL-FLAKEMIL-FREE MIL-GARD

MIL-GARD LMIL-GARD RMIL-GEL

X X X X X X

X X X X X X X XX X X X X X X XX X X X X

X X X X X X

X X X X X X X

X X X X X XX X X X X X XX X X X X X X X


X X X X X X

LO

VW V

LOSU LO

LOP

CO

COCOV

FI

FI

FI

LUBE-153LUBE 167LUBRA BEADS LUBRI-FILMLVO-69MAGNA-FLUSH MAGNE-SETMCATMCAT-A

MELANEX TM-I BAR

MICATEX

X X X X X XX X X X X X X XX X X X X X X

X X X X X X XX

X X X X X XX X XX X XX X XX X X

X X X X XX X X X X X X X

X X X X X X XX

LULULU

LUV

* LOSHSH

TEW

LO

SU

V

TH

SH

FI

FIMD TM X X X X X X X X DT DT DT

MICA X X X X X X XX LO

* FOR CLEANING UP WELL TUBULARS

ARPO







PRODUCT FLUID SYSTEM FUNCTION

NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E B

AS

E

PO

LYM

ER

-BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

AT

ED

WO

RK

OV

ER

OIL

BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

AE

RE

AT

ED

MIL-STARCHMIL-TEMPMIL-THIN M-I LUBEM-I LUBE ENVM-I QUEBRACHO M-I X IIMY-LO-JEL

NEW-DRILL NEW DRILL HPNEW-DRILL PLUS

X X X X X XX X X X X

X X X X


X X X X X X X XX X X X X X X

X X X XX XX X X X X XX X X X X

FITETH

LULUTH

LOFI

SH SHSH

VFI

FI

FI

TH

E

MIL-GEL NTMIL-KEM MIL-LUBEMIL-PACMIL-PAC LV MIL-PAC TMILPARK CSIMILPARK MD MILPARK SSIMIL-PLUGMIL-POLIMER 354 MIL-REZMIL-SEALMIL-SPOT 2

X X X X X XX

X X X X XX X X X X X

X X X X X X

X X X X X X

X X X X X XX X X X X X X

X X X X X XX X X X X X XX X X

X X X X XX X X X X XX X X X X X XX

VTH

LUFIFI

FICOSU

COLOV

FILOP

FIFI V

V

E

N-DRILL FI

N-DRILL-O FIN-DRILL-HI FIN-DRILL-HT FI

ARPO








NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E B

AS

E

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LYM

ER

BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

AT

ED

WO

RK

OV

ER

OIL

BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

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-AE

RE

AT

ED

NEW-THIN NEW-TROLNEW-VIS

NF-2 NOVAMOD

NOVAMULNOVASOL

NOVAWET

X X X X XXX X X XX X X X X X

X

XX

XXNOXYGEN

OIL FAZE BASE

OXIGEN SCAVENGER

X X X X X X X

X

X X X X X X X

THFIV

I V

ETH

SUCO

E

CO

SU

E

FI

FI

TH

V

NO-SULF X X X X X X COI I

NOVATEC-P XX E SU

NOVATEC-S XX SU E

N-PLZ-X LON-SQUEEZE LON-VIS-O FI

N-VIS-P VN-VIS-HI V

OIL FOS X X X X TH FI FIOMC X THOMC-42 X TH

OMNI COTE X THX THOMNI MIX X EX EOMNI MUL X EX E

OMNI PLEX X VX V

EE

VOMNI TEC X EX E EOMNI COTE X FIX FI

ARPO








NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E B

AS

E

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LYM

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LOW

SO

LID

S

SA

LT S

AT

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AT

ED

WO

RK

OV

ER

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BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

-AE

RE

AT

ED

SAFE-BLOCK

SAFE-KLEENSAFE-LINK

SAFE-TROL

SALINEXSALT GEL

SCALE-BANSDISHALE-BOND

XX

XXXX

X X XX X X X X X X

X X X X X X XX X X X X X XX X X X X X

FI

SUVFI

EV

COD

LO

FI

FI LUFI

SUSH LU

PAC-L

PERMA-LOSE HT

PHOS

X X X X X X X FI SH EXPAC-R X X X X X X X FI SH VX

X LU LU LUPARA-TEQ

PENETREX X X X X X

LU LU LUPERFLOW DIF X FI FI FIPERFLOW 100 X FI FI FI

X X XX X X FI

VPETROFREE

X X X X X X X CA

PIPE LAX X X X X X X X PXPIPE LAX ENV X X X X X X X PX LUPOLYLIG X X X X X X TH FI E

PYROTROL X X X X FI TH THQ-BROXIN XX X TH FIRESINEX X X X X X FI

RHEOPOL X X X XX FI VRHEOSTAR X X X X X TE THRHEOMATE X X X X X TE TH

X RMRM-63X FLRV-310

SAPP X X TH TH

ARPO






RALLAPPLICATION GUIDE TO DRILLING FLUID PRODUCTS


NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E B

AS

E

PO

LYM

ER

BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

AT

ED

WO

RK

OV

ER

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-BA

SE

PR

IMA

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SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

-AIR

EA

TE

D

THERMA-BUFFTHERMA -CHEK

THERMA-CHEK LV THERMA-THINTHERMA-THIN DP

THERMA-VIS



X X X X X

TEFI

FI THTH

V FI

SHALE-CHEKSI-10006-UP

SP-101

SPERSENESPERSENE CF

STABIL HOLESTABILITE


X

X X X X X X X


X X X X X X XX X

SHCOV

FI

THTH

SHTH

FISH

SH

FIFI

LUSU

TH

TE

EE

FI

X X X X X


X X X X X X X XX X X

X

XX X X X XX X X X X X

X X X X X XX

LU

DD

CO V

SU

V TH

TH

SU

SH

FI

FI

FI

E

LU

SM-(X) X X X X X XX V SHSOLUFLAKE X X X X X XX LO LOX LO

STAPLEX X X X XX SH LU E

STABILUBE

STEARALLSTEARALL LQDSTICK-LESS X X X X X XX LUX

SULF-XSUPER COLSURF COTE

SUSPENTONETACKLETANNATHIN

TCS/30

ARPO







NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E B

AS

E

PO

LYM

ER

BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

AT

ED

WO

RK

OV

ER

OIL

-BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

AIR

-AIR

EA

TE

D

THERMPAC ULTORQ-TRIM 22TORQ-TRIM II TRIMULSO

UNI-CAL

UNI-CAL CF VEN-FYBERVERSACOAT

VERSADUAL

VERSAGARD

VERSA-HRPVERSALIG VERSAMOD

VERSAMULVERSAPRO VERSA-SWA

VERSATHINVERSATRIM VERSATROLL

VERSATROLL NSVERSAWET

X X X X X XX X

X X X

XX

X

X

XXX

XXX

XXX

FILULU P TE LU

TH

TH

LOE

SU

SU

VFIV

EE SU

THSU FI

FISU

FI

FI

SU

E

E

FISU E

E

E

TE

TH

TH

VTE

X X X X X X

X X X

X X X

VERSAGEL-HT V TEX

XXX

ULTIMUL E SUX

ARPO








NO

N D

ISP

ER

SE

D

DIS

PE

RS

ED

LIM

E B

AS

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BA

SE

LOW

SO

LID

S

SA

LT S

AT

UR

AT

ED

WO

RK

OV

ER

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-BA

SE

PR

IMA

RY

SE

CO

ND

AR

Y

SE

CO

ND

AR

Y

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AIR

AT

ED

VG-69VICTOGEL AFVICTOSAL VISCO 83VISCO SLVISCO XC/84

VISGEL

W.O. 21W.O. 21L

W.O. 30

W.O. DEFOAMWONDERSEAL XCD POLYMER

X-CIDE 207XP 20X-TEND II

X-VISZEOGEL

XX X X X X XX X X X X X X

X X X X XX X X X X X XX X X X X X X

X X X X X

X X X X XX X X

X X X X X X X

X X X X X X XX X X X X XX X X X X X

X X X X X X X XX X X X X

X X X

XX X XX

VFIFI

SHFLSH

V

VVW

DSH V

BTEFL

VV

V

V FISHV FI

FL

LU FI

TH FIV

FI

VISPLEX X V SH

WALLNUT SHELLS X X X X X LOXX X

ARPO




10. DRILLING FLUID ANALYSIS

The contents of this section comply with specification API RP 13B-1 dated June 1st,1990.

ARPO




10.1 DRILLING FLUIDS

10.1.1 Density (Fluid Weight)

Equipment Required:

• Fluid balance• Pressurised balance• Thermometer 0-105oC

Calibration:

• With fresh water at 21oC = 1kg/lProcedure:

1) Level with the instrument base.2) Fill the balance cup with the drilling fluid to be tested.3) Put on the cap and make sure some of the fluid is expelled through the hole. When

using the pressurised balance, use pump to add fluid into the cup under pressure.4) Wash the fluid from outside of the balance.5) Place the balance on the support.6) Move the rider so that the bubble is on the centre.7) Read the density value at the side of the rider toward the support.

Result:

• Report the density to the nearest 10gr (0.1lbs/gal).• The balance provides the reading in ft3 and the gradient in psi per 1,000ft depth.

10.1.2 Marsh Viscosity

Equipment Required:

• Marsh Funnel• Chronometer• Thermometer 0-105oC

Calibration:

• With fresh water at 21 oC, 1/4 gallon = 26(+/- 0.5) secs.Procedure:

1) Record the temperature of the sample.2) Keep the funnel upright.3) Close the orifice with a finger.4) Pour non-gelatinised fluid through the screen.5) Remove the finger and measure the number of seconds required for fluid to fill the

receiving vessel, commonly 1/4 gallon (946 cc).

Results:

Viscosity is recorded in seconds.

• API regulations indicate 1/4 gals (946).• Eni-Agip gen erally specifies 1 litre (1,000cc).

ARPO




10.1.3 Viscosity, Yield Point, Gel Strength

• Apparent Viscosity• Plastic Viscosity• Yield Point

• Gels Strength• K (Consistency Index)• n (Flow Index)

Equipment Required:

• Rotational viscosimeter (Fann)(1)

• Thermostatic cup(2)• Chronometer• Thermometer 0-105oC

Calibration:

• With fluids of known viscosity (Silicon Oils)• With a suitable mechanical calibration kit(3)

Procedure:

1) Record the fluid sample point.2) Place the sample in a suitable container.3) Place the rotor exactly at the scribed line.4) Record the temperature of the sample.5) With the rotor rotating at a speed of 600 RPM, wait for reading to become a steady

value.6) Change to 300 RPM, and again wait for reading to reach a steady value.7) Stir the fluid at high speed for 10 secs.8) Allow the fluid to stand undisturbed for 10 secs.9) Shift to 3 RPM and record the maximum reading.10) Re-stir the fluid at high speed for 10 secs.11) Allow the fluid to stand undisturbed for 10 secs.12) At 3 RPM again, record the maximum reading.

Alternative Steps For Oil Based Fluids:

1) Place the fluid sample in the thermostatic cup.2) Place rotor exactly at the scribed line.3) Adjust the thermostat to the pre-selected temperature(4), and record on the report.

Results:

Apparent Viscosity (cP) = (Reading at 600rpm) /2Plastic Viscosity (cP) = (Reading at 600rpm) - (Reading at 300RPM)Yield Point (lbs/100sqft) = (Reading at 300rpm) - (Plastic Viscosity)Gels Values (lbs/100sqft) at 10”and 10

= (Reading at 3rpm) after 10” and at 10’

n (Dimensionless) = 3.32 log of reading at 600rpm/Reading at 300rpmK (lbs .Sn/100sqft) = (Reading at 600rpm/1020)

Convers ion Factors:

lbs/100ft2 /2 = +/- (g/100 cm2)lbs* sn/100ft2 *4.79 = (dyne*sn/cm2)lbs100ft2 *0.48 = Pa (pascal)

(1) Preferably at six speeds.(2) Must be used with oil based fluids(3) Recommended if used at the rig site.(4) 120 +/- 2oF, 150 +/-2oF.

ARPO




10.1.4 API Filtrate

Equipment Required:

• Filter press with internal diameter of 3", filter area of 7.1 +/- 0.1 in2

• Paper filter, Whatman No 50 or S&S No 576 diameter 90mm• 30min timer• 10 or 25cc graduated cylinder

Calibration:

• Verify the accuracy of the filter press manometer and filtrate area.Procedure:

1) Pour the fluid into the dry filter press until it is 1/2 inch from the top.2) Place the cylinder at the filtrate exit.3) Apply a pressure of 100 +/- 5 psi for 30secs.4) After 30 ins, measure the volume of filtrate and release the pressure.5) Remove the paper from filter and wash the filter cake .

Result:

• Record the fluid temperature at the start.• Report the filtrate volume in cc.• Report the thickness of the filter cake in ?/32".• If filtrate area is 3.5in2, double the filtrate volume.

ARPO




10.1.5 HPHT Filtrate

Equipment Required:

• A complete HP/HT filter press with a filter area of 3.5 or 7.1in2;• CO2 source (not AOTE, only CO2)• Paper filter, Whatman No 50 or S&S No 576 diameter 90mm• Pressurised connection cell• 30 min timer• 25 or 50cc graduated cylinder• High speed stirring unit

Procedure to Test at Max. Temperature of 300 oF:

1) Pre-heat the heating jacket to 10oF above the selected test temperature.2) Stir the fluid at a high speed for 10mins.3) Fill the cell up to 1/2" from the top.4) Place filter paper.5) Complete the assemble of the cell.6) Place the cell into the heating jacket with both the top and bottom valves closed.7) Place the pressurised cell to collect the filtrate.8) Apply pressure of the top with not less than 100psi with valves closed.9) Open the top valve and apply a pressure to the fluid while heating it to the selected

temperature. Note: Total time of heating should not exceed 1hr.10) When the sample pressure reaches the set temperature, increase the pressure of

the top pressure to 600psi.11) Open the collector valve to start the filtration.12) Collect the filtrate for 30mins.13) Maintain the pre-selected test temperature to within +/- 5oF.14) If back pressure increases over 100psi, reduce the pressure by draining some

filtrate from the graduated cylinder.15) At the end of the test, close both valves of the filter press.16) Recover all the filtrate in the graduated cylinder.17) Bleed the pressure from both regulators.18) Allow sufficient time for the cell to cool before draining the internal pressure and

open the cell.19) Recover the cake and wash it with a gentle stream of water .

Results (6):

• Record temperature and test pressure.• Report the filtrate volume in cc.• Report the thickness of the filter cake in ?/32".• If filtrate area is 3.5 ins2, double the filtrate volume.

(6) HP/HT filtrate is commonly carried out at 500psi (35atm) and at 300oF (149oC). It aims toevaluate the filtrate reducer performance at a temperature where most of the cellulosepolymers degrade, thus allowing the use of appropriate filtrate reducers.As for oil based fluids, HP/HT filtrate represents an important index of emulsion stability.

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10.1.6 Oil, Water, Solids Measurement

Equipment Required:

• 10 to 20cc retort (required accuracy +/- 5%)• 10 or 20cc collection cylinder (required accuracy 0.1 and 0.2cc respectively)• Fine steel wool• Silicon grease• Spatula with a blade shaped to fit inside the dimensions of the retort sample cup• Defoamer• Pipe cleaner

Procedure:

1) Thoroughly check that retort is clean, dry and operating.2) Collect a sample of fluid filtered through a 20 mesh screen on the marsh funnel.3) If the fluid sample is aerated, add some defoamer to about 300cc of the fluid and

slowly stir for 2-3 mins.4) Lubricate the threads.5) Fill the retort with fluid.6) Allow an overflow of the sample through the hole in the lid. Wipe the overflow from

the sample cup and lid.7) Screw the retort cup onto the retort chamber by positioning a ring of steel wool into

the chamber.8) Heat the retort and collect the fluid into the dry liquid receiver.9) Continue heating for 10mins after the last recovered fluid. Note: If the recovered

fluid contains solids, the test must be repeated .Results:

Volume percent water = 100 (volume of water in the fluid)/volume of the sample

Volume of oil: = 100 (volume of oil in the fluid)/volume of the sample

Volume percent solids(7) = 100 - (vol. percent water + vol. percent oil)(7) The solids percentage, as calculated above, is the difference between the volume of water

and volume of oil and the total volume of the sample. The calculation does not make anydifference between the solids and salts which may have been dissolved. To correct solidsfrom NaCl, for every 10gr/l, deduct 0.3% from the solids calculated by means of the retort.

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10.2 WATER-BASED FLUIDS

10.2.1 Sand Content Estimate

Equipment Required:

• A sand screen set consisting of a 200 mesh sieve of 2.5" diameter, a funnel to fitthe screen, a glass measuring tube with indicated marks relating to the quantity offluid and water to be reached. In addition, the tube must have graduations from 0%to 20% which immediately allows the reading of sand percentage .

Procedure:

1) Fill the glass measuring tube to the indicated mark with the fluid.2) Add water to relating mark.3) Close the tube and shake vigorously.4) Pour the mixture into the screen and discard the fluid. Repeat until the wash water passes

through clear.5) Wash the sand retained on the screen.6) Fit the funnel on the screen.7) Turn upside down the funnel and the screen onto the tube.8) Wash the sand into the tube by collecting water and solids in the tube.9) Allow sand to settle.10) Read the percent by volume of the sand from the graduation .Results:

• Report the sand contents of the fluid in percent by volume.• Report where the fluid was caught.

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10.2.2 pH Measurment

Equipment Required:

• pH paper test strips which permit estimation of pH to 0.5/0.2 units(8)

• Glass-electrode pH meter(9)

• Buffet solutions according to the indications supplied with the instruments .Procedure:

• Using paper test strips:1) Place a 2cm strip on the indicator paper on the surface of fluid.

2) Allow it to remain until the fluid has wetted the surface of the paper (+/-30").

3) Compare the colour standards provided on the side of the strip with the teststrip.

• Glass-electrode pH meter.1) Make the necessary adjustment to standardise the meter with the solutions

according to the directions supplied with the instrument(10).

2) Insert the electrode into the fluid contained in a beaker.

3) Stir the fluid around the electrode by rotating the beaker.

4) After the meter reading becomes constant, record the pH .

Results:

• As for pH determination with paper test strips, record the fluid pH to the nearest0.2/0.5 units.

• As for pH determination with glass-electrode pH-meter, record pH to the nearest 0.1unit.

(8) The paper strip method may not be reliable if salt concentration of the sample is high.(9) The electrometric method is subject to error in solutions containing high concentrations of

sodium ions, unless a special glass electrode is used. Suitable correction factors must beapplied.

(10) For accurate pH readings, the test fluid, buffet solutions and reference electrode must all beat the same temperature.

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10.2.3 Methylene Blue Capacity Determination

Equipment Required:

• 1cc syringe.• 250cc Erlenmeyer flask.• 1cc Serological (graduated) pipette.• 50cc graduated cylinder.• Glass stirring rod.• Hot plate.• Paper filter, Whatman No. 1 or equivalent, 11cm in diameter .

Reagents:

• Methylene blue solution, 1cc = 0.01 milli-equivalents.• Hydrogen peroxide, 3% solution.• Sulphuric acid, 5N .

Procedures:

1) Place 1cc of fluid or more (or suitable volume to require 10cc of blue methylene) inthe Erlenmeyer flask.

2) Add 15cc of Hydrogen peroxide.

3) Add 0.5cc of sulphuric acid.

4) Stir.

5) Boil for 10mins.

6) Add blue methylene solution. After each addition of 0.5cc, swirl the content forabout 30secs.

7) Remove one drop of fluid with the glass stirring rod and place it on the filter paper.

8) The end point is reached when the dye appears as a blue ring surrounding the dyedsolids placed on the filter paper.

9) When the situation as described in step 8 occurs, shake the flask for an additional2mins and repeat step 7. If the ring is again evident, the end point has beenreached.

10) If the ring does not appear, repeat steps 6 and 7. Continue shaking the flask for2mins until a drop shows the blue tint.

11) Record the number of cc of blue used to reach the end step .

Results:

Cation exchange capacity (CEC) = cc of methylene/cc of fluid

MBT (Bentonite equivalent) in lbs/bbl = CEC X 5

MBT (Bentonite equivalent) in kg/m3 = CEC X 14.25

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10.2.4 Chloride Content Determination

Equipment Required:

• 1cc pipette.• 1cc serological (graduated) pipette.• 100-150cc beaker (or a white vessel).• Glass stirring rod .

Reagents:

• Silver nitrate solution with known titration.• Potassium chromate indicator solution.• Sulphuric acid: N/50.• Phenolphthalein indicator solutions .

Procedure:

1) Place 1cc (or more) of filtrate into the beaker.2) Add 2 or 3 drops of phenolphthalein.3) If the indicator turns pink, add sulphuric acid drop by drop until the colour is

discharged.4) dilute with 25-50cc of distilled water.5) Add 5-10 drops of potassium chromate.6) Titrate with the addition of silver nitrate until colour changes from yellow to

orange/red and persists for 30secs.7) Record the number of cc of silver nitrate required to reach the end point.8) If over 10cc of silver nitrate are required to reach the end point, repeat the test with

a smaller sample of filtrate .Results:

Chloride gr/l = cc AgNO3 (normality of solutions) 35.453(11)/(cc of filtrate)

NaCl gr/l = cc AgNO3 (Normality of solution) 58.443(12)/(cc of filtrate)

Solutions and Con vers ion Factors:

Concentration of AgNO3 commonly required:

• 0.1N Chlorides (Cl-) gr/l = (cc AgO3 x 3.545) / (cc of filtrate)Salt (NaCl) gr/l = (cc AgNO3 x 5.844) / (cc of filtrate)

• 0.282N Chlorides (Cl-) gr/l = 10 x cc AgNO3 / (cc of filtrate)

Salt (NaCl) gr/l = 10 x cc AgNO3 x 1.65 / (cc of filtrate)

• 0.0282 N Chlorides (Cl-) gr/l = cc AgNO3 / (cc of filtrate)

Salt (NaCl) gr/L = cc AgNO3 x 1.65 / (cc of filtrate)(11) PM Cl = PE Cl = 35.45(12) PM Cl = PE Cl = 58.443

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10.2.5 Calcium Hardness Determination

Equipment Required:

• 1cc pipette• 1cc graduated pipette• 1cc serological (graduated) pipette• 100-150cc beaker• Glass stirring rod• *Two 10cc graduated pipettes• *Hot plate

Reagents:

• 0.01 Molar EDTA solution• Buffer solution, pH 10• Hardness indicator (Black Eriochrome T or similar)• Sodium Hypochlorite, solution at 5.25%(13)

• *Galcial acetic acid(14)

• *pH paper strip

* equipment and reagents required if filtrate is coloured(15 )

Procedure:

1) Place 1 cc (or more) of filtrate into the beaker2) Dilute to 30-40 cc with distilled water3) Reach pH 10 with buffet solutions4) Add an adequate quantity of indicator5) Titrate with EDTA until colour changes from pink-red to light blue-blue.

Procedure for Filtrate Coloured (16):

1) Place 1cc of filtrate into the beaker.2) Add 10cc of sodium ipochlorite and mix.3) Add 1cc of acetic acid and mix.4) Boil for 5mins. Maintain the volume by adding distilled water.5) Verify if hypochlorite is totally discharged with the pH paper strip. If the paper strip

becomes white, boil for longer.6) Cool the solution.7) Continue as indicated from step 3 in the normal procedure .

Results:

Total hardness (gr/l Ca++) = cc 0.01 M EDTA x 0.4/cc of filtrate.(13) In the same cases, ipochlorite can be contaminated by calcium, verify.(14) Avoid all contact with your skin.(15) It is used only if coloured filtrate does not allow the evaluation of colour change.(16) The analysis must be carried out in a well ventilated placed. Do not breathe in vapours.

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10.2.6 Calcium And Magnesium Determination

Equipment Required:

• 1cc pipette• 5 cc graduated pipette• 100-150cc beaker• Glass stirring rod• 10cc serological (graduated) pipette

Reagents:

• 0.01 Molar EDTA solution• Buffer solution: pH 10• NaOH drops or solution• Total hardness indicator (Black Eriochrome T or similar )

Procedure for Determining Calcium:

1) Determine the total hardness as described in the related procedure.

2) Record as ‘a’ the number of cc required.

3) Place a volume of filtrate identical to that required for determining the totalhardness(17).

4) Dilute to 30-40cc with distilled water.

5) Increase pH to 12 by using NaOH.

6) Add the calcium indicator (with calcine or calver II).

7) Titrate with 0.01 M EDTA until colour changes from green to pink-brown in case ofcalcine, otherwise from pink to blue in case of Calver II.

8) Record as ‘b’ the number of cc required .

Results:

‘b’ = cc of EDTA required for calcium

Calcium (gr/l Ca++) = ‘b’ x 0.04/cc of filtrate

‘a’ -’b’ = cc of EDTA required for magnesium

Magnesium (gr/l Mg++) = ‘a’ - ‘b’ x 0.243/cc of filtrate(17) Also in this case, coloured filtrates may be applied.

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10.2.7 Alcalinity, Excess Lime, Pf, Mf, Pm Measurment

Equipment Required:

• 100-150cc pottery or plastic vessel• 1cc pipette• 2cc syringe• 10cc graduated pipette• Glass stirring rod• 10 cc serological (graduated) pipette

Reagents:

• Sulphuric acid, N/50 (0.02 N)• Phenolphthalein indicator solution• Methyl orange (or bromocresol blue)(18) indicator solution

Procedure:

• Pf1) Place 1cc of filtrate into the vessel.2) Add 2-3 drops of phenolphthalein solution.3) If the indicator turns red, add sulphuric acid until the colour disappears (pH

8.3).4) Report as Pf the number of cc of N/50 sulphuric acid required.

• Mf1) To the sample which has been titrate to the Pf end point, add 2-3 drops of

methyl orange (or bromocresol blue).2) Titrate with N/50 sulphuric acid until colour changes (pH 4.3) from yellow to

pink with methyl orange or from violet to yellow with bromocresol blue.3) Report as Mf the total of cc N/50 sulphuric acid required to reach

phenolphthalein (Pf) end point, and methyl orange (Mf) end point.

• Pm1) Place a syringe of 1cc of fluid into the vessel.2) Dilute the sample with 25-50cc of distilled water.3) Add 4-5 drops of phenolphthalein.4) If sample turns red, titrate by adding N/50 sulphuric acid until the colour

disappears (Ph 8.3).5) Report as Pf the number of cc N/50 sulphuric acid required .

Interpretation:

• Alkalinity(19) mg/l of OH CO3 HCO3

Pf = 0 0 0 1220 Mf2Pf < Mf 0 1220Pf 1220 (Mf-2Pf)2Pf = Mf 0 1200Pf 02Pf > Mf 340 (2Pf - Mf) 1200 (Mf-Pf) 0Pf = Mf 340Mf 0 0

• Excess lime: kg/m3 = 0.742 x (Pm - Fw x PF) (20)

lbs/bbl = 0.26 X (Pm - Fw x PF)(18) It is required for deeply coloured filtrates and the colour will change from violet to yellow.(19) Quantity can be measured with Garret Gas train.(20) Fw represents the liquid fraction measured with a retort.

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10.2.8 Excess Gypsum Measurment

Equipment Required:

• 1cc pipette• 5 cc graduated pipette• 100-150cc beaker• Calibrated floating-ball or graduated cylinder: 250 cc• Glass stirring rod• 10cc serological (graduated) pipette

Reagents:

• 0.01 Molar EDTA solution• NaOH drops or solution• Calcium indicator (with calcine or calver II )

Procedures:

1) Place 5cc of filtrate into the ball, dilute to 250cc with distilled water.2) Mix the solution for 15mins.3) Filtrate with an API standard filter press.4) Collect only clear filtrate.5) Place 10cc of filtrate obtained into the beaker.6) Increase pH to 12 by adding NaOH.7) Add calcium indicator (with calcine or calver II).8) Titrate with 0.01 M EDTA until colour changes from green to pink brown in case of

calcine, or from pink to blue in case of calver II.9) Record the volume of EDTA required as ’Vt’.10) Place 1cc of filtrate into the vessel.11) Dilute with 30-40cc of distilled water.12) Increase pH to 12 by adding NaOH.13) Add calcium indicator (with calcine or calver II).14) Titrate with 0.01 M EDTA until colour changes.15) Record as ‘Vf’ the number of cc required .

Results:

• Total gypsum (lbs/bbl) = 2.38 x (Vt)(kg/m3) = 6.78 x (Vt)

• Excess gypsum (lbs/bbl) = 2.38 x (Vt) - 0.48 x (Vf x Fw)(21)

(kg/m3) = 6.78 x (Vt) - 1.37 x (Vf x Fw) (21) Fw represents the liquid fraction measured with a retort.

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10.2.9 Semiquantitative Determination Of Sulphurs (Hatch Test)

Equipment Required:

• The apparatus consists of a sample chamber provided with a holed cap forpositioning the lead acetate paper disks

• Lead acetate paper disks• 25cc graduated cylinder• 5cc graduated syringe.

Reagents:

• Sulphuric acid, N/10• Alkaseltzer (or sodium bicarbonate)• Defoamer.

Procedures:

1) Using the syringe take away 2.5cc of fluid filtrate(24).2) Place the sample into the chamber by diluting with 22.5cc of fresh water.3) Position a lead acetate paper disk on the top cap of the chamber.4) Wet the chamber walls with a film of defoamer.5) Add 1cc of N/10 sulphuric acid.6) Place a tablet of Alkaseltzer (or a bit of sodium bicarbonate(25)).7) Screw the cap containing the lead acetate paper disk.8) Allow the tablet to be completely dissolved.9) Compare the colours of lead acetate paper disk with the hatch colour standards. If

colours are too dark, the test must be repeated with a diluted sample(25) .Results:

• Results are compared against the hatch paper and be multiplied by 10. Values arein mg/l of H2S.

(22) Garret gas train can also be applied for quantitative evaluation.(23) Complete gas kits are available.(24) Soluble sulphurs are determined with filtrate analysis, while total sulphurs with fluid analysis.(25) Coloration is altered if cement is present in fluid. In this case the test may result positive

even in absence of H2S. Calculations of the concentration must be carried out on thedilutions made.

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10.2.10 Fluid Corrosivity Analysis

FLUID CORROSIVITY ANALYSISEQUIPMENT

• Corrosion rings pre-weight 4.5” (AISI 4140)• Drill string

PROCEDURE

• Insert a corrosion ring into the tool joint closest to the drill bit.• Insert rings at halfway and at the top end of the drill string.• To keep in situ at least 40 hrs and max. of 10 days.• Recover the test pieces, dry them off with a cloth.• Notice the original weight and serial number.• For each corrosion ring, record :

1) Phase and depth of the ring.

2) Seria number and original weight.

3) Date and time of installation in the string

4) Date and time of recovery

5) Mud type, pH, Temperature in/out, flow rate.

6) Description of any treatment with corrosion inhibitors.

Send the test pieces to and the report data to: Eni-Agip/Corm

RESULT

• Speed corrosion

lbs/ft3/year mm/year Interpretation

<1 <0.6 Low

1 - 2 0.6 - 1.2 Moderate

2 - 5 1.2 - 3.1 High

>5 > 3.1 Severe

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10.3 OIL BASED FLUIDS

10.3.1 Electrical Stability Determination

Equipment Required:

• Electrical stability meter, 0-200 volt range, optimum operating frequency of 330-350hertz at 1500 volts, 61 microamps of current at emulsion break. Electrode probewith space of 1.59mm (0.061 in.)

• 0-150oC (32-220oF) thermometer• Heating cup• Glass or plastic beaker

Procedure:

1) Place a sample of the filtrated fluid from the screen of the marsh funnel into theheating cup.

2) Heat sample at 50oC (120oF).3) Put the sample into a plastic or glass container.4) Position the electrode probe into the fluid sample.5) Stir the sample with electrode probe for 15-30secs.6) Be sure that the electrode probe is completely covered by the sample. It must not

touch the bottom or sides of the container.7) Push test button and start from zero by rotating the PO tentsionmeter clockwise

with increments of 100-200 v/sec. (Most models start up automatically.)8) Record the ES value displayed on the readout device (which is lit at the passage of

current).9) Record the reading and reset potentiometer.10) Clean the electrode probe with a tissue paper.11) Repeat test and evaluate accuracy. Re-stir the sample for 30secs and repeat from

step 4 to step 9 .Results:

Electrical stability = 2 (reading of potentiometer)(27). (27) Some emulsion testers, i.e. Bariod’s testers, provide the value of electrical stability

directionally.

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10.3.2 Fluid Alkalinity Determination

Equipment:

• Half litre glass jar with lid.• 5cc syringe.• 5cc graduated pipette.• Magnetic stirrer with 38mm stirring bar (1.5in) .

Reagents:

• Xilene/Hysopropanole mixture: 50/50.• Distilled water.• Phenolphthalein.• Sulphuric acid: 0.1 regular (N/10) .

Procedure:

1) Add 100cc xilene/hysopropanole mixture to half litre jar.2) Add 2cc fluid with the syringe.3) Swirl the mixture until it is homogenous.4) Add 200cc distilled water.5) Add 15 drops of phenolphthalein.6) Slowly titrate with 0.1 N sulphuric acid, while stirring rapidly with magnetic stirrer.7) Titrate until red colour just disappears for 1min.8) Let the sample stand for 5mins, if no red colour re-appears, the end point has been

reached.9) If colour reappears, titrate until it disappears again. Repeat steps 6,7,8.10) If a third titration is necessary, call the total value of acid the end point, even if the

colour re-appears a fourth time .Results:

Fluid Alkalinity:

Pom = cc 0.1N sulphuric acid/cc fluid sample.

Pom = cc 0.1N sulphuric acid/2.

Excess Lime:

lbs/bbl = 1.3 Pom.

kg/m3 = 3.7 Pom.

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10.3.3 Fluid Chloride Determination

Equipment Required:

• Half litre glass jar with lid.• 5cc syringe.• 5cc graduated pipette.• 10cc graduated pipette.• Magnetic stirrer with 38mm stirring bar (1.5in) .

Reagents:

• Xilene/Hysopropanole mixture, 50/50.• Distilled water.• Phenolphthalein.• Sulphuric acid: 0.1 regular (N/10).• Potassium chromate indicator.• 0.282N silver nitrate .

Procedure:

1) Lead the alkaline test as indicated in the previous form.2) Be sure acqueous solution pH is less than 7 by adding 1-2 drops of N/10 sulphuric

acid.3) Add 10 to 15 drops of potassium chromate indicator(28).4) While stirring rapidly, slowly titrate with silver nitrate(29).5) When the pink salmon colour stabilises for at least 1min, then the end point has

been reached .Results:

Fluid chloride (mg/l) = 1000 (cc AgNO3 * PM(30) Cl-)/cc fluid sample required.Whole fluid chloride (mg/l) = 10000 (cc AgNO3 0.282N(31))/2.

(28) A further addition of potassium chromate may be required.(29) Rapid stirring is required. It may be necessary, however that the stirring is stopped

to allow separation of the two phases to occur.(30) Pm Cl = PE Cl = 35.45.(31) The normal 0.0282 N reagent is calculated as follows: 1cc AgNO3 equals 10g/l Cl.

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10.3.4 Calcium Determination

Equipment Required:

• Half litre glass jar with lid;• 5cc syringe• 5cc graduated pipette• 10cc graduated pipette• Magnetic stirrer with 38mm stirring bar (1.5in )

Reagents:

• Xilene/Hysopropanole mixture, 50%/50%• Distilled water• 1N hydroxide sodium (NaOH) 1N• Calcium indicator (Calver II)• 0.1M EDTA(32 )

Procedure:

1) Add 100cc of 50/50 xilene/hysopropanol mixture.2) Add 2cc of fluid with syringe.3) Shake vigorously, until the mixture is homogeneous.4) Add 200cc distilled water.5) Add 3cc 1N NaOH.6) Add 0.1 - 0.25gr calcium indicator (Calver II).7) Shake vigorously for 2mins.8) Let the sample stand to allow the separation of the two phases to occur. If a

reddish colour appears in the aqueous phase, calcium is present.9) Place the jar on the magnetic stirrer and drop in the stir bar.10) Titrate with 0.1 M EDTA.11) When the colour changes to blue-green, the end point has been reached.12) Record the number of cc of 0.1M EDTA required .

Results:

Fluid calcium (mg/l) = 1000 (cc EDTA * Normal EDTA PMCa++)/cc of fluidsampleWhole fluid calcium (mg/l) = 1000 (cc EDTA * 0.1 40/2cc

= 4000 (cc EDTA) 2cc(32) This EDTA solution is ten times more concentrated than the solution required for water based

fluids.

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APPENDIX A - DRILLING FLUID CODING SYSTEM

This coding system describes the Eni-Agip drilling fluid coding system currently in use andhow the system can be used for further developments of drilling fluids.

A.1. CODE GROUPS

There are three groups in the system:

1 2 3

• The first grouping represents the base fluid, such as fresh water, sea water,diesel, etc. The base fluid must be included in the full code.

• The second grouping represents the base fluid system, such aslignosulfonate, gels, polymers, invert emulsion, etc. The base system againmust be included.

• The third grouping describes the base system more precisely by providingfurther information: i.e. the water/oil ratio in an invert emulsion, the type of saltin a brine and underlining the specific treatment, such as addition of polymers,soltex, lignosulfonates. The third group is included only if relevant informationis applicable.

If there is one or more special treatments, only the most significant of these will beincluded. For example, DS-IE 80 signifies a diesel base, invert emulsion drilling fluid, witha WO ratio of 80/20. If this drilling fluid is relaxed, the code would be DS-IE RF, as'Relaxed Fluid' is to be considered a more significant characteristic than the W/O ratio.

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A.2. EXAMPLE CODING

Consider the development of a drilling fluid, as follows:

1) The code for sea water fluid with prehydrated bentonite is:

SW GE

2) During drilling, if the fluid is treated with light additions of lignosulfonate, its code willbe:

SW GE LS

3) Again during drilling, the addition of lignosulfonate will characterise the fluid furtherand the code will be:

SW LS

4) Finally, if lubricants are added, the code will be:

SW GE LU

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APPENDIX B - ABBREVIATIONS

B.1. FLUID CODE ABBREVIATIONS

1 2 3

Base Fluid Base System Specific Treatment

AR - Air AR - Air (- -) - Non Specific

FW - Fresh Water AT - Aerated CA - Calcium Carbonate

SW - Sea Water BR - Brine CB - Calcium Bromide

BW - Brine Water CL - Chromelignin CC - Calcium Chloride

DS - Diesel CT - Cationic Polymers CL - Chromelignin

LT - Low Toxicity Oil DE - Modified Tannins (Desco) KA - Potassium Acetate

EB - Ester DF - Drilling Fluid KB - Potassium Base (KOH)

OF - Poltolefine GE - Bentonite-Base KC - Potassium Chloride

UT - Olio Ultra LT GG - Guar Gum KF - Potassium Formiate

GL - Glycol-Base GL - Glycol-Base

GY - Gypsum-Base LI - Lime

HT - High Temperature LS - Lignosulfonate

IE - Invert Emulsion LU - Lubricants

K2 - Potassium Carbonate NC - Sodium Chloride

KA - Potassium Acetate NB - Sodium Bromide

KC - Potassium Chloride PA - Polyanionic Pol.(PAC)

KF - Potassium Formiate PN - Na Polyacrylates

LI - Lime-Base PC - PHPA

LS - Lignosulfonate-Base PK - Agipak (K-CMC/PAC)

LW - Low-Solids PO - Generic Polymers (CMC)

MM - Mud-Misting RF - Relaxed Filtrate

MR - Morex-Base RM - Rheology Modifiers

OB - Oil Base RX - Ht Pol. Mixtures

PA - Polyanionic Pol.(PAC) SX - Soltex

PC - PHPA TA - Tannins

PK - Agipak (K-PAC, K-CMC) XC - XCD Polymer

PO - Generic Polymers (CMC) VB - Viscosity Base

QU - Quebracho-Base ZB - Zinc Bromide

SF - Foam-Base

SS - Salt Saturated (NaCl)

XC - XCD Polymer

NOTE: The oil/water ratio of a fluid with an oil numeric value, such as O/W =70/30, will be expressed only by the first ratio, i.e. 70, omitting the later30 ratio.

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B.2. OTHER ABBREVIATIONS

AC - Antiscale

AF - Antifoam

B - Bactericide

C - Chelant

CC - Diesel

CI - Low Toxicity Oil

E - Ester

F - Poltolefine

FP - Olio Ultra LT

FR - Filtrate Reducer

LC - Loss Circulation Material

LU - Lubricant

P - Primary

pH - pH Control

S - Secondary

S - Solvent

SA - Suspension Agent

SH - Shale Stabiliser

SU - Surfactant

TH - Thinner

TR - Tracer

TS - Temperature Stability Agent

V - Viscofier

W - Weighting Material

Drilling Fluids Operations Manual

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