drilling fluids operations manual
DESCRIPTION
BookTRANSCRIPT
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
ENI S.p.A.Agip Division
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 3 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 4 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 5 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 6 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 7 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 8 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 9 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 10 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 11 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 12 OF 155
REVISIONSTAP -P-1-M-6160 0
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)
Oil-Base DS-IE AVOIL Invermul Interdril Versadril Carbotec
2.2.6 Drilling Fluids For Temperatures Greater Than 200 oC
Oil-Base DS-IE AVOIL Invermul Interdril Versadril Carbotec
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 13 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S
.p.A.
Ag
ip D
ivision
IDE
NT
IFIC
AT
ION
CO
DE
PA
GE 14 O
F 155
RE
VIS
ION
ST
AP
-P-1-M
-61600
2.3 C
HA
RA
CT
ER
IST
ICS
OF
TH
E F
LUID
SY
ST
EM
The level of solids rem
oval equipment as indicated in the ‘D
escription of Fluid S
ystems’
refers to the equipment recom
mended in section 5.
sea
wat
er
die
sel
fres
h w
ater
LT
oil
alte
rnat
ive
oil
non
-dis
pers
ed
dis
pers
ed
cut
ting
inhi
bitio
n
form
atio
n in
hibi
tion
LG
S to
lera
nce
mai
nt. d
iffer
ence
logi
sti d
iffer
ence
con
vert
ible
re-
use
tem
pera
ture
den
sity
lubr
ican
t pro
pert
ies
sol
ids-
rem
oval
eq.
CU
TT
ING
S
MU
D
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
ARPO
ENI S
.p.A.
Ag
ip D
ivision
IDE
NT
IFIC
AT
ION
CO
DE
PA
GE 15 O
F 155
RE
VIS
ION
ST
AP
-P-1-M
-61600
The level of solids rem
oval equipment as indicated in the ‘D
escription of Fluid S
ystems’
refers to the equipment recom
mended in section 5.
sea
wat
er
die
sel
fres
h w
ater
LT
oil
alte
rnat
ive
oil
non
-dis
pers
ed
dis
pers
ed
cut
ting
inhi
bitio
n
form
atio
n in
hibi
tion
LG
S to
lera
nce
mai
nt. d
iffer
ence
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.
CU
TT
ING
S
MU
D
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 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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 16 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 17 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 18 OF 155
REVISIONSTAP -P-1-M-6160 0
2.7 WATER-BASED FLUIDS
2.7.1 Optimum Values Of Marsh Viscosity, Solids And Gel
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 19 OF 155
REVISIONSTAP -P-1-M-6160 0
2.7.2 Optimum Values Of Plastic Viscosity And Yeld Point
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 20 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 21 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 22 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 23 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
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
MIXING TIME: +/- 30 m /hr
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
.)
CHARACTERISTICS OF THE DRILLING FLUID
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 24 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 25 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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
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)
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
.)
CHARACTERISTICS OF THE DRILLING FLUID
1.03 1.15
40 80
5
15
4
15
2
4
8
15
10
2
8.5
9.5
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 26 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 27 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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
.)
CHARACTERISTICS OF THE DRILLING FLUID
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 28 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 29 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
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
.)
CHARACTERISTICS OF THE DRILLING FLUID
1.1 2.1
38 60
5
45
2
12
1
2
5
15
10
2
9.5
10.5
ADVANTAGES AND LIMITATIONS
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 30 OF 155
REVISIONSTAP -P-1-M-6160 0
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
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 31 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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
.)
CHARACTERISTICS OF DRILLING FLUIDS
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 32 OF 155
REVISIONSTAP -P-1-M-6160 0
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
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 33 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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
.)
CHARACTERISTICS OF THE DRILLING FLUIDS
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 34 OF 155
REVISIONSTAP -P-1-M-6160 0
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
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 35 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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
.)
CHARACTERISTICS OF THE DRILLING FLUID
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 36 OF 155
REVISIONSTAP -P-1-M-6160 0
CONTAMINANTS REMEDIAL
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 37 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 38 OF 155
REVISIONSTAP -P-1-M-6160 0
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
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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
.)
CHARACTERISTICS OF THE DRILLING FLUID
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 39 OF 155
REVISIONSTAP -P-1-M-6160 0
CONTAMINANTS REMEDIAL
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 40 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
CO
ST
O
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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
ctri
cal s
tabi
lity.
(vo
lt) M
BT
(Kg/
m e
quiv
.)
CHARACTERISTICS OF THE DRILLING FLUID
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 41 OF 155
REVISIONSTAP -P-1-M-6160 0
CONTAMINANTS REMEDIAL
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 42 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
FORMULATION PRODUCT kg-l/m
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
.)
CHARACTERISTICS OF THE DRILLING FLUID
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 43 OF 155
REVISIONSTAP -P-1-M-6160 0
MAINTENANCE
CONTAMINANTS REMEDIAL
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 44 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
CO
ST
O
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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
Exc
ess
lime
(kg/
m3)
Ele
ctric
al S
tabi
lity
(vol
t) M
BT
(kg/
m e
quiv
.)
CHARACTERISTICS OF THE DRILLING FLUID
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 45 OF 155
REVISIONSTAP -P-1-M-6160 0
CONTAMINANTS REMEDIAL
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 46 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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
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
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 47 OF 155
REVISIONSTAP -P-1-M-6160 0
CONTAMINANTS REMEDIAL
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 48 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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
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 FLUID
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 49 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 50 OF 155
REVISIONSTAP -P-1-M-6160 0
3.3 OIL BASED FLUID
This section contains descriptions of the oil based fluids systems, their applications andlimitations.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 51 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
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
DESCRIPTION AND APPLICATION
ADVANTAGES AND LIMITATIONS
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 52 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 53 OF 155
REVISIONSTAP -P-1-M-6160 0
)
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
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
CHARACTERISTICS OF THE DRILLING FLUID @ 120 °F
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
ADVANTAGES AND LIMITATIONS
- 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.
DESCRIPTION AND APPLICATION
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 54 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
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 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
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
DESCRIPTION AND APPLICATION
ADVANTAGES AND LIMITATIONS
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 55 OF 155
REVISIONSTAP -P-1-M-6160 0
3.4 INHIBITED AND/OR ENVIRONMENTAL FLUIDS
This section contains descriptions of inhibited and environmentally friendly fluid systems,their applications and limitations.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 56 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
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
.)
CHARACTERISTICS OF THE DRILLING FLUID
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
DESCRIPTION AND APPLICATION
ADVANTAGES AND LIMITATIONS
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 57 OF 155
REVISIONSTAP -P-1-M-6160 0
CONTAMINANTS REMEDIAL
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 58 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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 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
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 59 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 60 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
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
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 FLUID
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
DESCRIPTION AND APPLICATION
ADVANTAGES AND LIMITATIONS
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 61 OF 155
REVISIONSTAP -P-1-M-6160 0
CONTAMINANTS REMEDIAL
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 62 OF 155
REVISIONSTAP -P-1-M-6160 0
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
FORMULATION PRODUCT kg-l/m
MIXING TIME:
ADVANTAGES AND LIMITATIONS
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
.)
CHARACTERISTICS OF THE DRILLING FLUID
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 63 OF 155
REVISIONSTAP -P-1-M-6160 0
CONTAMINANTS REMEDIAL
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 64 OF 155
REVISIONSTAP -P-1-M-6160 0
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
DESCRIPTION OF THE SYSTEM CODICE AGIP
DESCRIPTION AND APPLICATION
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
(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
ADVANTAGES AND LIMITATIONS
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 65 OF 155
REVISIONSTAP -P-1-M-6160 0
CONTAMINANTS REMEDIAL
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 66 OF 155
REVISIONSTAP -P-1-M-6160 0
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
DESCRIPTION OF THE SYSTEM AGIP CODE
DESCRIPTION AND APPLICATION
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 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
ADVANTAGES AND LIMITATIONS
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 67 OF 155
REVISIONSTAP -P-1-M-6160 0
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
- ADD. WETTING AGENT
-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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 68 OF 155
REVISIONSTAP -P-1-M-6160 0
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
DESCRIPTION OF THE SYSTEM AGIP CODE
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.
DESCRIPTION AND APPLICATION
ADVANTAGES AND LIMITATIONS
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 69 OF 155
REVISIONSTAP -P-1-M-6160 0
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 - - - - - = + - -
- ADD. WETTING AGENT
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 70 OF 155
REVISIONSTAP -P-1-M-6160 0
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
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
Cos
t
DESCRIPTION OF THE SYSTEM AGIP CODE
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 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
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
DESCRIPTION AND APPLICATION
ADVANTAGES AND LIMITATIONS
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 71 OF 155
REVISIONSTAP -P-1-M-6160 0
BASE FLUID CHARACTERISTICS OF THE SYSTEM ENV.
DESCRIPTION OF THE SYSTEM AGIP CODE
FORMULATION PRODUCT Kg-l/m
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
CHARACTERISTICS OF THE DRILLING FLUID @ 120 °F
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
DESCRIPTION AND APPLICATION
ADVANTAGES AND LIMITATIONS
- 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 72 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 73 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 74 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 75 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 76 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 77 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 78 OF 155
REVISIONSTAP -P-1-M-6160 0
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
Pre-treatment30kg/m3
Ironite Sponge
1.35gr/1grH2S
Pre-treatment30kg/m3
Ironite Sponge
1.35gr/1grH2S
Pre-treatment30kg/m3
Ironite Sponge
1.35gr/1grH2S
Pre-treatment30kg/m3
Zinc Carbonate Zinc Carbonate
5gr/1grH2S
Pre-treatment5-8kg/m3
Zinc Carbonate
5gr/1grH2S
Pre-treatment5-8kg/m3
Zinc Carbonate
4gr/1grH2S
Pre-treatment4-8kg/m3
Zinc Carbonate
5gr/1grH2S
Pre-treatment5-8kg/m3
Mil-Gard
6gr/1grH2S
Pre-treatment6-9kg/m3
*Zinc Chelate(liquid)
Coat-RD
20gr/1grH2S
Pre-treatment5-10kg/m3
IDZAC L
13gr/1grH2S
Pre-treatment14-29kg/m3
SV-120
13gr/1grH2S
Pre-treatment3-6kg/m3
*Zinc Chelate(powder)
IDZAC L
8gr/1grH2S
Pre-treatment14-23kg/m3
Fer-Ox Milgard R
19gr/1grH2S
Pre-treatment23-24kg/m3
Zinc Oxide(Polvere)
Oxide Zinc
2.3gr/1grH2S
Pre-treatment3-6kg/m3
Sulf-X
2.3gr/1grH2S
Pre-treatment3-6kg/m3
Zinc Mixture No-Sulf
Pre-treatment5-15kg/m3
Oil DispersantScavenger
SOS 200
14gr/1grH2S
Pre-treatment6-12kg/m3
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 79 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 80 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 81 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 82 OF 155
REVISIONSTAP -P-1-M-6160 0
Effect On Fluid Problems Cause Remedial Actions
• 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 83 OF 155
REVISIONSTAP -P-1-M-6160 0
Effect On Fluid Problems Cause Remedial Actions
• 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 84 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 85 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 86 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 87 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 88 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 89 OF 155
REVISIONSTAP -P-1-M-6160 0
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'
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 90 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 91 OF 155
REVISIONSTAP -P-1-M-6160 0
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"
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 92 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 93 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 94 OF 155
REVISIONSTAP -P-1-M-6160 0
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...
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 95 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 96 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 97 OF 155
REVISIONSTAP -P-1-M-6160 0
Treatment Formulation Operat ional Remarks
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 98 OF 155
REVISIONSTAP -P-1-M-6160 0
6.4.2 Loss Of Circulation With Oil Based Fluids
Treatment Formulation Operat ional Remarks
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 99 OF 155
REVISIONSTAP -P-1-M-6160 0
Treatment Formulation Operat ional Remarks
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)
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 100 OF 155
REVISIONSTAP -P-1-M-6160 0
Treatment Formulation Operat ional Remarks
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)
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 101 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 102 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 103 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 104 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 105 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 106 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 107 OF 155
REVISIONSTAP -P-1-M-6160 0
Code Description AVA Bariod Dowell MI BH Inteq
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 108 OF 155
REVISIONSTAP -P-1-M-6160 0
Code Description AVA Bariod Dowell MI BH Inteq
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 109 OF 155
REVISIONSTAP -P-1-M-6160 0
Code Description AVA Bariod Dowell MI BH Inteq
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 110 OF 155
REVISIONSTAP -P-1-M-6160 0
Code Description AVA Bariod Dowell MI BH Inteq
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
0601 PrimaryEmulsifiers
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 111 OF 155
REVISIONSTAP -P-1-M-6160 0
Code Description AVA Bariod Dowell MI BH Inteq
System Name AVA Core Baroid 100 Trudrill Versacore Carbo-Core
0601 PrimaryEmulsifiers
EZ Core Trumul Versamul Carbo-Tec
0602 SecondaryEmuls.
AVAOIL-SE Trusperse Carbo-Mull
0603 Wetting Agents AVAOIL-WA Trusperse Versa SWA
0605 OrganophilClays
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
0601 PrimaryEmulsifiers
AVABIO PRI. EZ Mul NTF Ultimul Novatec-P
0602 SecondaryEmuls.
AVABIO Sec. Ultimul II Novatec-S
0603 Wetting Agents AVABIO Wet Ultisperse Novawet
0605 OrganophilClays
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 112 OF 155
REVISIONSTAP -P-1-M-6160 0
Code Description AVA Bariod Dowell MI BH Inteq
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 113 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 114 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 115 OF 155
REVISIONSTAP -P-1-M-6160 0
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 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 116 OF 155
REVISIONSTAP -P-1-M-6160 0
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
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 XX 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
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 117 OF 155
REVISIONSTAP -P-1-M-6160 0
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
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
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 118 OF 155
REVISIONSTAP -P-1-M-6160 0
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
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 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 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 119 OF 155
REVISIONSTAP -P-1-M-6160 0
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 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
RY
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 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
LO
V
D
TE FI
FI SUSU
LUFI
SHV
SU
VTH
SU
FIFI
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 120 OF 155
REVISIONSTAP -P-1-M-6160 0
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-
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
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
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 121 OF 155
REVISIONSTAP -P-1-M-6160 0
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 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 122 OF 155
REVISIONSTAP -P-1-M-6160 0
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
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
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 X XX X X X X X XX X X X X 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 123 OF 155
REVISIONSTAP -P-1-M-6160 0
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
-BA
SE
LOW
SO
LID
S
SA
LT
SA
TU
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
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 XX X X X X X XX X X X X X X
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 124 OF 155
REVISIONSTAP -P-1-M-6160 0
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
-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
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 125 OF 155
REVISIONSTAP -P-1-M-6160 0
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
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
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
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 XX 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 126 OF 155
REVISIONSTAP -P-1-M-6160 0
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
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 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 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 127 OF 155
REVISIONSTAP -P-1-M-6160 0
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
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
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 128 OF 155
REVISIONSTAP -P-1-M-6160 0
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
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
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 129 OF 155
REVISIONSTAP -P-1-M-6160 0
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
RALLAPPLICATION 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
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
THERMA-BUFFTHERMA -CHEK
THERMA-CHEK LV THERMA-THINTHERMA-THIN DP
THERMA-VIS
X X X X X XX 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
TEFI
FI THTH
V FI
SHALE-CHEKSI-10006-UP
SP-101
SPERSENESPERSENE CF
STABIL HOLESTABILITE
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 XX 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 XX X 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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 130 OF 155
REVISIONSTAP -P-1-M-6160 0
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
PRODUCTS 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
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 131 OF 155
REVISIONSTAP -P-1-M-6160 0
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
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
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 132 OF 155
REVISIONSTAP -P-1-M-6160 0
10. DRILLING FLUID ANALYSIS
The contents of this section comply with specification API RP 13B-1 dated June 1st,1990.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 133 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 134 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 135 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 136 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 137 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 138 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 139 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 140 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 141 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 142 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 143 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 144 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 145 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 146 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 147 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 148 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 149 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 150 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 151 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 152 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 153 OF 155
REVISIONSTAP -P-1-M-6160 0
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
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 154 OF 155
REVISIONSTAP -P-1-M-6160 0
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.
ARPO
ENI S.p.A.Agip Division
IDENTIFICATION CODE PAGE 155 OF 155
REVISIONSTAP -P-1-M-6160 0
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