Water Base Drilling Fluids Products Systems

Water Base Drilling Fluids Products & Systems

DRILLING FLUID SYSTEMS • Water Based Drilling Fluids

(Two phase)

• Emulsion Drilling Fluids (NAF) (Three phase) • Oil Base Muds • Synthetic Base Muds • Linear Paraffins

• Reservoir Drill-in Fluids (Two or Three phase)

2

Copyright ©2001-2012 NExT. All rights reserved

WATER BASE DRILLING FLUIDS COMPONENTS OF WATER BASE MUDS

Water

Solids

Soluble Chemicals

Fresh Water

3

Necessary Solids

Drilled Solids

Sea Water

Salt Enhanced Water

Low Gravity

High Gravity

Reactive

Inert

Chlorides Calcium Magnesium

Chlorides Calcium Potassium

Commercial Clays Polymers Chemicals

Weight Material

Smectite Clays Contaminants

MISC.

Copyright ©2001-2012 NExT. All rights reserved

WATERBASE MUD SYSTEMS • Many types of water-base systems… WHY? • More than one system typically used when drilling the same well • Basic systems usually converted to complex systems : • as a well deepens • as wellbore temperatures and/or pressures increase • as formations dictate

4

Copyright ©2001-2012 NExT. All rights reserved

WATER-BASE DRILLING FLUIDS GENERAL CLASSIFICATIONS • Un-weighted clay water suspensions • Deflocculated, weighted clay-water suspensions • Calcium treated, weighted deflocculated clay-water suspensions • Salt water systems • HTHP Deflocculated Systems • Polymers Systems • HTHP Polymer Systems • Cationic Systems

5

Copyright ©2001-2012 NExT. All rights reserved

FACTORS AFFECTING DRILLING FLUID SELECTION • Drilling Data

– Depth – Hole Size – Hole Angle – Torque/Drag – Anticipated R.O.P. – Maximum Expected Mud Weight – Temperature Expected – Others...? 6

Copyright ©2001-2012 NExT. All rights reserved

FACTORS AFFECTING DRILLING FLUID SELECTION • POTENTIAL PROBLEMS • Shale Problems • Bit/BHA Balling • Loss Circulation • Depleted Sands • Stuck Pipe

7

Copyright ©2001-2012 NExT. All rights reserved

PV, YP vs MUD WT ppg PV & YP v. Mud Wt, lbs/gal 50 Max Recommended PV

Plastic Viscosity, Yield Point & MBT

45 40 35 30 25

Max Recommended MBT

20 15

Max Recommended YP

10 5 0 9

10

11

12

13

14

15

16

Mud Weight, lbs/gal

8

Copyright ©2001-2012 NExT. All rights reserved

17

18

19

20

21

UNWEIGHTED CLAY-WATER SUSPENSION • Used to spud (begin) a well • Basically Bentonite and water • Native Mud - Bentonite incorporated with drilled solids from the formation… some formations are bentonitic in nature and increase viscosity... OK?

9

Copyright ©2001-2012 NExT. All rights reserved

UNWEIGHTED CLAY-WATER SUSPENSION • System usually converted to a more complex system prior to reaching critical formation • Drilled solids should be maintained at low values with solids control equipment to prevent excessive dilution before converting to complex system • Low buoyancy effect on cuttings • Hole cleaning depends primarily on viscosity

10

Copyright ©2001-2012 NExT. All rights reserved

UNWEIGHTED CLAY-WATER SUSPENSION • Plastic Viscosity naturally low since solids content is low • Higher Yield Points required due to low Plastic Viscosity • Chemical deflocculants should be avoided since they reduce YP. (if possible)

11

Copyright ©2001-2012 NExT. All rights reserved

UNWEIGHTED CLAY-WATER SUSPENSION • Typical Properties: • • • • • • • • • • •

12

Density: FV PV YP Gels pH Pf/Pm Solids Fluid Loss Calcium Chlorides

Copyright ©2001-2012 NExT. All rights reserved

8.8-10.0 ppg 36-55 sec/qt 5-9 cps 12-25 lb/100 ft2 5-10 / 10-20 lb/100 ft2 8.5-9.0 0.1-0.5 / 0.1-0.8 cc’s 3-10 percent as needed 220± mg/l 0-5000± mg/l (fresh water) 20,000± mg/l (seawater)

UNWEIGHTED CLAY-WATER SUSPENSION Typical Products

Primary Function

Bentonite (M-I GEL)® Caustic Soda Lignite (TANNATHIN)® POLYPAC ® */CMC* MY-LO-JEL ® POLYSAL ® POLYPLUS ® S.A.P.P THERMPAC UL ® Barite (M-I BAR)® *POLYPAC UL ®/CMC-LV

viscosity / fluid loss control pH / Pf / Pm thinner / fluid loss control viscosity / fluid loss control fluid loss control fluid loss control Bentonite extender thinner @ low temp. fluid loss control increase density fluid loss control only

13

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS CHEMICAL NAME

14

M-I SWACO NAME

FUNCTION

1.

Caustic Soda (NaOH)

Caustic Soda

Increase pH

2.

Caustic Potash (KOH)

Caustic Potash

Incr pH and K+

3.

Lime (CaOH2)

Lime

Incr pH and Ca2+

4.

Gyp / Anhydrite (CaSO4)

Gypsum

Ca2+ source

5.

Bicarb. (NaHCO3)

Bicarb.

Treat Cement

6.

Soda Ash (Na2CO3)

Soda Ash

Treat Hardness (Ca2+, Mg2+)

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS 7.

Sodium Acid

SAPP

Top hole thinner

Pyrophosphate

15

8.

Citric Acid

Citric Acid

Decrease pH, treat cmt

9.

Sodium Chloride (NaCl)

Sod. Chloride

Increase Cl- (WBM)

10. Calcium Chloride (CaCl2)

Calc. Chloride

Incr Cl- (OBM / SBM)

11. Potassium Chloride (KCl)

Pot. Chloride

Increase Cl- and K+

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS WEIGHTING MATERIALS: BARITE Barium Sulfate (BaSO4) SG 4.2

M-I BAR

Increase Mud Density

HEMATITE Ferris Oxide (Fe2O3) SG 5.0

FER-OX

Increase Mud Density

CALC CARBONATE (CaCO3)

SAFECARB

Increase Mud Density,

LO WATE

LCM

SG = 2.6 - 2.8

16

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS CLAYS:

17

API BENTONITE

M-I GEL

Increase Viscosity, Decrease FL

BENTONITE

M-I GEL SUPREME

Increase Viscosity, Decrease FL (Non-Treated)

ATTAPULGITE

SALT GEL

Increase Viscosity

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS THINNER / DEFLOCCULANTS AND FLC PRODUCTS:

18

1. Lignite

TANNATHIN

FLC, Deflocculant

2. Chrome Lignosulfonate

SPERSENE

Deflocculant

3. Lignosulfonate

SPERSENE CF

4. Causticised Chrome Lignite

XP-20

Chrome Free Deflocculant (env) HT FLC, Thinner

5. Resin treated Lignite

RESINEX

HT FLC

6. Synthetic Resin (liquid)

THERMEX

HT FLC (env)

7. Potassium Lignite

K-17

FLC and K+

8. Sodium Polyacrylate

SP-101

HT FLC

9. Polyacrylate (Low MW)

TACKLE

Thinner

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS POLYMERS: PHPA Partially Hydrolyzed Polyacrylamide Polymer

PAC

POLY-PLUS RD, ULTRACAP

Encapsulation

ULTRAHIB

Clay hydration suppressant

POLYPAC

FLC and Viscosity

POLYPAC UL POLYPAC ELV CMC

FLC FLC FLC and Viscosity

MY-LO-JEL

FLC

Poly Anionic Cellulose

PAC ultra low PAC extra low CMC Carboxy Methyl Cellulose

Corn Starch

19

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS 8.

20

Potato Starch

POLY SAL

FLC

9. Carboxy Methyl Starch

THERMPAC UL

FLC

10. XCD (Biopolymer)

DUO-VIS

Increase LSRV

11. Starch derivative

FLO-TROL

FLC

12. Clarified Biopolymer

FLO-VIS

Increase LSRV

13. Bentonite extender

GELEX

Increase viscosity

14. Clay Flocculant

FLOXIT

Flocculate clays

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS SHALE CONTROL:

21

1. Shale Inhibitor

ASPHASOL

Shale Inhibitor, FLC

2. Shale Inhibitor

STABLE HOLE

Shale Inhibitor, FLC

3. Shale Control

GLYDRIL-(GP,LC,MC,HC)

Shale Control, FLC

4. Shale Control

SHALE CHEK

Shale Control

5. Shale Control

K-52

K+ Source

6. Shale Control

KLA CURE

Shale Control

7. Shale Control

KLA GARD

Shale Control

8. Shale Control (Cl- free)

KLA GARD-B

Shale Control

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS CORROSION INHIBITORS:

22

1. Water dispersible blended amine

CONQOR 101

FW Packer fluids

2. Persistent filming amine

CONQOR 202-B

Wipe on pipe, slug treatment

3. Brine soluble filming amine

CONQOR 303-A

Pkr. fluids, Clear brines (no Zn)

4. Phosphorus based Corr. inhibitor

CONQOR 404

Corr. prev. in Drilling Fluids

5. 55% Ammonium Bisulfite

OS-1L

Oxygen Scavenger

6. Scale Inhibitor

SI-1000

Inhibits scale formation

7. 12% Zn (liquid)

SV-120

Low Conc. H2S Scavenger

8. Zinc Oxide

ZnO

H2S Scavenger

9. 25% Gluteraldehyde

X-Cide102/ Greencide 25-G

Bactericide

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS SPECIALTY PRODUCTS:

23

1. Detergent for clean-up OBM/SBM

CLEAN-UP

Rig Clean-up OBM/SBM

2. Drilling Detergent

D.D.

Surfactant Emulsifier

3. Alcohol-base de-foamer

DEFOAM-A

De-foam Mud

4. Silicone-base de-foamer

DEFOAM-X

De-foam Mud

5. Low toxicity detergent additive

DRIL-KLEEN

Prevent Bit and BHA balling

6. Low toxicity Lubricant

LUBE-100

ENV. lubricant, HTHP FLC

7. All purpose lubricant (ENV)

LUBE-167

Decr. COF reduce torque/drag

8. Graphite plugging agent

G-SEAL (C)

Cure LC, (torque/drag/FLC)

9. LCM Blend

M-I SEAL (F,M)

Cure Lost Circulation

Copyright ©2001-2012 NExT. All rights reserved

PRODUCTS AND THEIR APPLICATIONS SPECIALTY PRODUCTS: 10. Ground Mica

MICA (F,C)

Cure lost Circulation

11. Fibrous plugging and bridging agent 12. Ground nut hulls

M-I-X II (F,M,C)

Plug / Bridge perm. form.

NUT PLUG (F,M,C)

Cure Lost Circulation

13. OB-Stuck Pipe freeing surfactant

PIPE LAX

Free Stuck Pipe

14. ENV-Stuck Pipe spotting fluid

PIPE LAX (ENV)

Free Stuck Pipe (ENV)

15. One Drum Stuck Pipe Spotting fluid

PIPE LAX-W (Export)

Free Stuck Pipe

16.

ULTRAFREE

Accretion inhibitor and ROP enhancer

24

Accretion inhibitor and ROP enhancer

Copyright ©2001-2012 NExT. All rights reserved

SPERSENE® SYSTEMS •One of the most common drilling fluids used in the industry. Dispersed. •Primary product -SPERSENE® (lignosulfonate - contains chrome) an organic acid which supplies anions (negative ions) which reduce the YP and Gel strengths by neutralizing cations (positive ions) on the clay particles •System requires an alkaline environment to solubilize the SPERSENE ® •Caustic Soda or Lime used to increase pH to a minimum of 9.5

25

Copyright ©2001-2012 NExT. All rights reserved

SPERSENE® SYSTEMS

26

Typical Products

Primary Function

M-I BAR ® M-I GEL ® Caustic Soda SPERSENE ® TANNATHIN ® POLYPAC ® */CMC* MY-LO-JEL ® POLYSAL ® POLYPLUS ®

increase density viscosity/fluid loss pH/Pf/Pm thinner/fluid loss fluid loss/thinner viscosity/fluid loss fluid loss control fluid loss control bentonite extender

Copyright ©2001-2012 NExT. All rights reserved

SPERSENE® SYSTEMS

27

Typical Products

Primary Function

S.A.P.P THERMPAC UL ® RESINEX ® THERMEX™ Lime Gyp *POLYPAC UL ®/CMC-LV

Thinner (low temp < 93°C) Fluid loss HTHP fluid loss HTHP fluid loss Treat out CO3 Treat out CO3 Fluid loss only

Copyright ©2001-2012 NExT. All rights reserved

SATURATED SALT SYSTEM •System designed to prevent hole enlargement while drilling salt section, preventing salt from dissolving into the fluid’s water phase •Built by adding salt (sodium chloride) until system reaches saturation point •NaCl system saturation point :190,000± mg/l chlorides. •Some operators increase chlorides to slightly above 100,000 mg/l if the salt section is not very thick, reducing solubility rate and hole enlargement. 28

Copyright ©2001-2012 NExT. All rights reserved

SATURATED SALT SYSTEM •TO CONVERT AN EXISTING SYSTEM: • On initial break-over, add the following as fast as possible: • 2 - 3 ppb Caustic Soda • 1 - 2 ppb Soda Ash • 4 - 6 ppb SPERSENE® • 110-125 ppb Salt (Amount depends on salt concentration prior to break over.) NOTE: The salt flocculates reactive clays, increasing viscosity. For this reason, clay solids should be minimized before and during conversion.

29

Copyright ©2001-2012 NExT. All rights reserved

SATURATED SALT SYSTEM Typical Products M-I BAR® M-I GEL®(pre-hydrated) Caustic Soda Salt SPERSENE® Soda Ash POLYPAC® CMC DUO-VIS™ MY-LO-JEL® POLYSAL® SURFAK M® SP-101®

30

Copyright ©2001-2012 NExT. All rights reserved

Primary Function increase density viscosity & FL pH/Pf/Pm increase chlorides thinner control Ca2+ < 200 mg/l stability/fluid loss stability/fluid loss low shear rate viscosity fluid loss fluid loss surface acting agent HTHP fluid loss

POTASSIUM SYSTEMS Potassium chloride system : •Used to stabilize water-sensitive shales by potassium ion inhibition •Minimizes shale hydration, which minimizes hole enlargement, bit and stabilizer balling, sloughing shale and permeability reduction in productive zones •Uses potassium chloride (KCl) as the primary potassium source

31

Copyright ©2001-2012 NExT. All rights reserved

POTASSIUM SYSTEMS

32

Typical Properties

Old Formation

Young Formation

Density PV YP Initial Gels 10 Min. Gels MBT Fluid Loss Potassium Calcium pH LGS

as required see PV/YP Graph 20-30 lb/100 sq ft 5-10 lb/100 sq ft 15-20 lb/100 sq ft 5-15 ppb 10-15 cc’s 15K – 25K mg/l <200 mg/l 9.5-10.0 2-4 %

as required see PV/YP Graph 20-30 lb/100 sq ft 10-15 lb/100 sq ft 15-20 lb/100 sq ft 10-20 ppb 5 -10 cc’s 55K-100K mg/l <200 mg/l 10.0-10.5 3-5%

Copyright ©2001-2012 NExT. All rights reserved

POTASSIUM SYSTEMS Typical Products

Old Formation

Young Formation

Primary Function

KCl POLY-PLUS® M-I GEL®

10-15 ppb 0.5-.75 ppb 8-10 ppb

35-70 ppb .25-.5 ppb -----------

0.5 ppb 0.5-1.0 ppb 0.5-1.0 ppb 0.5 ppb as required fresh water

0.5-1.5 ppb 0.5-1.0 ppb 0.75-1.5 ppb 0.5 ppb as required seawater

inhibition inhibition vis. & wall cake viscosity fluid loss pH & K+ control Ca2+ density dilution

( pre-hydrated)

DUO-VIS ™ POLYPAC ® KOH Soda Ash M-I BAR Water 33

Copyright ©2001-2012 NExT. All rights reserved

K - MAG SYSTEM System is designed to provide : •Formation inhibition •Wellbore stability •Improved production by potassium inhibition, in areas where KCl systems are not environmentally acceptable due to high potassium chloride concentration

34

Copyright ©2001-2012 NExT. All rights reserved

K - MAG SYSTEM Potassium sources: K-17 ® (potassium lignite) XP-20 ® (KOH chrome lignite) K-52 ® (potassium acetate) Caustic Potash (KOH) K-MAG system designed for freshwater or seawater

35

Copyright ©2001-2012 NExT. All rights reserved

K - MAG SYSTEM Typical Properties: Density FV PV YP Initial Gels 10 Min. Gels MBT Fluid Loss Potassium Calcium pH Pm Pf Chlorides LGS 36

Copyright ©2001-2012 NExT. All rights reserved

10.0 ppb + (3.5) (Mud Wt.) ± see PV/YP Graph see PV/YP Graph 1-5 lb/100 sq ft 1 - 10 lb/100 sq ft <25 ppb as required 1,000 - 10,000 mg/l 0 - 300 mg/l 9.5-10.5 1.0 - 1.8 cc’s 0.5 - 0.8 cc’s 0 - 20,000 mg/l 4- 5 %

K - MAG SYSTEM

37

Typical Products:

Primary Function

M-I BAR FER-OX  M-IGEL  (pre-hydrated) K-17 XP-20 KOH K-52 POLY-PLUS POLYPAC THERMPAC U.L. THERMEX™ RESINEX DUO-VIS™ SHALE-CHEK 

increase density increase density viscosity & FL fluid loss/thinner & K+ source fluids loss/thinner & K+ source pH, Pf, & K+ source K+ source shale stabilization viscosity & FL fluid loss HPHT fluid loss HPHT fluid loss low shear rate viscosity shale stabilization

Copyright ©2001-2012 NExT. All rights reserved

DURATHERM SYSTEM Designed to drill in high temperature, high pressure environments Stable in presence of contaminants such as calcium, salts, and acid gases Used at temperatures > 500°F due to low clay solids content and chemicals stable at high temperatures

38

Copyright ©2001-2012 NExT. All rights reserved

DURATHERM SYSTEM Clays solids content (bentonite) reduced as density and temperatures increase. Polymeric materials replace bentonite for viscosity and gel strengths. Convert most water base systems by using XP-20 instead of SPERSENE, reducing clay solids, and using CMC or POLYPAC for viscosity and solids suspension. THERMEX™ or RESINEX used for high temperature-high pressure fluid loss 39

Copyright ©2001-2012 NExT. All rights reserved

DURATHERM SYSTEM Proper solids control absolutely necessary Monitor fluid carefully for temperature stability. Can be done by heat aging daily at 25°F above estimated BHT. ids content and When using closed-loop solids control unit with this system, monitor solids particle size (PSD) and PV closely, controlling within proper range by opening up the loop as needed to discard fine solids. Monitor dilution rates closely to insure proper chemical concentrations are maintained.

40

Copyright ©2001-2012 NExT. All rights reserved

DURATHERM SYSTEM Typical Products M-I BAR M-IGEL  (pre-hydrated) Caustic Soda Lime Gyp XP-20 POLYPAC CMC THERMEX™ RESINEX

41

Copyright ©2001-2012 NExT. All rights reserved

Primary Function increase density viscosity & FL increase pH & Pf treat out CO3 treat out CO3 fluid loss control/thinner viscosity & gel strengths viscosity & gel strengths HPHT fluid loss HPHT fluid loss

DURATHERM SYSTEM Typical Properties: Density FV PV YP Initial Gels 10 Min. Gels MBT Fluid Loss Calcium pH Pm Pf Chlorides LGS 42

Copyright ©2001-2012 NExT. All rights reserved

as required (2.5-3.0) (Mud Wt.)
ENVIROTHERM SYSTEM A chrome-free, environmentally acceptable water-base system designed for high temperature, high pressure environments Stable in the presence of contaminants such as calcium, salts, and acid gases Used at temperatures up to about 430°F Stability due to low clay solids content and temperature stable, chrome-free products

43

Copyright ©2001-2012 NExT. All rights reserved

ENVIROTHERM SYSTEM Clays solids content (bentonite) reduced in this system as density and temperatures increase. Polymeric materials like CMC or POLYPAC replace bentonite for viscosity and gel strengths. SPERSENECF (chrome-free lignosulfonate) used for fluid stability by preventing gelation and flocculation while aiding in both API and HPHT fluid loss control TANNATHIN (lignite) reduces fluid loss & serves as a secondary deflocculant.

44

Copyright ©2001-2012 NExT. All rights reserved

POLY-PLUS® SYSTEM POLY-PLUS® SYSTEMS: Used primarily for shale stabilization Shale stabilization achieved through encapsulation, viscosifying the water phase, and by the polymer adsorbing free water Encapsulation - POLY-PLUS® wraps around clay platelets, preventing water from entering the interlayer structure of the clays. By viscosifying the water phase, fluid movement into the interlayer structure of the clay is slowed.

45

Copyright ©2001-2012 NExT. All rights reserved

POLY - PLUS® SYSTEM This system’s stability depends on maintaining polymer concentration in the proper range, and controlling clay content to less than 6.0 percent. If polymer concentration is not maintained, and solids content increases above the proper range, viscosity will increase, and anionic deflocculants (thinners) will be required to stabilize fluid properties. Cement (Ca++) and high pH are very detrimental to the polymer.

46

Copyright ©2001-2012 NExT. All rights reserved

POLY- PLUS® SYSTEM Initial POLY-PLUS® system makeup : Un-Weighted Syst. ppb 8 - 10 ppb 0.25 ± 1.0 - 2.5 0.5 - 2.0 --------------47

Copyright ©2001-2012 NExT. All rights reserved

Pre-hydrated M-I GEL® Caustic Soda or KOH POLY-PLUS® POLYPAC® or THERMPAC® UL DUO-VIS™ RESINEX®

Weighted Syst. ppb 0-5 0.25 ± 1.0 - 2.5 0.5 - 2.0 0.2 - 1.0 2.0 - 5.0

POLY- PLUS® SYSTEM Typical POLY_PLUS® System Properties : Density FV PV YP Initial Gels 10 Min. Gels MBT Fluid Loss Calcium pH Pm Pf Chlorides Solids 48

Copyright ©2001-2012 NExT. All rights reserved

8.8 - 12 ppg 32 - 45 sec/qt 6 - 10 cps 10 - 20 lb/100 sq ft 3 - 6 lb/100 sq ft 5 - 10 lb/100 sq ft 12 -20 ppb as required 0 - 600 mg/l 8.5 - 10.0 0.2 - 1.0 cc’s 0.1 - 0.5 cc’s 0 - 5% (KCL) 3 - 10 %

POLY-PLUS® SYSTEM True POLY-PLUS® System: Typical Products: M-I BAR M-IGEL  POLY-PLUS® Caustic Soda POLYPAC SP - 101 POLYSAL Soda Ash DUO-VIS™ TACKLE 49

Copyright ©2001-2012 NExT. All rights reserved

Primary Function: increase density viscosity & FL inhibition, gel extender pH & Pf fluid loss fluid loss fluid loss control hardness control LSRV reduce gel strengths

GLYCOL (GLYDRIL) SYSTEM • An enhanced-polymer, water-base system using polyglycol technology to provide shale inhibition, wellbore stability, HTHP fluid loss, and lubricity. • Ideal for drilling depleted sands where differential pressure sticking is a concern, in high-angle holes, with reactive formations • Other benefits include enhanced cuttings integrity, improved filter cake, lower dilution rates, less hole enlargement, greater solids tolerance, reduced bit balling, increased ROP, and environmentally friendly due to low toxicity; reduced disposal cost. 50

Copyright ©2001-2012 NExT. All rights reserved

GLYDRIL SYSTEM • The Cloud-Point phenomenon is the primary mechanism for inhibition and stabilization. • Cloud-Point is the temperature at which polyglycol changes from being totally soluble to insoluble. When temperature increases, some glycols become insoluble and come out of solutions. This temperature is called the cloud point. • At temperatures above the cloud point, poly-glycols form colloidal droplets or micelles which results in a microemulsion. This is referred to as “Thermally Activated Mud Emulsion” (TAME).

51

Copyright ©2001-2012 NExT. All rights reserved

GLYDRIL SYSTEM ADVANTAGES:

• • • • • •

Lower potential for differential sticking Lower fluid loss and leak-off values Less torque, drag, and bit balling Slicker, firmer filter-cakes Greater wellbore stability In-gauge wellbores

Engineered cloud point behavior 52

Copyright ©2001-2012 NExT. All rights reserved

GLYDRIL SYSTEM THE TAME PROVIDES WELLBORE STABILITY IN THREE DISTINCT WAYS: • Through chemical adsorption • Through micro-emulsion and precipitate pore plugging • By providing a thinner, less porous filter/wall cake. This system is more effective with salt in the system. • Therefore, NaCl or KCL is recommended for use in the system.

53

Copyright ©2001-2012 NExT. All rights reserved

GLYDRIL SYSTEM

54

Copyright ©2001-2012 NExT. All rights reserved

GLYDRIL SYSTEM

Wellbore Filter Cake Formation

55

Copyright ©2001-2012 NExT. All rights reserved

Clouded Glycol

GLYDRIL SYSTEM • Creates a hydrophobic or water repellant layer around the cuttings. When soluble they can also be absorbed between the layers of shale particles • GMC can improve the quality of the filtercake by - in their soluble form - enter small shale micro pores and then cloud out as the temperature in the formation is higher than the temperature of the drilling fluid. (Cloud up in the micro pores of the formation and create a water repellant layer around and block the formation pores) Hydrophobisity makes the filtercake slicker and will reduce torque and drag.

56

Copyright ©2001-2012 NExT. All rights reserved

GLYDRIL SYSTEM • The adsorption of insoluble poly-glycols into the filter/wall cake on permeable formations reduces the thickness of the filter/wall cake and fluid loss rates. • The poly-glycols provide lubrication and resists balling since insoluble poly-glycols have an affinity to solids and can coat solids and other surfaces. • Most Poly-glycol systems are designed to become totally soluble as it cools while being pumped up the annulus to the surface. But some systems are designed to keep the poly-glycol insoluble at all times.

57

Copyright ©2001-2012 NExT. All rights reserved

GLYDRIL SYSTEM Typical Products:

Primary Function:

M-I BAR

increase density

M-I GEL

viscosity & FL

Caustic Soda/KOH

pH & Pf

POLY-PLUS

encapsulation

DUO-VIS™

viscosity & suspension

POLYPAC R & UL

fluid loss control

GLYDRIL™ GP,

inhibition, lubricity

LC, MC, HC, 100

58

NaCl & KCl Brine

base fluid, activity

LUBE 167

lubricity

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM

59

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM  A salt/polymer system with added SODIUM SILICATE.  Developed to provide shale inhibition and hole stability in areas where oil or synthetic fluid systems would normally be used.  Formations like micro-fractured shale, chalk, or interbedded dispersive clays are applications for a SILDRIL™ SYSTEM.

60

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM  SILDRIL silicate enhanced polymer-based systems are designed to drill very reactive shales.  They strongly minimize shale hydration and improve formation integrity.  These systems can be used as an economic and environmental replacement for oilbase muds.

BEFORE 61

Copyright ©2001-2012 NExT. All rights reserved

AFTER

SILDRIL™ SYSTEM  As soluble silicates contact the low pH shales (clays) of formations, a reduction in pH and a reaction with divalent cations (Ca2+, Mg2+) on/in the shale (clay) form a calcium and/or magnesium silicate coating. – Soluble silicates are stable only at pH values > 11.0 or in the absence of cations. – Silicates will precipitate out at pH <11.0 or in the presence of cations. – Therefore, the pH should be controlled at 11.0 or greater and cations treated out with Soda Ash.

62

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM Reservoir damage may occur when drilling reservoirs which contain hard water. • Damage may occur due to precipitation of calcium silicate (cement) or solidification of sodium silicate into the pore throat of the rock matrix. • The same reservoir damage may also occur if the pH of the invaded filtrate is reduced over time.

63

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ Engineering Guidelines

64

Rheology

Xanthan for 6/3 RPM readings

Fluid Loss

±3.0 ppb PAC U/L & Reg. (9 - 6cc)

Silicate

5 - 8% by vol.

KCl

25 - 35 ppb

MBT

Generally low (highly inhibitive)

pH

11 - 12 (natural level)

Hardness

Zero (positive Silicate)

Corrosion

Inhibitors not necessary

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM • Silicate-based Fluids – Essentially a polymer-based system – Utilizes silicate chemistry for inhibition – Used primarily for drilling troublesome shale sections • They strongly minimize shale hydration and improve formation integrity. • In some applications, these systems can be used as an economic and environmental replacement for oil-base muds.

65

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM •

Inhibition are achieved as the soluble silicates precipitate to form an insoluble silicate film which prevents water contact with the wellbore shale (clay) or invasion into permeable formations.

•

As the soluble silicates come in contact with the surface of the low pH shales, a reduction in the pH and reaction with the divalent cations (Ca, Mg) on/in the shale occur to form a calcium /magnesium silicate coating.

•

Soluble silicates are stable only at pH values above 10.4 and in the absence of divalent cations. If pH is less than 10.4 or if divalent cations are present, the silicates will precipitate (calcium silicate = cement)

66

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM • Soluble Silicates are the metal salts of Silica Acid that exist in multiple polymeric forms in solution. • All silicates contain three basic components: – Silica – Alkali – Water

- SiO2 (Sand) - Na2O or K2O (Soda Ash or Potassium Carbonate) - H2O

O O

Si

Copyright ©2001-2012 NExT. All rights reserved

Si O

O 67

O

O Si

O

O O

O

SILDRIL™ SYSTEM • Silicates are alkaline materials (ie. pH range from 11.0 to 13.5) • Silicate species need a pH >10.7 to remain soluble in solution • pH of silicate solutions is maintained until almost complete neutralization • At pH’s <10.7 silicates rapidly cross-link to form high molecular weight species • Polymerization on the wellbore face is considered one of the inhibition mechanisms 68

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM

69

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM

70

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM The glassy nature of silicates imparts strong and rigid physical coating to surfaces

71

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM • Silicate

primary shale inhibitor (provides water barrier)

• Potassium

secondary shale inhibitor (reduces swelling)

• Biopolymer

rheology control

• PAC / Starch

provides fluid loss control

• Compatible with conventional anionic and non-ionic fluid additives • Used with mono-valent salts (KCl & NaCl)

72

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM

73

• Rheology

Xanthan for 6/3 RPM readings

• Fluid Loss

±3.0 ppb PAC U/L & Regular (< 10 cc)

• Silicate

5 - 8% by vol.

• KCl

25 - 35 ppb

• MBT

Generally low (highly inhibitive)

• pH

11 - 12 (natural level)

• Hardness

Zero (positive Silicate)

• Corrosion

Inhibitors not necessary

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM •

Silicate Gels formed on contact with low pH. (Formation Water / Acid Gas)

74

•

Silicate precipitation with divalent cations (Ca/Mg)

•

Precipitated / gelled Silicates bridge across Clays/Sands

•

Better stability with added Salts (KCl / NaCl)

Copyright ©2001-2012 NExT. All rights reserved

SILDRIL™ SYSTEM PRO’S Environmentally acceptable.  Can be discharged.  Land disposal subject to local regulations. Good Shale inhibition + wellbore stability. (extended OH periods) Good gauge hole through reactive Clays or Chalks. Corrosion Inhibitor. (sealant effect) Lower Cost per Foot. (cf: PHPA;KCl/Poly;Glydril)

75

Copyright ©2001-2012 NExT. All rights reserved

CON’S Debatable use for reservoir drilling (Unless perforate Liner)(Not OHC) Needs close monitoring (pH / Silicate) Sensitive to Hardness / Acid Gasses (divalent ions) Can effect performance of certain mechanical tools, elastomers, seals Temperature stability (± 260ºF) Density limitations similar to polymer mud system (13 -15 ppg) Lubricity (M-M Coefficient of Friction = 0.34)

High Performance WBM

76

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL SYSTEM

Gumbo cuttings 77

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL SYSTEM

22” – hole opener Accretion Free BHA 78

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL SYSTEM What is ULTRADRIL?

– High performance water-based fluid designed for use in a wide range of global applications ranging from deepwater to land • Highly inhibitive water-based fluid

– Superior chemical stabilization in reactive claystones – Reduced clay dispersion and hydration in comparison to existing glycol fluids – Lower risk of accretion and cuttings agglomeration.

• ULTRADRIL was designed to address the concerns and limitations associated with OBM’s and WBM’s. • ULTRADRIL was designed for broader application.

79

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL SYSTEM  Highly inhibitive water based fluid system, capable of providing superior chemical stabilisation over a wide range of reactive claystone and shale formations.  Significant reduction in clay dispersion and hydration, compared to existing glycol systems, particularly in fresh water and NaCl fluids (Onshore, GOM drilling).  Lower risk of accretion and cuttings agglomeration related problems.  Environmentally acceptable.  Viable alternative to Silicate fluids – more stable to contaminants – application not restricted to temperatures < 230°F.

80

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL - Performance Goals

 Shale stability – Cuttings – dilution – Wellbore – hole stability

 Good drilling performance – Low bit balling & good lubricity – Low dilution as compared to other WBM – Good properties for deepwater

 Flexibility – Base fluid – SW, SS & KCl – Products designed not to impact others! – Good environmental performance

81

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL20% NaCl

glycol/ PHPA20% NaCl

CaCl2/polymer

ULTRADRIL  Shale Inhibition Selected molecular structure polyamine reacts with shales to collapse hydrated clay structure.  Requires minimum levels of salinity (SW).  Applicable in densities to 17 ppg, and temp up to 300F.  Design approach to superior performance: – Inhibition of clay hydration – Shale encapsulator (LV) – ROP enhancer and anticrete – FL reducer with little viscosity contribution

82

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL - Main Components





83

ULTRAHIB - Clay Hydration Suppressant • Expected field concentration 3-4% v/v. • Liquid polyamine additive • Also imparts gas hydrate inhibition • Can be added directly to system with no effects on viscosity or filtration ULTRACAP - Clay dispersion inhibitor • Expected field concentration 2-3 lb/bbl. • Polymeric additive • Contributes little viscosity and some filtration reduction

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL - Main Components



ULTRAFREE - Accretion inhibitor and ROP enhancer – Liquid additive – Can be added directly to system with no effects on viscosity and filtration – Expected field concentration 1.5 - 3% volume



84

POLYPAC ELV – Fluid loss control – 2.0 – 4.0 ppb – Low viscosity product

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL Chemical stabilization of Reactive Clays Dispersion Tests

85

DI Water

Low-Lime

K-MAG

ULTRADRIL

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL SYSTEM • Viable alternative to silicate fluids and SBM – Improved lubricity – More stable to contaminants – No adverse effects in reservoir – No adverse effects with elastomers or tools – Adaptable over a wider range of densities and temperatures

86

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL SYSTEM  ULTRAHIB / ULTRAHIB NS – Clay hydration suppressant

– Liquid polyamine additive – Concentration 2 – 4 % v/v – Can be added directly to system with no adverse effects on viscosity or filtration

87

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL SYSTEM  ULTRACAP – Clay dispersion inhibitor

– Polymeric additive – Concentration 3,0 – 8,5 kg/m3 – Contribuites very little to viscosity and some filtration reduction

88

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL SYSTEM  ULTRACAP NS – Clay dispersion inhibitor

– Polymeric cellulose additive – Concentration 5,5 – 11,5 kg/m3 – Contribuites very little to viscosity and some filtration reduction

89

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL SYSTEM  ULTRAFREE NS / ULTRAFREE – Accretion inhibitor and ROP enhancer

– Liquid additive – Concentration 1,5 – 3,0% v/v – Can be added directly to system with no adverse effects on viscosity or filtration

90

Copyright ©2001-2012 NExT. All rights reserved

ULTRADRIL SYSTEM ULTRADRIL gives compact, readily removed cuttings, gauge wellbore, lower COF, without using environmentally hazardous materials. Result is lower fluid volumes, improved drilling performance, and disposal-compliant cuttings.

91

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX SYSTEM

What it is and how it works An ugly mud is just what you need! Understanding Drilplex and What Makes it T(h)ick…

92

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX (MMO) Products and System • A Mixed Metal Oxide (MMO) bentonite extender developed for high-angle holes, stabilizing weak and unconsolidated formations, and curing seepage losses in porous and fractured zones • A synthesized mixture of inorganic Magnesium and Aluminum oxides - insoluble in water • Non-toxic, with no heavy metals

93

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX AR • FEATURES: – Simple formulation and design – Cost effective – Friendly To Environment

94

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX AR • FEATURES: – Highly shear thinning – Improved solids removal efficiency – Low ECD’s – (allow high ROP) – Exceptional hole cleaning and suspension – Zero flow at wellbore face 95

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX AR • FEATURES:

– Stable to 300°F – Viscosity easily destroyed (for displacement procedures)

– Low reservoir damage and easy clean up

96

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX AR • APPLICATIONS: – Loss zones (porous and fractures) – Unconsolidated formations – Stabilizing surface hole against collapse – Milling Operations – High ROP required 97

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX AR • APPLICATIONS: – Deepwater – Coiled tubing drilling – Horizontal open-hole completions – Geothermal drilling

98

Copyright ©2001-2012 NExT. All rights reserved

99

Copyright ©2001-2012 NExT. All rights reserved

100

Copyright ©2001-2012 NExT. All rights reserved

A Psuedoplastic Fluid Two Euro coin floating on Drilplex fluid

101

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX AR – Typical Formulation PRODUCT

102

CONCENTRATION

GELPLEX

9.0 – 10.0 lb/bbl for freshwater fluids 9.0 – 12.0 lb/bbl for salty or seawater-based fluids

Soda Ash

1.0 lb/bbl for freshwater fluids 1.25 lb/bbl for salty or seawater-based fluids

DRILPLEX

1.0 lb/bbl in freshwater makeup water 1.0 – 1.5 lb/bbl in salty or seawater makeup water

FLOPLEX, FLOPLEX PLUS, TROLPLEX

3.0 – 5.0 lb/bbl

REPLEX

0.50 lb/bbl (If required)

M-I Bar or CaCO3

As required for desired weight

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX AR COMPONENTS – GELPLEX – (High grade API bentonite) Untreated bentonite specifically selected for the DRILPLEX system. (M-I GEL SUPREME may be substituted but results will differ slightly.) – DRILPLEX – (Viscosifier) The Mixed Metal Oxide product 0.6 – 1.2 ppb (freshwater) 0.8 – 1.4 ppb (seawater)

103

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX AR COMPONENTS Soda Ash •Primary pH control •0.5 ppb (freshwater) •1.25 ppb (seawater) Caustic Soda •Secondary pH control additive •Use as required for pH of 10.5 – 10.8 M-I BAR or Calcium Carbonate •Weighting agents •Use as required 104

Copyright ©2001-2012 NExT. All rights reserved

DRILPLEX AR Limitations • Drilplex looks ugly! •

Does not like Anionic materials such as: Lignins, Tannins, Coals, Peat, or PAC’s

• Properties can be restored with addition of an anionic scavenger – REPLEX • Fluid loss additives tend to compromise the low-end rheology (LSRV) of DRILPLEX AR

105

Copyright ©2001-2012 NExT. All rights reserved