completion fluids manual

COMPLETIONFLUIDS

Manual

TABLE OF CONTENTS

INTRODUCTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . iv

Chapter 1

DIVALENT BRINES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1·1• Calcium Chloride . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1·1• Calcium Bromide. . . . . . . . . . . . . . . . . . . . . . . . . . . . 1·2• Calcium Chloride and Calcium Bromide . . . . 1·2• Calcium Chloride, Calcium Bromide,

Zinc Bromide . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1·4• Blending Tables

U.S. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1·5Metric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1·23

Chapter 2

MONOVALENT BRINES. . . . . . . . . . . . . . . . . . . . . . . . . . 2·1• Sodium Chloride (Dry). . . . . . . . . . . . . . . . . . . . . . . 2·1• Potassium Chloride (Dry). . . . . . . . . . . . . . . . . . . . 2·1• Ammonium Chloride (Dry) . . . . . . . . . . . . . . . . . 2·1• Sodium Bromide (Liquid). . . . . . . . . . . . . . . . . . . . 2·1• Sodium Bromide (Dry) . . . . . . . . . . . . . . . . . . . . . . 2·2• Sodium Formate (Dry). . . . . . . . . . . . . . . . . . . . . . . 2·2• Potassium Formate (Liquid) . . . . . . . . . . . . . . . . . 2·2• Potassium Formate (Dry). . . . . . . . . . . . . . . . . . . . 2·2• Cesium Formate (Liquid) . . . . . . . . . . . . . . . . . . . . 2·3• Miscellaneous Blends . . . . . . . . . . . . . . . . . . . . . . . 2·3• Blending Tables

U.S. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2·4Metric . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2·15

Chapter 3

EXAMPLE CALCULATIONS . . . . . . . . . . . . . . . . . . . . . . . 3·1

Chapter 4

QHSE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4·1

Chapter 5

TEMPERATURE AND PRESSURE . . . . . . . . . . . . . . . . . . 5·1

ii

Chapter 6

TESTING PROCEDURES . . . . . . . . . . . . . . . . . . . . . . . . . . 6·1• RDF Testing Procedures . . . . . . . . . . . . . . . . . . . . 6·32

Chapter 7

DISPLACEMENT TECHNOLOGY . . . . . . . . . . . . . . . . . . 7·1

Chapter 8

VISCOSIFIERS AND FLUID-LOSS CONTROL. . . . . . . . 8·1

Chapter 9

CORROSION INHIBITION AND

PACKER FLUIDS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9·1

Chapter 10

FILTRATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10·1

Chapter 11

SPEEDWELL* TOOLS . . . . . . . . . . . . . . . . . . . . . . . . . . . 11·1

Chapter 12

INTERVENTION FLUID SYSTEMS . . . . . . . . . . . . . . . 12·1

Chapter 13

RESERVOIR DRILL-IN FLUIDS . . . . . . . . . . . . . . . . . . 13·1

Chapter 14

ENGINEERING FORMULAS AND TABLES . . . . . . . . 14·1

Chapter 15

LIST OF PRODUCTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15·1

iii

INTRODUCTION

M-I SWACO* provides a complete line of reser-voir drill-in, completion and workover fluidsand additives that help make oil and gas wellsmore productive. The company also offers fluidreclamation and filtration services comple-mented by a complete line of scrapers andbrushes for internal cleaning of casing, linersand risers.

This manual provides information and tech-nical data to support these systems and assistin their management during well design andfield operations.

iv

INTRODUCTION TO COMPLETION FLUIDS

With the recent proliferation of horizontalwellbores and open-hole completions, manydrilling and completion engineers now considerthe completion operation to begin as soon asthe drill bit enters the productive interval.Therefore, it is necessary to plan proceduresand implement practices to reduce formationdamage and maximize productivity at theearliest possible stage. Proper selection andapplication of the completion fluid is an inte-gral part of this process.

Completion fluid can be defined as any fluidpumped downhole to conduct operations afterthe initial drilling of a well. Workover fluids arethose used during remedial operations after awell has been completed and produced oil and/or gas. Clear, solids-free brine completion/workover fluids serve to control downhole for-mation pressures while reducing the risk ofpermanent formation damage (permeabilitydamage) resulting from solids invasion or someform of incompatibility between the comple-tion fluid and the in situ matrix. The clear brinesused for completion and workover applicationsare pure solutions of dissolved salt in water andmust be stable at surface and downhole con-ditions. Depending on the application, othercompletion/workover fluid types are some-times used, including solids-laden, oil-baseand emulsions. For the purpose of this docu-ment, no distinction is made between comple-tion and workover fluids and the terms are usedinterchangeably throughout. Packer fluids arethose that fill the annular volume above a pro-duction packer. The term reservoir drill-in fluidrefers to a drilling fluid designed specificallyfor the productive interval. Drill-in fluids are

v


designed to minimize damage to the interval,typically by eliminating insoluble solids such asbarite, minimizing the total solids content andformulating such that a thin, resilient, remov-able, non-damaging filter cake is placed.

Among the typical operations in whichclear brines are applied are well kills, fishing,perforating, washing, drilling and gravel pack-ing and as packer fluids. In order to perform thedesired function, completion fluids must con-trol formation pressures, circulate and trans-port solids, protect the productive zone, bestable under surface and downhole conditions,be safely handled, be environmentally friendlyor used with controlled exposure, and be costeffective. Completion fluids have no purposewithin the formation and may in fact reducethe permeability. The operator has two choices:1) minimize fluid losses to the formation and2) use a formation-compatible fluid and acceptpartial losses.

Clear brine completion fluids are formulatedand applied in the field according to perform-ance specifications that ensure well controlwith minimal permeability reduction. Thesespecifications are not always expressly iden-tified but should always be understood andassigned. Density and solids content (expressedas clarity — NTU) are typical performancespecifications for clear brine, although selec-tion of a particular completion fluid accordingto these alone can be dangerous to the produc-tivity of a well. Proper density is necessary forpressure control.

Clarity is necessary to eliminate formationplugging by solids. In addition to these, the all-encompassing term “formation compatible” is

vi


also a requirement and must not be overlooked.In order to select a completion or workoverfluid appropriate for the application, one mustunderstand the various types and propertiesof clear brine fluids. The remainder of this sec-tion provides this introductory information.

Types and PropertiesThe most common types of completion fluidsare selected from those listed in Table 1.

vii

Density Typical Range Density

Brine Type (lb/gal) (lb/gal)

NaCl 8.33 – 10.0 8.4 – 10.0

KCl 8.33 – 9.7 8.4 – 9.0

NH4Cl 8.33 – 8.9 8.4 – 8.7

NaBr 8.33 – 12.7 10.0 – 12.5

NaCl/NaBr 8.33 – 12.5 10.0 – 12.5

NaHCO2 8.33 – 11.1 9.0 – 10.5

KHCO2 8.33 – 13.3 10.8 – 13.1

NaHCO2/KHCO2 8.33 – 13.1 8.4 – 12.7

KHCO2/CsHCO2 8.33 – 20.0 13.1 – 18.3

CaCl2 8.33 – 11.8 ±9.0 – 11.6

CaBr2 8.33 – 15.3 ±12.0 – 14.2

CaCl2/CaBr2 8.33 – 15.1 11.7 – 15.1

ZnBr2 ±12 – 21.0 19.2 – 21.0

ZnBr2/CaBr2 ±12 – 19.2 ±14.0 – 19.2

ZnBr2/CaBr2/CaCl2 ±12 – 19.1 ±14.2 – 19.2

CsHCO2 ±8.33 – 20.0 13.2 – 19.2

Table 1


Density and Blending The density of clear brine is obtained by dis-solving salt in water. The density achieved isdirectly related to the amount of salt in solu-tion. Table 2 shows the maximum solubilityof standard completion-fluid salts in water atroom temperature.

The data in Table 2 demonstrates that thesolubility of these salts in water is extremelyhigh, capable of producing densities up to21 lb/gal (2.52 SG). It is also evident that as thesolubility increases, the ratio of salt-to-water

viii

Sol Density Specific lb lbSalt wt % (lb/gal) Gravity Salt Water

Sodium 26 10.0 1.200 109 311Chloride

Potassium 24 9.7 1.164 98 309Chloride

Sodium 46 12.7 1.525 245 288Bromide

Calcium 40 11.8 1.416 198 298Chloride

Calcium 57 15.3 1.837 366 277Bromide

Zinc 78 21.0 2.521 688 194Bromide

Sodium 50 11.1 1.329 231 235Formate

Potassium 78 13.3 1.595 434 125Formate

Cesium 84 19.17 2.30 676.3 128.8Formate

Table 2: Maximum Solubility of Salt in Water

one bbl at room temperature


becomes increasingly small. In fact, the satu-rated solutions of several of these systemscontain more salt than water. This fact isextremely important. It defines much of the“special chemistry” and properties of high-density completion fluids.

Commercial completion brines are oftenprepared with a combination of dry salts andliquid “stock fluids.” Some salts such as NaCland KCl are produced as dry material, i.e., theyare mined or formed through simple evapora-tion. Other brines like sodium bromide, potas-sium formate, calcium chloride and calciumbromide are manufactured as liquids. The drysalts are obtained only after processing theliquid. This process is energy consumptive andexpensive, so, solutions prepared with thesesalts are generally more expensive than theirall-liquid-blended counterparts. Zinc bromideis produced only in the liquid form. Table 3 listscommercially available “stock” fluids and drysalts. Comparing Tables 2 and 3 indicates thestock fluids are not produced as saturated solu-tions. In this way, the crystallization temper-ature is low enough as to allow storage inunheated tanks.

ix


“Standard” brine tables follow that providethe necessary data to blend various clear brinefluids to a specific density. Simple blendingcalculations are also included. To blend fluidsto achieve a specific crystallization tempera-ture (see TCT) or, to blend to a lowest-costdensity, consult an M-I SWACO completionfluids representative.

x

Stock Fluids that are Manufactured as Liquids

11.6 lb/gal (1.39) [38%] CaCl2 (U.S.)

11.3 lb/gal (1.36) [35%] CaCl2 (Europe)

12.5 lb/gal (1.50) [45%] NaBr

14.2 lb/gal (1.70) [52%] CaBr2

13.1 lb/gal (1.57) [78%] KHCO2

19.2 lb/gal (2.30) [53% / 23%] ZnBr2 / CaBr2

18.3 lb/gal (2.20) Cesium Formate

20.5 lb/gal (2.46) ZnBr2

Fluids Prepared From Salts

10 lb/gal (1.20) NaCl Stock, 3 to 8% KCl, 3-8% NH4Cl

Stock Salts

NaCl, NaBr, KCl, NH4Cl, CaCl2, CaBr2, NaHCO2, KHCO2

Table 3


xi

Crystallization Temperature (TCT)As salt is dissolved in water, it lowers the freez-ing point of the solution until the eutecticpoint is reached. The eutectic temperaturerepresents the lowest temperature on thesaltwater phase diagram. Increasing the saltconcentration beyond the eutectic raises thecrystallization point. The concentration atwhich the solution is saturated is a function ofits temperature. As shown in Table 2, calciumchloride is soluble in water to a final concen-tration of 40-wt % at room temperature. Thissolution is referred to as “saturated at roomtemperature.” If the solution is cooled, salt willprecipitate from solution. If the solution isheated, additional salt can be dissolved. Thattemperature, at which a salt is saturated, iscalled the True Crystallization Temperature(TCT). There are many instances where thecrystallization temperature of brine is aprimary selection criterion. For example, whenstored in cold weather or when used offshorewhere the seawater may be cold, the temper-ature at which a salt solution crystallizes (TCT)is an important consideration. Figures 2 and3 show crystallization curves for variouscompletion fluids. Pressure increases the crys-tallization point of a brine solution when theconcentration of salt is above the eutectic con-centration. See section 5 for a discussion of theeffect of pressure on TCT.


xii

55

35

15

–5

–25

–45

–65

Temperature (° F)

Density (lb/gal)

8.3 9.1 9.9 10.7 11.5 12.3 13.1 13.9 14.7 15.1

Eutectic pt

Eutectic pt

TCT (CaBr2) TCT (CaCl2)

Figure 2: Crystallization curves for

CaCl2 and CaBr2

60

40

20

0

–20

–40

–60

–80

Density (lb/gal)

Potassium ChlorideSodium ChlorideCalcium Chloride

8.58 9.5 10 11 11.5 1210.59

Temperature (° F)

Eutectic pt

Eutectic pt

Eutecticpt

Figure 3: Crystallization curves

for KCl, NaCl and CaCl2

Chapter 1DIVALENT BRINES

COMPLETION FLUIDSMANUAL

1.D

IVALENTBRINES

DIVALENT BRINES

Calcium ChlorideCalcium chloride is available either as a con-centrated solution or as a dry powder. The solu-tion is manufactured at two different densitiesdepending on the source, i.e., 11.6 lb/gal (1.392 SG)and 11.3 lb/gal (1.356 SG). Liquid calcium chlo-ride is the most economical form. The anhy-drous (94 to 97%) form of CaCl2 is used at therigsite to adjust fluid density.

The dry form of calcium chloride containstrace amounts of insoluble contaminants thatcause brines mixed on location to be more tur-bid than premixed brines. These contaminantsshould be filtered out of solution before use.

With addition of dry calcium chloride tofreshwater, a great deal of heat is generated.Adding the solid calcium chloride too rapidlycan result in enough heat to bring the temper-ature of the solution to over 200° F (93.3° C).Safe handling must be exercised to avoid beingburned by the hot liquid or equipment.

Less heat is produced when the concen-trated solution is diluted to prepare the desireddensity. As a result, problems related to heat aregenerally not encountered.

Personnel protective equipment must beused when mixing brines with dry calciumchloride. This material will generate dust that ishygroscopic and will also generate heat as itabsorbs moisture from the atmosphere or fromskin. Exposure to this dust must be avoided.

Formation waters or seawater should notbe used to prepare calcium chloride completionfluids because sodium chloride and/or insolublecalcium salts may precipitate.

1·1

DIVALENT BRINES

Calcium BromideCalcium Bromide (CaBr2) brine systems aresingle-salt solutions used to form clear-brineworkover and completion fluids with densitiesranging from 8.4 to 15.3 lb/gal (1.404 to 1.812 SG).The desired density is obtained by mixing stan-dard 14.2 lb/gal (1.704 SG) calcium bromide brinewith dry calcium bromide (or water) or by simplymixing dry calcium bromide in water. Calciumbromide systems exhibit lower crystallizationpoints than the corresponding calcium bromide/calcium chloride fluids.

Calcium bromide systems provide inhibition,preventing the hydration and migration ofswelling clays, and can be used for packer fluidsor to adjust the density of other brine systems.

Calcium bromide brine systems can be formu-lated with various crystallization points and areavailable for special applications and winter use.

Calcium Chloride and Calcium BromideClear brines having a density range of 11.7 lb/gal(1.404 SG) and 15.1 lb/gal (1.813 SG) are preparedusing a combination of calcium chloride andcalcium bromide. Liquid CaCl2, pelletized calciumchloride, concentrated liquid CaBr2, or solid cal-cium bromide powder are used in combinationto prepare these brines. CaBr2 concentrate isproduced at a density of 14.2 lb/gal (1.705 SG).

Calcium bromide costs approximately tentimes as much as calcium chloride. When TCTand density requirements allow, field-preparedbrines should contain as much calcium chlorideas is practical.

1·2

DIVALENT BRINES

1·3

Increasing the density of a CaCl2-CaBr2

blended brine by adding dry salts can causewellsite problems unless proper blending tech-niques are employed. For example, the additionof calcium bromide powder to a saturated blendcan result in the precipitation of calcium chlo-ride. Under these conditions, both water andcalcium bromide must be added to avoid precip-itation. An example of this is provided at theend of this section.

High-density, solids-free brines ranging upto 15.3 lb/gal (1.837 SG) can be prepared usingeither calcium bromide or the combination ofcalcium bromide and calcium chloride. The ratioof bromide-to-chloride in any particular densitydetermines the True Crystallization Temperature(TCT), or “freezing point.” Crystallization tem-perature must always be considered whenblending brines of any type, however, thechloride-bromide brines are particularly sensi-tive because small changes in the ratio of thetwo salts can result in significant changes inTCT. Environmental factors such as surface tem-perature, water depth and water temperatureand the influence of pressure on the crystal-lization point are important considerations andmust be taken into account when formulatingthe appropriate blend.

High-density slugs are used to ensure thata dry string is pulled when coming out of thehole. This is an important safety considerationsince calcium bromide brines can be irritatingto the skin and eyes.

When solid calcium bromide is added tofreshwater, considerable heat is released. Caremust be taken to avoid getting splashed by thehot liquid or burned by hot equipment. Unlike

DIVALENT BRINES

calcium chloride, this is not a problem whenliquid calcium bromide is added to waterbecause very little heat is generated.

Calcium Chloride, Calcium Bromide and Zinc BromideConcentrated zinc bromide-calcium bromidesolutions are manufactured to a density of19.2 lb/gal (2.305 SG). Solution densitiesbetween ±14.0 to 19.2 lb/gal (1.681 to 2.305 SG)are prepared by blending this 19.2 lb/gal(2.305 SG) “stock” fluid with lower densitycalcium bromide or calcium bromide-calciumchloride brines. The three-salt formulations areless expensive due to the presence of calciumchloride. As with the lower density chloride-bromide brines, special blend formulationsare used to achieve a specific density and TCT.

Zinc bromide or zinc bromide-calcium bro-mide solutions of up to 20.5 lb/gal (2.46 SG) arealso available in smaller quantities for sluggingor spiking purposes. When agitated in pitswhich are exposed to the atmosphere for as lit-tle as 4 hrs, the density of these concentratedliquids can decrease by as much as 0.02 lb/gal(2.397 kg/m3). A calm solution does not pick upmoisture as readily and will not lose density asquickly. To prevent absorption of moisture fromthe atmosphere, these high-density brinesshould be mixed and stored in covered tanks.

1·4

DIVALENT BRINES

1·5

Density CaCl2 Water CaCl2 Ca+2 Cl– TCT@70° F lb/bbl bbl/bbl wt % mg/L mg/L ° F

8.3 0.0 0.0000 0.00% 0 0 32

8.4 3.8 0.9989 1.00% 3,641 6,443 32

8.5 9.4 0.9951 2.50% 9,212 16,298 30

8.6 14.9 0.9914 3.90% 14,540 25,724 29

8.7 20.4 0.9875 5.30% 19,989 35,365 27

8.8 26.0 0.9836 6.70% 25,560 45,221 25

8.9 31.6 0.9796 8.00% 30,866 54,608 24

9.0 37.2 0.9755 9.40% 36,675 64,886 22

9.1 42.9 0.9714 10.70% 42,211 74,680 20

9.2 48.6 0.9671 11.90% 47,461 83,968 18

9.3 54.3 0.9627 13.20% 53,218 94,153 15

9.4 60.1 0.9583 14.50% 59,087 104,538 13

9.5 65.9 0.9537 15.70% 64,658 114,394 10

9.6 71.7 0.9491 16.90% 70,333 124,433 7

9.7 77.5 0.9443 18.10% 76,111 134,657 4

9.8 83.4 0.9395 19.30% 81,994 145,065 1

9.9 89.4 0.9346 20.40% 87,552 154,897 –3

10.0 95.3 0.9296 21.60% 93,638 165,666 –7

10.1 101.3 0.9245 22.70% 99,391 175,843 –12

10.2 107.3 0.9193 23.80% 105,239 186,190 –16

10.3 113.4 0.9140 24.90% 111,182 196,705 –22

10.4 119.4 0.9086 26.00% 117,221 207,389 –27

10.5 125.6 0.9031 27.00% 122,900 217,436 –33

10.6 131.7 0.8975 28.10% 129,125 228,450 –39

10.7 137.9 0.8918 29.10% 134,982 238,812 –46

10.8 144.1 0.8860 30.20% 141,394 250,155 –51

10.9 150.4 0.8801 31.20% 147,428 260,831 –36

Calcium Chloride CaCl2 (U.S.)

Mixing dry CaCl2 (94 to 97%) and water

Composition for one barrel fluid

Continues on next page

DIVALENT BRINES

1·6

Density CaCl2 Water CaCl2 Ca+2 Cl– TCT@70° F lb/bbl bbl/bbl wt % mg/L mg/L ° F

11.0 156.7 0.8741 32.20% 153,549 271,661 –22

11.1 163.0 0.8680 33.20% 159,757 282,644 –10

11.2 169.4 0.8618 34.20% 166,052 293,780 2

11.3 175.8 0.8555 35.20% 172,433 305,070 13

11.4 182.2 0.8491 36.10% 178,407 315,639 22

11.5 188.7 0.8426 37.10% 184,957 327,228 31

11.6 195.2 0.8360 38.10% 191,594 338,970 38

11.7 201.7 0.8293 39.00% 197,810 349,969 44

11.8 208.1 0.8227 39.90% 204,105 361,105 50

To calculate parts per million, divide mg/L by the specific gravity.

Continued from previous page



Composition for one barrel fluid

DIVALENT BRINES

1·7

CaCl2

Density 11.6 lb/gal Water TCT70° F bbl bbl ° F

8.3 0.022 0.978 32

8.4 0.022 0.978 32

8.5 0.052 0.948 30

8.6 0.083 0.917 29

8.7 0.113 0.887 27

8.8 0.144 0.856 25

8.9 0.174 0.826 24

9.0 0.203 0.797 22

9.1 0.233 0.767 20

9.2 0.264 0.736 18

9.3 0.294 0.706 15

9.4 0.325 0.675 13

9.5 0.356 0.644 10

9.6 0.390 0.610 7

9.7 0.420 0.580 4

9.8 0.450 0.550 1

9.9 0.480 0.520 –3

10.0 0.510 0.490 –7

10.1 0.540 0.460 –12

10.2 0.571 0.429 –16

10.3 0.601 0.399 –22

10.4 0.632 0.368 –27

10.5 0.663 0.337 –33

10.6 0.694 0.306 –39

10.7 0.724 0.276 –46


Blending 11.6 lb/gal CaCl2 (liquid) and water

Composition for one barrel of fluid


DIVALENT BRINES

1·8

CaCl2

Density 11.6 lb/gal Water TCT70° F bbl bbl ° F

10.8 0.755 0.245 –51

10.9 0.785 0.215 –36

11.0 0.820 0.180 –22

11.1 0.850 0.150 –10

11.2 0.880 0.120 2

11.3 0.910 0.090 13

11.4 0.940 0.060 22

11.5 0.970 0.030 31

11.6 1.000 0.000 38



Blending 11.6 lb/gal CaCl2 (liquid) and water


DIVALENT BRINES

1·9

Density CaBr2 Water CaBr2 Ca+2 Br– TCT@70° F lb/bbl bbl/bbl wt % mg/L mg/L ° F

8.33 0.0 1.0000 0.00% 0 0 32

8.4 3.6 0.9992 1.00% 2,022 8,062 30

8.5 9.0 0.9958 2.40% 4,910 19,580 30

8.6 14.4 0.9923 3.80% 7,866 31,366 29

8.7 19.9 0.9889 5.20% 10,889 43,421 28

8.8 25.3 0.9854 6.50% 13,768 54,900 27

8.9 30.7 0.9819 7.80% 16,709 66,628 27

9.0 36.1 0.9784 9.10% 19,713 78,606 26

9.1 41.6 0.9749 10.30% 22,560 89,961 25

9.2 47.0 0.9713 11.60% 25,687 102,428 24

9.3 52.4 0.9678 12.80% 28,653 114,253 23

9.4 57.9 0.9642 13.90% 31,449 125,405 22

9.5 63.3 0.9606 15.10% 34,528 137,681 21

9.6 68.8 0.9570 16.20% 37,433 149,266 19

9.7 74.3 0.9534 17.30% 40,391 161,061 18

9.8 79.7 0.9498 18.40% 43,402 173,068 17

9.9 85.2 0.9461 19.50% 46,466 185,286 16

10.0 90.7 0.9425 20.50% 49,343 196,756 14

10.1 96.2 0.9388 21.50% 52,267 208,417 13

10.2 102.0 0.9351 22.50% 55,240 220,270 11

10.3 107.0 0.9314 23.50% 58,261 232,316 10

10.4 113.0 0.9277 24.50% 61,329 244,553 8

10.5 118.0 0.9239 25.50% 64,447 256,982 7

10.6 124.0 0.9202 26.40% 67,357 268,586 5

10.7 129.0 0.9164 27.30% 70,310 280,362 3

10.8 135.0 0.9126 28.20% 73,307 292,312 2

10.9 140.0 0.9088 29.10% 76,347 304,434 0

11.0 146.0 0.9050 30.00% 79,430 316,729 –2

Calcium Bromide CaBr2 (U.S.)

Mixing dry CaBr2 (95%) and water



DIVALENT BRINES

1·10


11.1 151.0 0.9012 30.80% 82,289 328,131 –4

11.2 157.0 0.8973 31.70% 85,457 340,762 –6

11.3 162.0 0.8935 32.50% 88,396 352,481 –8

11.4 168.0 0.8896 33.30% 91,373 364,353 –10

11.5 174.0 0.8857 34.10% 94,389 376,379 –12

11.6 179.0 0.8818 34.90% 97,444 388,559 –14

11.7 185.0 0.8779 35.70% 100,537 400,892 –16

11.8 190.0 0.8740 36.50% 103,668 413,379 –18

11.9 196.0 0.8700 37.20% 106,552 424,877 –21

12.0 201.0 0.8660 38.00% 109,758 437,661 –23

12.1 207.0 0.8621 38.70% 112,711 449,438 –25

12.2 213.0 0.8581 39.40% 115,698 461,349 –28

12.3 218.0 0.8540 40.10% 118,719 473,394 –30

12.4 224.0 0.8500 40.80% 121,773 485,574 ≤–30

12.5 229.0 0.8460 41.50% 124,861 497,888 ≤–30

12.6 235.0 0.8419 42.20% 127,983 510,336 ≤–30

12.7 241.0 0.8378 42.90% 131,139 522,919 ≤–30

12.8 246.0 0.8338 43.50% 134,020 534,408 ≤–30

12.9 252.0 0.8296 44.20% 137,240 547,249 ≤–30

13.0 258.0 0.8255 44.80% 140,182 558,978 ≤–30

13.1 263.0 0.8214 45.40% 143,152 570,822 ≤–30

13.2 269.0 0.8172 46.10% 146,469 584,048 ≤–30

13.3 274.0 0.8131 46.70% 149,499 596,131 ≤–30

13.4 280.0 0.8089 47.30% 152,558 608,330 ≤–30

13.5 286.0 0.8047 47.90% 155,646 620,644 ≤–30

13.6 291.0 0.8005 48.50% 158,763 633,073 ≤–30

13.7 297.0 0.7962 49.10% 161,909 645,618 ≤–30

13.8 303.0 0.7920 49.60% 164,752 656,953 ≤–30






DIVALENT BRINES

1·11


13.9 309.0 0.7877 50.20% 167,953 669,718 –29

14.0 314.0 0.7835 50.80% 171,183 682,598 –19

14.1 320.0 0.7792 51.30% 174,103 694,240 –10

14.2 326.0 0.7749 51.90% 177,389 707,341 –1

14.3 331.0 0.7705 52.40% 180,359 719,185 7

14.4 337.0 0.7662 52.90% 183,353 731,125 15

14.5 343.0 0.7618 53.50% 186,720 744,552 23

14.6 349.0 0.7575 54.00% 189,765 756,693 30

14.7 354.0 0.7531 54.50% 192,834 768,931 36

14.8 360.0 0.7487 55.00% 195,927 781,264 43

14.9 366.0 0.7443 55.50% 199,044 793,693 48

15.0 371.0 0.7398 56.00% 202,185 806,218 54

15.1 377.0 0.7354 56.50% 205,350 818,839 59

15.2 383.0 0.7309 57.00% 208,540 831,557 63

15.3 389.0 0.7264 57.50% 211,753 844,370 68






DIVALENT BRINES

1·12

Density CaBr2

lb/gal 14.2 lb/gal Water TCT@70° F bbl/bbl bbl/bbl ° F

8.33 0.0 1.0000 32

8.4 0.012 0.989 30

8.5 0.028 0.972 30

8.6 0.045 0.957 29

8.7 0.061 0.940 28

8.8 0.078 0.924 27

8.9 0.094 0.908 27

9.0 0.111 0.892 26

9.1 0.127 0.876 25

9.2 0.144 0.859 24

9.3 0.162 0.840 23

9.4 0.177 0.826 22

9.5 0.194 0.810 21

9.6 0.211 0.793 19

9.7 0.228 0.777 18

9.8 0.244 0.760 17

9.9 0.261 0.744 16

10.0 0.278 0.727 14

10.1 0.295 0.710 13

10.2 0.312 0.693 11

10.3 0.329 0.676 10

10.4 0.345 0.660 8

10.5 0.362 0.643 7

10.6 0.379 0.626 5

10.7 0.396 0.609 3

10.8 0.413 0.592 2

10.9 0.430 0.575 0


Blending 14.2 lb/gal CaBr2 (liquid) and water

Composition for one barrel


DIVALENT BRINES

1·13

Density CaBr2


11.0 0.447 0.558 –2

11.1 0.464 0.541 –4

11.2 0.481 0.524 –6

11.3 0.499 0.507 –8

11.4 0.516 0.490 –10

11.5 0.533 0.472 –12

11.6 0.550 0.456 –14

11.7 0.567 0.438 –16

11.8 0.584 0.421 –18

11.9 0.601 0.403 –21

12.0 0.619 0.386 –23

12.1 0.636 0.369 –25

12.2 0.653 0.351 –28

12.3 0.670 0.334 –30

12.4 0.687 0.317 ≤–30

12.5 0.705 0.299 ≤–30

12.6 0.722 0.282 ≤–30

12.7 0.739 0.264 ≤–30

12.8 0.757 0.247 ≤–30

12.9 0.774 0.229 ≤–30

13.0 0.791 0.212 ≤–30

13.1 0.809 0.194 ≤–30

13.2 0.826 0.177 ≤–30

13.3 0.843 0.159 ≤–30

13.4 0.861 0.142 ≤–30






DIVALENT BRINES

1·14

Density CaBr2


13.5 0.878 0.124 ≤–30

13.6 0.895 0.106 ≤–30

13.7 0.913 0.089 ≤–30

13.8 0.930 0.071 ≤–30

13.9 0.948 0.053 –29

14.0 0.965 0.036 –19

14.1 0.982 0.018 –10

14.2 1.000 0.000 –1





DIVALENT BRINES

1·15

Density CaBr2 CaCl2

lb/gal Water (95%) (94 – 97%) TCT@70° F bbl/bbl dry lb/bbl dry lb/bbl ° F

11.7 0.809 8.1 200.3 40

11.8 0.803 16.1 198.3 41

11.9 0.798 24.2 196.2 42

12.0 0.793 32.3 194.1 42

12.1 0.788 40.3 192.0 42

12.2 0.783 48.4 189.9 43

12.3 0.778 56.5 187.8 43

12.4 0.773 64.5 185.8 43

12.5 0.768 72.6 183.7 44

12.6 0.763 80.6 181.6 45

12.7 0.758 88.7 179.5 46

12.8 0.752 96.8 177.4 47

12.9 0.747 104.8 175.4 47

13.0 0.742 112.9 173.3 47

13.1 0.737 121.0 171.2 48

13.2 0.732 129.0 169.1 48

13.3 0.727 137.1 167.0 49

13.4 0.722 145.2 165.0 50

13.5 0.717 153.3 162.9 50

Calcium Bromide/Calcium Chloride

CaBr2/CaCl2 Dry (U.S.)

Mixing water, dry CaBr2 (95%) and

dry CaCl2 (94 to 97%)



DIVALENT BRINES

1·16

Density CaBr2 CaCl2

lb/gal Water (95%) (94 – 97%) TCT@70° F bbl/bbl dry lb/bbl dry lb/bbl ° F

13.6 0.712 161.3 160.8 52

13.7 0.707 169.4 158.7 53

13.8 0.701 177.5 156.6 55

13.9 0.696 185.5 154.6 56

14.0 0.691 193.6 152.5 57

14.1 0.686 201.7 150.4 58

14.2 0.681 209.7 148.3 58

14.3 0.676 217.8 146.2 59

14.4 0.671 225.8 144.1 60

14.5 0.666 233.9 142.1 60

14.6 0.661 242.0 140.0 61

14.7 0.658 249.2 137.9 61

14.8 0.651 258.1 135.8 61

14.9 0.645 266.2 133.7 62

15.0 0.640 274.2 131.7 62

15.1 0.635 282.3 129.6 63


CaBr2/CaCl2 Dry (U.S.)

Mixing water, dry CaBr2 (95%) and

dry CaCl2 (94 to 97%)



DIVALENT BRINES

1·17

Density CaBr2 CaCl2 CaCl2

lb/gal 14.2 lb/gal 11.6 lb/gal dry TCT@70° F bbl/bbl bbl/bbl lb/bbl ° F

11.7 0.024 0.971 3.6 40

11.8 0.048 0.943 7.2 41

11.9 0.073 0.915 10.9 42

12.0 0.097 0.886 14.5 42

12.1 0.121 0.857 18.1 42

12.2 0.146 0.829 21.7 43

12.3 0.170 0.800 25.3 43

12.4 0.194 0.772 29.0 43

12.5 0.218 0.744 32.6 44

12.6 0.243 0.715 36.2 45

12.7 0.267 0.686 39.8 46

12.8 0.291 0.658 43.4 47

12.9 0.315 0.630 47.0 47

13.0 0.340 0.601 50.7 47

13.1 0.364 0.572 54.3 48

13.2 0.388 0.544 57.9 48

13.3 0.412 0.516 61.5 49

13.4 0.437 0.487 65.2 50

13.5 0.461 0.458 68.8 50

13.6 0.485 0.430 72.4 52

13.7 0.509 0.402 76.0 53


CaBr2/CaCl2 (U.S.)

Blending 14.2 lb/gal CaBr2 (liquid), 11.6 lb/gal

CaCl2 liquid and dry CaCl2 (94 to 97%)



DIVALENT BRINES

1·18

Density CaBr2 CaCl2 CaCl2

lb/gal 14.2 lb/gal 11.6 lb/gal dry TCT@70° F bbl/bbl bbl/bbl lb/bbl ° F

13.8 0.534 0.373 79.6 55

13.9 0.558 0.345 83.2 56

14.0 0.582 0.316 86.9 57

14.1 0.606 0.288 90.5 58

14.2 0.631 0.259 94.1 58

14.3 0.655 0.231 97.7 59

14.4 0.679 0.202 101.3 60

14.5 0.703 0.174 l05.0 60

14.6 0.728 0.145 108.6 61

14.7 0.749 0.120 111.8 61

14.8 0.776 0.088 115.8 61

14.9 0.800 0.060 119.4 62

15.0 0.825 0.031 123.1 62

15.1 0.851 0.000 126.9 63


CaBr2/CaCl2 (U.S.)

Blending 14.2 lb/gal CaBr2 (liquid), 11.6 lb/gal

CaCl2 (liquid) and dry CaCl2 (94 to 97%)



DIVALENT BRINES

1·19

Density CaBr2 ZnCaBr2

lb/gal 14.2 lb/gal 19.2 lb/gal TCT@70° F bbl/bbl bbl/bbl ° F

14.2 1.000 0.000 –1

14.3 0.980 0.020 –5

14.4 0.960 0.040 –11

14.5 0.940 0.060 –17

14.6 0.920 0.080 –21

14.7 0.900 0.100 –27

14.8 0.880 0.120 –31

14.9 0.860 0.140 –34

15.0 0.840 0.160 –37

15.1 0.820 0.180 –40

15.2 0.800 0.200 –43

15.3 0.780 0.220 –46

15.4 0.760 0.240 –49

15.5 0.740 0.260 –52

15.6 0.720 0.280 –55

15.7 0.700 0.300 –58

15.8 0.680 0.320 –60

15.9 0.660 0.340 –62

16.0 0.640 0.360 –58

16.1 0.620 0.380 –55

16.2 0.600 0.400 –51

16.3 0.580 0.420 –46

16.4 0.560 0.440 –42

16.5 0.540 0.460 –37

16.6 0.520 0.480 –31

Calcium Bromide/Zinc Bromide

CaBr2/ZnBr2 (U.S.)

Blending 14.2 CaBr2 (liquid) with

19.2 ZnCaBr2 (liquid)



DIVALENT BRINES

1·20

Density CaBr2 ZnCaBr2


16.7 0.500 0.500 –27

16.8 0.480 0.520 –23

16.9 0.460 0.540 –20

17.0 0.440 0.560 –17

17.1 0.420 0.580 –14

17.2 0.400 0.600 –11

17.3 0.380 0.620 –9

17.4 0.360 0.640 –7

17.5 0.340 0.660 –5

17.6 0.320 0.680 –3

17.7 0.300 0.700 –2

17.8 0.280 0.720 –1

17.9 0.260 0.740 1

18.0 0.240 0.760 2

18.1 0.220 0.780 3

18.2 0.200 0.800 4

18.3 0.180 0.820 5

18.4 0.160 0.840 6

18.5 0.140 0.860 8

18.6 0.120 0.880 9

18.7 0.100 0.900 11

18.8 0.080 0.920 13

18.9 0.060 0.940 14

19.0 0.040 0.960 13

19.1 0.020 0.980 12

19.2 0.000 1.000 10



CaBr2/ZnBr2 (U.S.)

Blending 14.2 CaBr2 (liquid) with

19.2 ZnCaBr2 (liquid)


DIVALENT BRINES

1·21

Density CaCl2/CaBr2 CaBr2/ZnCaBr2


15.1 1.000 0.000 62

15.2 0.976 0.024 60

15.3 0.951 0.049 59

15.4 0.927 0.073 58

15.5 0.903 0.098 56

15.6 0.878 0.122 55

15.7 0.854 0.146 54

15.8 0.829 0.171 53

15.9 0.805 0.195 51

16.0 0.780 0.220 51

16.1 0.756 0.244 49

16.2 0.732 0.268 48

16.3 0.707 0.293 47

16.4 0.683 0.317 46

16.5 0.658 0.342 44

16.6 0.634 0.366 42

16.7 0.610 0.390 39

16.8 0.585 0.415 34

16.9 0.561 0.439 28

17.0 0.537 0.463 25

17.1 0.512 0.488 26

17.2 0.488 0.512 28

17.3 0.463 0.537 28

17.4 0.439 0.561 30

17.5 0.415 0.585 32

Calcium Chloride/Calcium Bromide/

Zinc Bromide CaCl2/CaBr2/ZnBr2 (U.S.)

Blending 15.1 CaCl2/CaBr2 (liquid)

with 19.2 ZnCaBr2 (liquid)



DIVALENT BRINES

1·22

Density CaCl2/CaBr2 CaBr2/ZnCaBr2


17.6 0.390 0.610 34

17.7 0.366 0.634 36

17.8 0.341 0.659 38

17.9 0.317 0.683 40

18.0 0.293 0.707 35

18.1 0.268 0.732 32

18.2 0.244 0.756 29

18.3 0.220 0.780 27

18.4 0.195 0.805 25

18.5 0.171 0.829 23

18.6 0.146 0.854 21

18.7 0.122 0.878 20

18.8 0.097 0.903 19

18.9 0.073 0.927 17

19.0 0.049 0.951 16

19.1 0.024 0.976 12

19.2 0.000 1.000 10

To make 1 bbl 15.1 lb/gal = .851 (14.2 lb/gal CaBr2) + 127 ppb dry CaCl2.


Calcium Chloride/Calcium Bromide/

Zinc Bromide CaCl2/CaBr2/ZnBr2 (U.S.)

Blending 15.1 CaCl2/CaBr2 (liquid)

with 19.2 ZnCaBr2 (liquid)


DIVALENT BRINES

1·23

SpecificGravity CaCl2 Water CaCl2 Ca+2 Cl– TCT

(SG) kg/m3 m3/m3 wt % mg/L mg/L ° C

1.00 0.0 0.0000 0.00% 0 0 0

1.01 11.2 0.9988 1.10% 4,012 7,098 0

1.02 24.2 0.9957 2.30% 8,472 14,988 –1

1.03 37.2 0.9926 3.40% 12,646 22,374 –2

1.04 50.4 0.9895 4.60% 17,276 30,564 –2

1.05 63.5 0.9863 5.80% 21,992 38,908 –3

1.06 76.8 0.9830 6.90% 26,412 46,728 –4

1.07 90.0 0.9797 8.00% 30,911 54,689 –5

1.08 103.0 0.9763 9.10% 35,490 62,790 –6

1.09 117.0 0.9728 10.20% 40,149 71,031 –6

1.10 130.0 0.9693 11.30% 44,886 79,414 –7

1.11 144.0 0.9657 12.40% 49,704 87,936 –8

1.12 157.0 0.9620 13.40% 54,196 95,884 –10

1.13 171.0 0.9583 14.40% 58,760 103,960 –11

1.14 185.0 0.9546 15.50% 63,809 112,891 –12

1.15 199.0 0.9507 16.50% 68,521 121,229 –13

1.16 213.0 0.9468 17.50% 73,306 129,694 –15

1.17 226.0 0.9428 18.40% 77,741 137,539 –16

1.18 240.0 0.9388 19.40% 82,666 146,254 –18

1.19 255.0 0.9347 20.40% 87,664 155,096 –20

1.20 269.0 0.9305 21.30% 92,301 163,299 –21

1.21 283.0 0.9263 22.30% 97,439 172,391 –23

1.22 297.0 0.9220 23.20% 102,210 180,830 –26

1.23 311.0 0.9177 24.10% 107,045 189,385 –28

1.24 326.0 0.9132 25.00% 111,945 198,055 –30

1.25 340.0 0.9087 25.90% 116,911 206,839 –33

1.26 355.0 0.9042 26.80% 121,941 215,739 –36

Calcium Chloride CaCl2 (Metric)


Composition for one m3 of fluid


DIVALENT BRINES

1·24

SpecificGravity CaCl2 Water CaCl2 Ca+2 Cl– TCT


1.27 369.0 0.8995 27.70% 127,036 224,754 –38

1.28 384.0 0.8948 28.60% 132,196 233,884 –41

1.29 399.0 0.8901 29.50% 137,422 243,128 –52

1.30 413.0 0.8852 30.30% 142,243 251,657 –45

1.31 428.0 0.8803 31.20% 147,594 261,126 –38

1.32 443.0 0.8754 32.00% 152,534 269,866 –32

1.33 458.0 0.8703 32.80% 157,532 278,708 –26

1.34 473.0 0.8652 33.70% 163,072 288,508 –20

1.35 488.0 0.8600 34.50% 168,189 297,561 –15

1.36 504.0 0.8548 35.30% 173,363 306,717 –10

1.37 519.0 0.8494 36.10% 178,596 315,974 –6

1.38 534.0 0.8440 36.90% 183,886 325,334 –2

1.39 550.0 0.8386 37.70% 189,234 334,796 2

1.40 565.0 0.8330 38.50% 194,640 344,360 5

1.41 581.0 0.8274 39.30% 200,104 354,026 8

1.42 596.0 0.8217 40.00% 205,113 362,887 10






DIVALENT BRINES

1·25

Specific CaCl2

Gravity 1.39 SG Water TCT(SG) m3/m3 m3/m3 ° C

1.00 0.000 1.000 0

1.01 0.022 0.978 –1

1.02 0.052 0.948 –1

1.03 0.083 0.917 –1

1.04 0.113 0.887 –2

1.06 0.144 0.856 –3

1.07 0.174 0.826 –4

1.08 0.203 0.797 –6

1.09 0.233 0.767 –7

1.10 0.264 0.736 –8

1.12 0.294 0.706 –9

1.13 0.325 0.675 –11

1.14 0.356 0.644 –12

1.15 0.390 0.610 –14

1.16 0.420 0.580 –16

1.18 0.450 0.550 –17

1.19 0.480 0.520 –19

1.20 0.510 0.490 –22

1.21 0.540 0.460 –24

1.22 0.571 0.429 –27

1.24 0.601 0.399 –30

1.25 0.632 0.368 –33

1.26 0.663 0.337 –36

1.27 0.694 0.306 –39

1.29 0.724 0.276 –43


Blending 1.39 SG CaCl2 (liquid) and water



DIVALENT BRINES

1·26

Specific CaCl2

Gravity 1.39 SG Water TCT(SG) m3/m3 m3/m3 ° C

1.30 0.755 0.245 –46

1.31 0.785 0.215 –38

1.32 0.820 0.180 –30

1.33 0.850 0.150 –23

1.35 0.880 0.120 –17

1.36 0.910 0.090 –11

1.37 0.940 0.060 –6

1.38 0.970 0.030 –1

1.39 1.000 0.000 3



Blending 1.39 SG CaCl2 (liquid) and water


DIVALENT BRINES

1·27

Specific CaBr2

Gravity Water 95% dry CaBr2 Ca+ Br– TCT(SG) m3/m3 kg/m3 % wt mg/L mg/L ° C

1.00 1.0000 0.0 0.0% 0 0 0

1.01 0.9991 10.9 1.0% 2,025 8,074 –1

1.02 0.9963 23.7 2.2% 4,499 17,939 –1

1.03 0.9934 36.5 3.4% 7,021 27,995 –2

1.04 0.9905 49.4 4.5% 9,383 37,412 –2

1.05 0.9876 62.2 5.6% 11,789 47,005 –2

1.06 0.9847 75.1 6.7% 14,239 56,774 –3

1.07 0.9818 87.9 7.8% 16,733 66,719 –3

1.08 0.9789 100.8 8.9% 19,271 76,839 –3

1.09 0.9760 113.7 9.9% 21,635 86,264 –4

1.10 0.9730 126.6 11.0% 24,259 96,729 –4

1.11 0.9701 139.5 12.0% 26,705 106,481 –5

1.12 0.9671 152.4 13.0% 29,191 116,394 –5

1.13 0.9641 165.4 13.9% 31,491 125,563 –6

1.14 0.9612 178.3 14.9% 34,055 135,788 –6

1.15 0.9582 191.3 15.8% 36,429 145,253 –7

1.16 0.9552 204.2 16.8% 39,072 155,789 –7

1.17 0.9521 217.2 17.7% 41,520 165,550 –8

1.18 0.9491 230.2 18.6% 44,004 175,454 –8

1.19 0.9461 243.2 19.5% 46,524 185,503 –9

1.20 0.9430 256.2 20.3% 48,839 194,736 –10

1.21 0.9400 269.2 21.2% 51,430 205,065 –10

1.22 0.9369 282.2 22.0% 53,812 214,562 –11

1.23 0.9338 295.3 22.9% 56,472 225,170 –12

1.24 0.9308 308.3 23.7% 58,920 234,931 –12

1.25 0.9277 321.4 24.5% 61,400 244,819 –13

1.26 0.9246 334.4 25.3% 63,912 254,836 –14

Calcium Bromide CaBr2 (Metric)

Mixing CaBr2 dry (95%) and water



DIVALENT BRINES

1·28

Specific CaBr2


1.27 0.9214 347.5 26.1% 66,456 264,980 –15

1.28 0.9183 360.6 26.8% 68,776 274,230 –15

1.29 0.9152 373.7 27.6% 71,383 284,622 –16

1.30 0.9120 386.8 28.4% 74,021 295,142 –17

1.31 0.9089 399.9 29.1% 76,429 304,743 –18

1.32 0.9057 413.1 29.8% 78,865 314,456 –19

1.33 0.9025 426.2 30.5% 81,329 324,281 –20

1.34 0.8993 439.4 31.2% 83,821 334,217 –20

1.35 0.8961 452.5 31.9% 86,341 344,266 –21

1.36 0.8929 465.7 32.6% 88,889 354,426 –22

1.37 0.8897 478.9 33.3% 91,466 364,699 –23

1.38 0.8864 492.1 34.0% 94,070 375,083 –24

1.39 0.8832 505.3 34.6% 96,424 384,468 –25

1.40 0.8799 518.5 35.3% 99,082 395,068 –26

1.41 0.8767 531.7 35.9% 101,486 404,653 –27

1.42 0.8734 545.0 36.6% 104,199 415,469 –28

1.43 0.8701 558.2 37.2% 106,653 425,254 –29

1.44 0.8668 571.5 37.8% 109,131 435,135 –30

1.45 0.8635 584.7 38.4% 111,633 445,111 –31

1.46 0.8602 598.0 39.0% 114,159 455,184 –33

1.47 0.8568 611.3 39.6% 116,709 465,352 –34

1.48 0.8535 624.6 40.2% 119,284 475,617 <–35

1.49 0.8502 637.9 40.8% 121,882 485,977 <–35

1.50 0.8468 651.2 41.4% 124,504 496,433 <–35

1.51 0.8434 664.6 41.9% 126,848 505,779 <–35

1.52 0.8400 677.9 42.5% 129,517 516,419 <–35






DIVALENT BRINES

1·29

Specific CaBr2


1.53 0.8366 691.3 43.1% 132,209 527,155 <–35

1.54 0.8332 704.6 43.6% 134,617 536,756 <–35

1.55 0.8298 718.0 44.1% 137,045 546,437 <–35

1.56 0.8264 731.4 44.7% 139,806 557,444 <–35

1.57 0.8230 744.8 45.2% 142,276 567,293 <–35

1.58 0.8195 758.2 45.7% 144,766 577,222 <–35

1.59 0.8160 771.6 46.2% 147,276 587,230 <–35

1.60 0.8126 785.0 46.8% 150,127 598,598 <–35

1.61 0.8091 798.5 47.3% 152,679 608,774 <–35

1.62 0.8056 811.9 47.8% 155,252 619,031 <–35

1.63 0.8021 825.4 48.3% 157,844 629,367 <–35

1.64 0.7986 838.9 48.7% 160,128 638,473 <–35

1.65 0.7951 852.3 49.2% 162,758 648,961 <–35

1.66 0.7915 865.8 49.7% 165,408 659,529 –39

1.67 0.7880 879.3 50.2% 168,079 670,177 –34

1.68 0.7844 892.8 50.6% 170,433 679,562 –30

1.69 0.7809 906.4 51.1% 173,141 690,362 –25

1.70 0.7773 919.9 51.6% 175,870 701,242 –21

1.71 0.7737 933.5 52.0% 178,276 710,835 –17

1.72 0.7701 947.0 52.5% 181,043 721,867 –13

1.73 0.7665 960.6 52.9% 183,483 731,596 –10

1.74 0.7629 974.2 53.4% 186,287 742,780 –6

1.75 0.7592 987.8 53.8% 188,762 752,644 –3

1.76 0.7556 1001.4 54.2% 191,252 762,573 0

1.77 0.7519 1015.0 54.6% 193,758 772,566 3

1.78 0.7483 1028.6 55.1% 196,637 784,045 6






DIVALENT BRINES

1·30

Specific CaBr2


1.79 0.7446 1042.2 55.5% 199,177 794,174 9

1.80 0.7409 1055.9 55.9% 201,733 804,366 11

1.81 0.7372 1069.5 56.3% 204,306 814,623 14

1.82 0.7335 1083.2 56.7% 206,894 824,943 16

1.83 0.7298 1096.9 57.1% 209,498 835,327 18

1.84 0.7260 1110.5 57.5% 212,119 845,775 20






DIVALENT BRINES

1·31

Specific CaBr2

Gravity 1.705 SG Water TCT(SG) m3 m3 ° C

1.008 0.012 0.989 –1

1.020 0.028 0.972 –1

1.032 0.045 0.957 –2

1.044 0.061 0.940 –2

1.056 0.078 0.924 –2

1.068 0.094 0.908 –3

1.080 0.111 0.892 –3

1.092 0.127 0.876 –4

1.104 0.144 0.859 –5

1.116 0.162 0.840 –5

1.128 0.177 0.826 –6

1.140 0.194 0.810 –7

1.152 0.211 0.793 –7

1.164 0.228 0.777 –8

1.176 0.244 0.760 –9

1.188 0.261 0.744 –9

1.200 0.278 0.727 –10

1.212 0.295 0.710 –11

1.224 0.312 0.693 –12

1.236 0.329 0.676 –12

1.248 0.345 0.660 –13

1.261 0.362 0.643 –14

1.273 0.379 0.626 –15

1.285 0.396 0.609 –16

1.297 0.413 0.592 –17


Blending 1.705 SG CaBr2 (liquid) and water



DIVALENT BRINES

1·32

Specific CaBr2


1.309 0.430 0.575 –17

1.321 0.447 0.558 –18

1.333 0.464 0.541 –19

1.345 0.481 0.524 –20

1.357 0.499 0.507 –21

1.369 0.516 0.490 –22

1.381 0.533 0.472 –23

1.393 0.550 0.456 –25

1.405 0.567 0.438 –28

1.417 0.584 0.421 –28

1.429 0.601 0.403 –29

1.441 0.619 0.386 –29

1.453 0.636 0.369 –31

1.465 0.653 0.351 –34

1.477 0.670 0.334 –37

1.489 0.687 0.317 –37

1.501 0.705 0.299 –37

1.513 0.722 0.282 –37

1.525 0.739 0.264 –37

1.537 0.757 0.247 –37

1.549 0.774 0.229 –37

1.561 0.791 0.212 –38

1.573 0.809 0.194 –38

1.585 0.826 0.177 –38

1.597 0.843 0.159 –38






DIVALENT BRINES

1·33

Specific CaBr2


1.609 0.861 0.142 –38

1.621 0.878 0.124 –38

1.633 0.895 0.106 –38

1.645 0.913 0.089 –38

1.657 0.930 0.071 –38

1.669 0.948 0.053 –32

1.681 0.965 0.036 –28

1.693 0.982 0.018 –26

1.705 1.000 0.000 –18





DIVALENT BRINES

1·34

Specific CaBr2 CaCl2

Gravity Water (95%) (94 – 97%) TCT(SG) m3/m3 dry kg/m3 dry kg/m3 ° C

1.405 0.809 23.1 572.1 4

1.417 0.803 46.0 566.2 5

1.429 0.798 69.1 560.3 6

1.441 0.793 92.2 554.3 6

1.453 0.788 115.2 548.4 6

1.465 0.783 138.2 542.4 6

1.477 0.778 161.2 536.5 6

1.489 0.773 184.3 530.5 6

1.501 0.768 207.3 524.6 7

1.513 0.763 230.1 518.6 7

1.525 0.758 253.4 512.7 8

1.537 0.752 276.5 506.8 8

1.549 0.747 299.4 500.8 8

1.561 0.742 322.5 494.9 8

1.573 0.737 345.5 488.9 9

1.585 0.732 368.5 483.0 9

1.597 0.727 391.6 477.1 9

1.609 0.722 414.6 471.1 10

1.621 0.717 437.7 465.1 10

1.633 0.712 460.7 459.2 11

1.645 0.707 483.7 453.3 12

Calcium Bromide/Calcium Chloride Dry

CaBr2/CaCl2 (Metric)

Mixing procedure for dry CaBr2 (95%),

dry CaCl2 (94 to 97%) and water

Composition for m3 of fluid


DIVALENT BRINES

1·35

Specific CaBr2 CaCl2

Gravity Water (95%) (94 – 97%) TCT(SG) m3/m3 dry kg/m3 dry kg/m3 ° C

1.657 0.701 506.8 447.3 13

1.669 0.696 529.8 441.4 13

1.681 0.691 552.8 435.5 14

1.693 0.686 575.9 429.5 14

1.705 0.681 599.0 423.5 14

1.717 0.676 622.0 417.6 15

1.729 0.671 645.0 411.7 16

1.741 0.666 668.0 405.7 16

1.753 0.661 691.0 399.8 16

1.765 0.658 711.8 393.8 16

1.777 0.651 737.2 387.9 16

1.789 0.645 760.2 381.9 17

1.801 0.640 783.2 376.0 17

1.813 0.635 806.2 370.1 17

Calcium Bromide/Calcium Chloride Dry


Mixing procedure for dry CaBr2 (95%),

dry CaCl2 (94 to 97%) and water



DIVALENT BRINES

1·36

Specific CaBr2 CaCl2 CaCl2

Gravity 1.705 SG 1.39 SG (94 – 97%) TCT(SG) m3/m3 m3/m3 dry kg/m3 ° C

1.405 0.024 0.971 10.3 4

1.417 0.048 0.943 20.6 5

1.429 0.073 0.915 31.1 6

1.441 0.097 0.886 41.4 6

1.453 0.121 0.857 51.7 6

1.465 0.146 0.829 62.0 6

1.477 0.170 0.800 72.3 6

1.489 0.194 0.772 82.8 6

1.501 0.218 0.744 93.1 7

1.513 0.243 0.715 103.4 7

1.525 0.267 0.686 113.7 8

1.537 0.291 0.658 124.0 8

1.549 0.315 0.630 134.2 8

1.561 0.340 0.601 144.8 8

1.573 0.364 0.572 155.1 9

1.585 0.388 0.544 165.4 9

1.597 0.412 0.516 175.6 9

1.609 0.437 0.487 186.2 10

1.621 0.461 0.458 196.5 10

1.633 0.485 0.430 206.8 11

1.645 0.509 0.402 217.1 12



Blending 1.705 SG CaBr2 (liquid), 1.39 SG




DIVALENT BRINES

1·37

Specific CaBr2 CaCl2 CaCl2

Gravity 1.705 SG 1.39 SG (94 – 97%) TCT(SG) m3/m3 m3/m3 dry kg/m3 ° C

1.657 0.534 0.373 227.3 13

1.669 0.558 0.345 237.6 13

1.681 0.582 0.316 248.2 14

1.693 0.606 0.288 258.5 14

1.705 0.631 0.259 268.7 14

1.717 0.655 0.231 279.0 15

1.729 0.679 0.202 289.3 16

1.741 0.703 0.174 299.9 16

1.753 0.728 0.145 310.2 16

1.765 0.749 0.120 319.3 16

1.777 0.776 0.088 330.7 16

1.789 0.800 0.060 341.0 17

1.801 0.825 0.031 351.6 17

1.813 0.851 0.000 362.4 17



Blending 1.705 SG CaBr2 (liquid), 1.39 SG




DIVALENT BRINES

1·38

Specific CaBr2 ZnCaBr2

Gravity 1.705 SG 2.31 SG TCT(SG) m3/m3 m3/m3 ° C

1.705 1.0000 0.0000 –18

1.720 0.9780 0.0220 –22

1.730 0.9613 0.0387 –24

1.740 0.9447 0.0553 –27

1.750 0.9281 0.0719 –29

1.760 0.9114 0.0886 –31

1.770 0.8948 0.1052 –32

1.780 0.8781 0.1219 –34

1.790 0.8615 0.1385 –36

1.800 0.8449 0.1551 –38

1.810 0.8282 0.1718 –39

1.820 0.8116 0.1884 –41

1.830 0.7949 0.2051 –42

1.840 0.7783 0.2217 –43

1.850 0.7617 0.2383 –44

1.860 0.7450 0.2550 –46

1.870 0.7284 0.2716 –47

1.880 0.7117 0.2883 –48

1.890 0.6951 0.3049 –49

1.900 0.6785 0.3215 –51

1.910 0.6618 0.3382 –52

1.920 0.6452 0.3548 –51

1.930 0.6285 0.3715 –49

1.940 0.6119 0.3881 –47

1.950 0.5953 0.4047 –45


CaBr2/ZnBr2 (Metric)

Blending 1.705 SG CaBr2 (liquid)

with 2.31 SG ZnCaBr2 (liquid)

Composition for one m3 fluid


DIVALENT BRINES

1·39



1.960 0.5786 0.4214 –43

1.970 0.5620 0.4380 –41

1.980 0.5454 0.4546 –39

1.990 0.5287 0.4713 –37

2.000 0.5121 0.4879 –34

2.010 0.4954 0.5046 –32

2.020 0.4788 0.5212 –31

2.030 0.4622 0.5378 –29

2.040 0.4455 0.5545 –28

2.050 0.4289 0.5711 –27

2.060 0.4122 0.5878 –25

2.070 0.3956 0.6044 –24

2.080 0.3790 0.6210 –23

2.090 0.3623 0.6377 –22

2.100 0.3457 0.6543 –21

2.110 0.3290 0.6710 –20

2.120 0.3124 0.6876 –19

2.130 0.2958 0.7042 –19

2.140 0.2791 0.7209 –18

2.150 0.2625 0.7375 –18

2.160 0.2458 0.7542 –17

2.170 0.2292 0.7708 –17

2.180 0.2126 0.7874 –16

2.190 0.1959 0.8041 –16

2.200 0.1793 0.8207 –16








DIVALENT BRINES

1·40



2.210 0.1626 0.8374 –14

2.220 0.1460 0.8540 –14

2.230 0.1294 0.8706 –13

2.240 0.1127 0.8873 –12

2.250 0.0961 0.9039 –11

2.260 0.0794 0.9206 –11

2.270 0.0628 0.9372 –10

2.280 0.0462 0.9538 –11

2.290 0.0295 0.9705 –11

2.300 0.0129 0.9871 –12







DIVALENT BRINES

1·41

Specific CaCl2/CaBr2 ZnCaBr2


1.81 1.000 0.000 17

1.83 0.976 0.024 16

1.84 0.951 0.049 15

1.85 0.927 0.073 14

1.86 0.903 0.098 13

1.87 0.878 0.122 13

1.89 0.854 0.146 12

1.90 0.829 0.171 12

1.91 0.805 0.195 11

1.92 0.780 0.220 11

1.93 0.756 0.244 9

1.95 0.732 0.268 9

1.96 0.707 0.293 8

1.97 0.683 0.317 8

1.98 0.658 0.342 7

1.99 0.634 0.366 6

2.01 0.610 0.390 4

2.02 0.585 0.415 1

2.03 0.561 0.439 –2

2.04 0.537 0.463 –4

2.05 0.512 0.488 –3

2.07 0.488 0.512 –2

2.08 0.463 0.537 –2

2.09 0.439 0.561 –1

2.10 0.415 0.585 0

Calcium Chloride/Calcium Bromide/Zinc

Bromide CaCl2/CaBr2/ZnBr2 (Metric)

Blending 1.81 SG CaCl2/CaBr2 (liquid)

with 2.31 SG CaBr2/ZnCaBr2 (liquid)



DIVALENT BRINES

1·42

Specific CaCl2/CaBr2 ZnCaBr2


2.11 0.390 0.610 1

2.13 0.366 0.634 2

2.14 0.341 0.659 3

2.15 0.317 0.683 4

2.16 0.293 0.707 2

2.17 0.268 0.732 0

2.19 0.244 0.756 –2

2.20 0.220 0.780 –3

2.21 0.195 0.805 –4

2.22 0.171 0.829 –5

2.23 0.146 0.854 –6

2.25 0.122 0.878 –7

2.26 0.097 0.903 –7

2.27 0.073 0.927 –8

2.28 0.049 0.951 –9

2.29 0.024 0.976 –11

2.31 0.000 1.000 –12

To make 1 m3 15.1 lb/gal = 0.851 m3 (1.71 SG) + 57.8 kg/bbl dryCaCl2 (94 to 97%).

Calcium Chloride/Calcium Bromide/Zinc

Bromide CaCl2/CaBr2/ZnBr2 (Metric)

Blending 1.81 SG CaCl2/CaBr2 (liquid)

with 2.31 SG CaBr2/ZnCaBr2 (liquid)



Chapter 2MONOVALENT BRINES


2.M

ONOVALENTBRINES

MONOVALENT BRINES

Sodium Chloride (Dry)Sodium Chloride (dry) is a high-purity salt usedin brines with a density range between 8.4 to10.0 lb/gal (1.008 to 1.200 SG). When mixedwith NaBr, densities up to 12.5 lb/gal (1.501 SG)can be achieved. It is packaged in 100-lb (45.4-kg),80-lb (36.3-kg), 110-lb (50-kg) sacks and 2,000-lb(909-kg) tote bags.

Potassium Chloride (Dry)Potassium Chloride (dry) is a high-purity saltthat can achieve brine densities from 8.4 lb/gal(1.008 SG) to 9.7 lb/gal (1.164 SG). It is packagedin 50-lb (22.7-kg), 100-lb (45.4-kg) sacks and2,000-lb (909-kg) tote bags.

Ammonium Chloride (Dry)Ammonium Chloride (dry) is a high-purity saltthat can generate brine densities from 8.4 to9.7 lb/gal (1.008 to 1.164 SG). It is also used at 2to 4% as a clay and shale stabilizer. It may liber-ate ammonia gas at pHs above 9.0. Ammoniumchloride (dry) is packaged in 50-lb (22.7-kg) and55-lb (25-kg) sacks.

Sodium Bromide (Liquid) Sodium Bromide (liquid) is a single-salt clearbrine fluid. Pure sodium bromide solutions canbe prepared with densities between 8.4 lb/gal(1.008 SG) and 12.8 lb/gal (1.537 SG). Typically,it can be mixed with NaCl to prepare brineswith densities between 10.0 and 12.5 lb/gal(1.200 and 1.501 SG). It is used where formationwaters contain high concentrations of bicar-bonate or sulfate ions. It can be formulated for

2·1

MONOVALENT BRINES

various crystallization temperatures and forsummer or winter blends. It is packaged inbulk-liquid quantities.

Sodium Bromide (Dry) Sodium Bromide (dry) is a high-purity salt.Pure sodium bromide solutions can be preparedwith densities between 8.4 lb/gal (1.008 SG) and12.8 lb/gal (1.537 SG). Typically, it can be mixedwith NaCl to prepare brines with densitiesbetween 8.4 and 12.5 lb/gal (1.008 and 1.501 SG).It is used where formation waters contain highconcentrations of bicarbonate or sulfate ionsand is packaged in 55-lb (25-kg) sacks.

Sodium Formate (Dry)Sodium formate (dry) is a high-purity, organicsalt that can deliver brine fluid densities rang-ing from 8.4 lb/gal (1.008 SG) to 11.1 lb/gal(1.330 SG). It is packaged in 55-lb (25-kg) sacksand 2,205-lb (1,000-kg) “big” bags.

Potassium Formate (Liquid) Potassium Formate (liquid) is a single-saltclear brine fluid. Pure potassium formate solu-tions can be prepared with densities between8.4 lb/gal (1.08 SG) and 13.1 lb/gal (1.571 SG).Potassium formate provides excellent thermalstabilization effects on natural polymers. Thepotassium ion provides excellent clay stabili-zation and swelling inhibition of shales.

Potassium Formate (Dry) Potassium formate (dry) is a high-purity,organic salt with eventual densities between

2·2

MONOVALENT BRINES

8.4 lb/gal (1.008 SG) and 13.1 lb/gal (1.573 SG).It is packaged in 55-lb (25-kg) sacks or in 2,205-lb(1,000-kg) “big” bags.

Cesium Formate (Liquid)Cesium formate (liquid) is a single-salt clearbrine fluid. Pure cesium formate systems canbe prepared with densities between 8.4 lb/gal(1.01 SG) and 20.0 lb/gal (2.40 SG), but cesiumformate is most often commercially availableat 17.5 lb/gal (2.10 SG) and 18.3 lb/gal (2.20 SG).Like potassium formate, cesium formate providesexcellent thermal stability on natural polymers,clay stabilization and shale-swelling inhibition.

Miscellaneous Blends• Sodium Chloride/Calcium Chloride• Potassium Bromide

2·3

MONOVALENT BRINES

2·4

Densitylb/gal NaCl Water NaCl Na+ Cl– TCT@70° F lb/bbl bbl/bbl wt % mg/L mg/L ° F

8.33 0.0 1.000 0.0 0 0 32

8.40 3.7 0.998 1.0 4,133 6,350 31

8.50 9.6 0.993 2.7 10,710 16,524 29

8.60 16.2 0.986 4.4 18,060 27,761 27

8.70 22.2 0.981 6.0 24,638 38,106 25

8.80 28.1 0.976 7.5 31,258 48,259 23

8.90 34.8 0.969 9.2 38,662 59,701 21

9.00 41.0 0.962 10.7 45,576 70,200 19

9.10 47.7 0.955 12.4 53,071 81,900 16

9.20 54.3 0.948 13.9 60,389 93,178 14

9.30 61.3 0.940 15.5 68,188 105,239 11

9.40 68.0 0.933 17.1 75,576 116,748 8

9.50 74.6 0.926 18.5 82,992 128,022 5

9.60 81.3 0.919 20.0 90,432 139,507 1

9.70 88.6 0.910 21.5 98,474 152,135 –2

9.80 95.6 0.902 23.0 106,310 164,052 –6

9.90 102.3 0.895 24.4 113,810 175,586 12

10.00 109.0 0.890 25.7 121,200 187,080 25


Sodium Chloride NaCl (U.S.)

Mixing dry NaCl (99%) and water


MONOVALENT BRINES

2·5

Density NaCllb/gal 10.0 lb/gal Water TCT@70° F bbl/bbl bbl/bbl ° F

8.33 0.000 1.000 32

8.40 0.034 0.968 31

8.50 0.088 0.914 29

8.60 0.149 0.854 27

8.70 0.204 0.799 25

8.80 0.259 0.746 23

8.90 0.320 0.684 21

9.00 0.377 0.628 19

9.10 0.439 0.566 16

9.20 0.500 0.505 14

9.30 0.564 0.439 11

9.40 0.626 0.377 8

9.50 0.686 0.317 5

9.60 0.748 0.255 1

9.70 0.815 0.186 –2

9.80 0.879 0.121 –6

9.90 0.941 0.059 12

10.00 1.000 0.000 25

Sodium Chloride NaCl (U.S.)

Blending 10.0 lb/gal NaCl (liquid) and water


MONOVALENT BRINES

2·6

Densitylb/gal KCl Water KCl K Cl– TCT@70° F lb/bbl bbl/bbl wt % mg/L mg/L ° F

8.33 0.0 1.000 0.00 0 0 32

8.40 4.3 0.995 1.21 6,350 5,745 31

8.50 11.6 0.986 3.22 17,237 15,605 29

8.60 19.0 0.977 5.21 28,171 25,592 28

8.70 26.0 0.970 7.04 38,521 34,971 26

8.80 33.4 0.960 8.95 49,522 44,876 24

8.90 41.0 0.950 10.86 60,871 55,104 22

9.00 47.7 0.943 12.49 70,734 64,147 20

9.10 55.7 0.932 14.43 82,658 74,905 18

9.20 62.7 0.924 16.06 93,060 84,339 16

9.30 69.4 0.917 17.59 102,999 93,290 14

9.40 76.8 0.908 19.26 113,919 103,317 12

9.50 84.1 0.898 20.87 124,706 113,079 23

9.60 91.5 0.890 22.47 135,695 123,024 38

9.70 98.6 0.882 23.96 146,303 132,569 54


Potassium Chloride KCl (U.S.)

Mixing dry KCl (99%) and water


MONOVALENT BRINES

2·7

Density NaBrlb/gal Water 97% dry NaBr Na Br TCT@70° F bbl/bbl lb/bbl wt % mg/L mg/L ° F

9.0 0.973 37.9 9.73 23,434 81,533 24

9.1 0.969 43.4 11.01 26,861 93,359 23

9.2 0.965 48.9 12.28 30,247 105,203 0

9.3 0.961 54.5 13.53 33,701 117,282 21

9.4 0.957 60.2 14.79 37,334 129,597 19

9.5 0.953 65.8 16.00 40,809 141,577 17

9.6 0.948 71.5 17.20 44,233 153,895 16

9.7 0.944 77.2 18.38 47,837 166,090 14

9.8 0.940 83.0 19.56 51,387 178,620 12

9.9 0.935 88.7 20.69 54,881 190,896 11

10.0 0.931 94.5 21.83 58,555 203,384 9

10.1 0.926 100.3 22.94 62,171 215,840 7

10.2 0.922 106.1 24.02 65,724 228,258 5

10.3 0.917 111.9 25.09 69,334 240,754 4

10.4 0.912 117.8 26.16 73,002 253,449 2

10.5 0.907 123.6 27.19 76,602 265,965 0

10.6 0.903 129.5 28.22 80,257 278,673 –2

10.7 0.898 135.3 29.20 83,838 291,188 –4

10.8 0.893 141.2 30.19 87,473 303,888 –6

10.9 0.888 147.1 31.17 91,160 316,511 –7

11.0 0.884 153.0 32.12 94,768 329,182 –9

11.1 0.879 158.9 33.06 98,427 341,897 –11

11.2 0.874 164.7 33.96 102,001 354,384 –13

11.3 0.869 174.6 35.69 108,200 375,718 –14

11.4 0.864 176.5 35.76 109,294 379,863 –16

11.5 0.859 182.4 36.63 113,013 392,441 –18

11.6 0.855 188.3 37.49 116,640 405,179 –19

Sodium Bromide NaBr (U.S.)

Mixing dry NaBr (97%) and water



MONOVALENT BRINES

2·8

Density NaBrlb/gal Water 97% dry NaBr Na Br TCT@70° F bbl/bbl lb/bbl wt % mg/L mg/L ° F

11.7 0.850 194.2 38.33 120,313 417,937 –19

11.8 0.845 200.1 39.16 123,890 430,571 –16

11.9 0.840 206.0 39.98 127,653 443,216 –11

12.0 0.835 211.9 40.78 131,174 456,012 –5

12.1 0.830 217.8 41.57 134,880 468,668 2

12.2 0.826 223.6 42.33 138,483 481,178 10

12.3 0.821 229.5 43.09 142,127 493,830 19

12.4 0.816 235.4 43.84 145,812 506,475 28

12.5 0.811 241.2 44.56 149,388 518,958 37

12.6 0.807 247.2 45.31 153,153 531,879 46

12.7 0.804 252.5 45.92 156,350 543,415 54






MONOVALENT BRINES

2·9

Density NaBrlb/gal 12.5 lb/gal Water TCT@70° F bbl/bbl bbl/bbl ° F

9.0 0.157 0.845 24

9.1 0.180 0.822 23

9.2 0.203 0.800 0

9.3 0.226 0.777 21

9.4 0.250 0.754 19

9.5 0.273 0.731 17

9.6 0.296 0.708 16

9.7 0.320 0.684 14

9.8 0.344 0.660 12

9.9 0.368 0.637 11

10.0 0.392 0.613 9

10.1 0.416 0.588 7

10.2 0.440 0.564 5

10.3 0.464 0.540 4

10.4 0.488 0.516 2

10.5 0.512 0.492 0

10.6 0.537 0.467 –2

10.7 0.561 0.443 –4

10.8 0.585 0.418 –6

10.9 0.610 0.393 –7


Blending 12.5 lb/gal NaBr (liquid) and water



MONOVALENT BRINES

2·10

Density NaBrlb/gal 12.5 lb/gal Water TCT@70° F bbl/bbl bbl/bbl ° F

11.0 0.634 0.369 –9

11.1 0.659 0.344 –11

11.2 0.683 0.320 –13

11.3 0.707 0.295 –14

11.4 0.732 0.270 –16

11.5 0.756 0.246 –18

11.6 0.781 0.221 –19

11.7 0.805 0.196 –19

11.8 0.830 0.172 –16

11.9 0.854 0.147 –11

12.0 0.879 0.122 –5

12.1 0.903 0.098 2

12.2 0.927 0.073 10

12.3 0.951 0.049 19

12.4 0.976 0.024 28

12.5 1.000 0.000 37


Blending 12.5 lb/gal NaBr (liquid) and water



MONOVALENT BRINES

2·11

De

nsi

tyN

aC

l N

aB

r lb

/ga

lW

ate

r(9

9%

) d

ry(9

7%

) d

ryN

aC

lN

aB

rB

rC

l–T

CT

@ 7

0°

Fb

bl/

bb

llb

/bb

llb

/bb

lw

t %

wt

%m

g/L

mg

/L°

F

10.0

0.88

010

9.0

0.0

25.6

90.

000

187,

080

23

10.1

0.87

710

4.6

9.6

24.4

22.

2120

,725

179,

618

24

10.2

0.87

410

0.3

19.3

23.1

74.

3741

,494

172,

094

25

10.3

0.87

295

.928

.921

.95

6.49

62,2

9416

4,63

526

10.4

0.86

991

.638

.620

.75

8.57

82,9

9215

7,12

327

10.5

0.86

687

.248

.219

.58

10.6

110

3,90

614

9,80

727

10.6

0.86

382

.857

.918

.42

12.6

112

4,62

714

2,32

127

10.7

0.86

178

.567

.517

.29

14.5

814

5,46

213

4,79

726

10.8

0.85

874

.177

.216

.18

16.5

116

6,27

512

7,36

526

So

diu

m C

hlo

rid

e/S

od

ium

Bro

mid

e (

Na

Cl/

Na

Br)

U.S

.

Mix

ing

dry

Na

Cl

(99

%),

dry

Na

Br

(97

%)

an

d w

ate

r

Co

mp

osi

tio

n f

or

on

e b

arr

el

of

flu

id

Con

tin

ues

on

nex

t p

age

MONOVALENT BRINES

2·12

De

nsi

tyN

aC

l N

aB

r lb

/ga

lW

ate

r(9

9%

) d

ry(9

7%

) d

ryN

aC

lN

aB

rB

rC

l–T

CT

@ 7

0°

Fb

bl/

bb

llb

/bb

llb

/bb

lw

t %

wt

%m

g/L

mg

/L°

F

10.9

0.85

569

.886

.815

.09

18.4

018

7,05

611

9,77

426

11.0

0.85

265

.496

.514

.01

20.2

620

7,79

311

2,28

525

11.1

0.85

061

.010

6.1

12.9

622

.08

228,

610

104,

907

24

11.2

0.84

756

.711

5.8

11.9

323

.87

249,

363

97,3

7824

11.3

0.84

452

.312

5.4

10.9

125

.63

270,

179

89,8

3325

11.4

0.84

148

.013

5.1

9.92

27.3

629

0,91

382

,414

26

11.5

0.83

943

.614

4.7

8.94

29.0

631

1,69

274

,850

28

11.6

0.83

639

.215

4.4

7.97

30.7

333

2,50

967

,421

29

So

diu

m C

hlo

rid

e/S

od

ium

Bro

mid

e (

Na

Cl/

Na

Br)

U.S

.

Mix

ing

dry

Na

Cl

(99

%),

dry

Na

Br

(97

%)

an

d w

ate

r

Co

mp

osi

tio

n f

or

on

e b

arr

el

of

flu

id

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

MONOVALENT BRINES

2·13

De

nsi

tyN

aC

l N

aB

r lb

/ga

lW

ate

r(9

9%

) d

ry(9

7%

) d

ryN

aC

lN

aB

rB

rC

l–T

CT

@ 7

0°

Fb

bl/

bb

llb

/bb

llb

/bb

lw

t %

wt

%m

g/L

mg

/L°

F

11.7

0.83

334

.916

4.0

7.03

32.3

835

3,21

759

,853

29

11.8

0.83

030

.517

3.7

6.10

33.9

937

3,94

652

,429

29

11.9

0.82

826

.218

3.3

5.18

35.5

839

4,83

344

,871

29

12.0

0.82

521

.819

3.0

4.28

37.1

441

5,58

437

,466

29

12.1

0.82

217

.420

2.6

3.40

38.6

743

6,33

629

,932

30

12.2

0.81

913

.121

2.3

2.53

40.1

845

7,08

022

,415

31

12.3

0.81

78.

722

1.9

1.67

41.6

747

7,81

014

,918

32

12.4

0.81

44.

423

1.6

0.83

43.1

349

8,66

67,

445

32

12.5

0.81

10.

024

1.2

0.00

44.5

651

9,34

60

33

So

diu

m C

hlo

rid

e/S

od

ium

Bro

mid

e (

Na

Cl/

Na

Br)

U.S

.

Mix

ing

dry

Na

Cl

(99

%),

dry

Na

Br

(97

%)

an

d w

ate

r

Co

mp

osi

tio

n f

or

on

e b

arr

el

of

flu

id

Con

tin

ued

from

pre

viou

s p

age

MONOVALENT BRINES

2·14

BrineDensity Pressure 10.0 lb/gal 12.5 lb/galat 60° F Gradient NaCl NaBr TCTlb/gal psi/ft (bbl) (bbl) ° F

10.0 0.520 1.000 0.000 23

10.1 0.525 0.960 0.040 24

10.2 0.530 0.920 0.080 25

10.3 0.536 0.880 0.120 26

10.4 0.541 0.840 0.160 27

10.5 0.546 0.800 0.200 27

10.6 0.551 0.760 0.240 26

10.7 0.556 0.720 0.280 26

10.8 0.562 0.680 0.320 26

10.9 0.567 0.640 0.360 26

11.0 0.572 0.600 0.400 25

11.1 0.577 0.560 0.440 25

11.2 0.582 0.520 0.480 24

11.3 0.588 0.480 0.520 25

11.4 0.593 0.440 0.560 27

11.5 0.598 0.400 0.600 28

11.6 0.603 0.360 0.640 29

11.7 0.608 0.320 0.680 29

11.8 0.613 0.280 0.720 30

11.9 0.618 0.240 0.760 30

12.0 0.623 0.200 0.800 31

12.1 0.628 0.160 0.840 31

12.2 0.633 0.120 0.880 32

12.3 0.639 0.080 0.920 32

12.4 0.644 0.040 0.960 33

12.5 0.650 0.000 1.000 33

Sodium Chloride/Sodium Bromide

NaCl/NaBr Brine

Using 10.0 lb/gal NaCl Brine and

12.5 lb/gal NaBr Brine

To make one barrel

MONOVALENT BRINES

2·15

SpecificGravity NaCl Water NaCl Na+ Cl– TCT


1.00 0.0 1.000 0.0 0.0 0.0 0

1.01 11.1 0.999 0.3 4,181 6,435 –1

1.02 26.7 0.994 1.5 10,278 15,846 –2

1.03 42.4 0.988 2.8 16,375 25,257 –3

1.04 58.1 0.982 4.1 22,472 34,669 –4

1.05 73.7 0.977 5.4 28,569 44,080 –4

1.06 89.4 0.971 6.7 34,666 53,491 –5

1.07 105.1 0.965 7.9 40,763 62,903 –6

1.08 120.7 0.959 9.2 46,860 72,314 –7

1.09 136.4 0.954 10.5 52,957 81,725 –9

1.10 152.1 0.948 11.8 59,054 91,136 –10

1.11 167.7 0.942 13.1 65,151 100,548 –11

1.12 183.4 0.937 14.3 71,248 109,959 –12

1.13 199.1 0.931 15.6 77,345 119,370 –13

1.14 214.7 0.925 16.9 83,442 128,781 –15

1.15 230.4 0.919 18.2 89,539 138,193 –17

1.16 246.1 0.914 19.4 95,636 147,604 –19

1.17 261.7 0.908 20.7 101,733 157,015 –20

1.18 277.4 0.902 22.0 107,830 166,427 –21

1.19 293.1 0.897 23.3 113,928 175,838 –11

1.20 308.7 0.891 24.6 120,025 185,249 –4

Sodium Chloride NaCl (Metric)

Mixing dry NaCl (99%) and water


MONOVALENT BRINES

2·16

Specific NaClGravity 1.2 SG Water TCT

(SG) m3/m3 m3/m3 ° C

1.00 0 1.000 0

1.01 0.035 0.965 –1

1.02 0.085 0.915 –2

1.03 0.135 0.865 –3

1.04 0.186 0.814 –4

1.05 0.236 0.764 –4

1.06 0.287 0.713 –5

1.07 0.337 0.663 –6

1.08 0.387 0.613 –7

1.09 0.438 0.562 –9

1.10 0.488 0.512 –10

1.11 0.539 0.461 –11

1.12 0.589 0.411 –12

1.13 0.639 0.361 –13

1.14 0.690 0.310 –15

1.15 0.740 0.260 –17

1.16 0.791 0.209 –19

1.17 0.841 0.159 –20

1.18 0.891 0.109 –21

1.19 0.942 0.058 –11

1.20 1.000 0.000 –4

Sodium Chloride NaCl (Metric)

Blending 1.2 SG NaCl (liquid) and water


MONOVALENT BRINES

2·17

Specific KCl (99%)Gravity Water dry KCl TCT

(SG) m3/m3 kg/m3 wt % ° C

1.00 0.9983 4.6 0.5 0

1.01 0.9942 15.7 1.6 –1

1.02 0.9882 31.7 3.1 –2

1.03 0.982 47.9 4.7 –2

1.04 0.9756 64.2 6.2 –3

1.05 0.969 80.7 7.7 –4

1.06 0.9623 97.4 9.2 –5

1.07 0.9554 114.2 10.7 –5

1.08 0.9484 131.2 12.2 –6

1.09 0.9412 148.3 13.6 –7

1.10 0.9339 165.5 15.1 –8

1.11 0.9266 182.9 16.5 –9

1.12 0.9191 200.3 17.9 –10

1.13 0.9115 217.9 19.3 –11

1.14 0.9038 235.5 20.7 –6

1.15 0.8961 253.2 22.1 1

1.16 0.8883 270.9 23.4 8

1.17 0.8805 288.7 24.7 15

1.18 0.8726 306.5 26 23


Potassium Chloride KCl (Metric)

Mixing dry KCl (99%) and water


MONOVALENT BRINES

2·18

SpecificGravity NaBr Water NaBr Na Br TCT


1.08 104.6 0.976 9.8 22,694 80,000 –4

1.09 118.5 0.972 10.8 25,699 90,000 –5

1.10 132.4 0.969 11.9 28,704 100,000 –18

1.11 146.2 0.965 12.9 31,709 110,000 –12

1.12 160.1 0.961 14.0 34,714 120,000 –6

1.13 173.9 0.957 15.0 37,719 130,000 –7

1.14 187.8 0.953 16.0 40,725 140,000 –8

1.15 201.6 0.949 17.0 43,730 150,000 –9

1.16 215.5 0.945 18.0 46,735 160,000 –10

1.17 229.4 0.941 18.9 49,740 170,000 –11

1.18 243.2 0.937 19.9 52,745 180,000 –11

1.19 257.1 0.934 20.8 55,750 190,000 –12

1.20 270.9 0.930 21.8 58,755 200,000 –13

1.21 284.8 0.926 22.7 61,760 210,000 –14

1.22 298.6 0.922 23.6 64,765 220,000 –15

1.23 312.5 0.918 24.5 67,771 230,000 –15

1.24 326.3 0.914 25.4 70,776 240,000 –16

1.25 340.2 0.910 26.3 73,781 250,000 –17

1.26 354.1 0.906 27.2 76,786 260,000 –18

1.27 367.9 0.902 28.0 79,791 270,000 –19

1.28 381.8 0.899 28.9 82,796 280,000 –19

1.29 395.6 0.895 29.7 85,801 290,000 –20

Sodium Bromide NaBr (Metric)




MONOVALENT BRINES

2·19

SpecificGravity NaBr Water NaBr Na Br TCT


1.3 409.5 0.891 30.5 88,806 300,000 –21

1.31 423.3 0.887 31.3 91,811 310,000 –22

1.32 437.2 0.883 32.1 94,817 320,000 –23

1.33 451.0 0.879 32.9 97,822 330,000 –24

1.34 464.9 0.875 33.7 100,827 340,000 –24

1.35 478.8 0.871 34.4 103,832 350,000 –25

1.36 492.6 0.867 35.2 106,837 360,000 –26

1.37 506.5 0.864 35.9 109,842 370,000 –27

1.38 520.3 0.860 36.6 112,847 380,000 –28

1.39 534.2 0.856 37.4 115,852 390,000 –28

1.40 548.0 0.852 38.1 118,857 400,000 –28

1.41 561.9 0.848 38.8 121,863 410,000 –28

1.42 575.8 0.844 39.4 124,868 420,000 –27

1.43 589.6 0.840 40.1 127,873 430,000 –24

1.44 603.5 0.836 40.8 130,878 440,000 –21

1.45 617.3 0.832 41.4 133,883 450,000 –17

1.46 631.2 0.829 42.0 136,888 460,000 –15

1.47 645.0 0.825 42.7 139,893 470,000 –12

1.48 658.9 0.821 43.3 142,898 480,000 –7

1.49 672.7 0.817 43.9 145,903 490,000 –2

1.50 686.6 0.813 44.5 148,909 500,000 3

1.51 700.5 0.809 45.0 151,914 510,000 8

1.52 714.3 0.805 45.6 154,919 520,000 10

1.53 728.2 0.801 46.2 157,924 530,000 12





MONOVALENT BRINES

2·20

Specific NaBrGravity 1.5 SG Water TCT

(SG) m3/m3 m3/m3 ° C

1.080 0.157 0.845 –4

1.092 0.180 0.822 –5

1.104 0.203 0.800 –18

1.116 0.226 0.777 –6

1.128 0.250 0.754 –7

1.140 0.273 0.731 –8

1.152 0.296 0.708 –9

1.164 0.320 0.684 –10

1.176 0.344 0.660 –11

1.188 0.368 0.637 –12

1.200 0.392 0.613 –13

1.212 0.416 0.588 –14

1.224 0.440 0.564 –15

1.236 0.464 0.540 –16

1.248 0.488 0.516 –17

1.261 0.512 0.492 –18

1.273 0.537 0.467 –19

1.285 0.561 0.443 –20

1.297 0.585 0.418 –21

1.309 0.610 0.393 –22

1.321 0.634 0.369 –23

1.333 0.659 0.344 –24

1.345 0.683 0.320 –25

1.357 0.707 0.295 –26


Blending 1.5 SG NaBr (liquid) and water



MONOVALENT BRINES

2·21

Specific NaBrGravity 1.5 SG Water TCT

(SG) m3/m3 m3/m3 ° C

1.369 0.732 0.270 –27

1.381 0.756 0.246 –28

1.393 0.781 0.221 –28

1.405 0.805 0.196 –28

1.417 0.830 0.172 –27

1.429 0.854 0.147 –24

1.441 0.879 0.122 –21

1.453 0.903 0.098 –17

1.465 0.927 0.073 –12

1.477 0.951 0.049 –7

1.489 0.976 0.024 –2

1.501 1.000 0.000 3


Blending 1.5 SG NaBr (liquid) and water



MONOVALENT BRINES

2·22

Sp

eci

fic

Na

Cl

Na

Br

Gra

vit

yW

ate

r(9

9%

) d

ry(9

7%

) d

ryN

aC

lN

aB

rB

rC

l–T

CT

(SG

)m

3/m

3k

g/m

3k

g/m

3w

t %

wt

%m

g/L

mg

/L°

C

1.20

00.

880

311.

30.

025

.69

0.00

018

7,08

0–5

1.21

20.

877

298.

727

.424

.42

2.21

20,7

2517

9,61

8–4

1.22

40.

874

286.

555

.123

.17

4.37

41,4

9417

2,09

4–4

1.23

60.

872

273.

982

.521

.95

6.49

62,2

9416

4,63

5–3

1.24

80.

869

261.

611

0.2

20.7

58.

5782

,992

157,

123

–3

1.26

10.

866

249.

013

7.7

19.5

810

.61

103,

906

149,

807

–3

1.27

30.

863

236.

516

5.4

18.4

212

.61

124,

627

142,

321

–3

1.28

50.

861

224.

219

2.8

17.2

914

.58

145,

462

134,

797

–3

1.29

70.

858

211.

622

0.5

16.1

816

.51

166,

275

127,

365

–3

So

diu

m C

hlo

rid

e/S

od

ium

Bro

mid

e N

aC

l/N

aB

r (M

etr

ic)

Mix

ing

dry

Na

Cl

(99

%),

dry

Na

Br

(97

%)

an

d w

ate

r

Co

mp

osi

tio

n f

or

on

e m

3o

f fl

uid

Con

tin

ues

on

nex

t p

age

MONOVALENT BRINES

2·23

Sp

eci

fic

Na

Cl

Na

Br

Gra

vit

yW

ate

r(9

9%

) d

ry(9

7%

) d

ryN

aC

lN

aB

rB

rC

l–T

CT

(SG

)m

3/m

3k

g/m

3k

g/m

3w

t %

wt

%m

g/L

mg

/L°

C

1.30

90.

855

199.

324

7.9

15.0

918

.40

187,

056

119,

774

–3

1.32

10.

852

186.

827

5.6

14.0

120

.26

207,

793

112,

285

–4

1.33

30.

850

174.

230

3.0

12.9

622

.08

228,

610

104,

907

–4

1.34

50.

847

161.

933

0.7

11.9

323

.87

249,

363

97,3

78–4

1.35

70.

844

149.

435

8.1

10.9

125

.63

270,

179

89,8

33–4

1.36

90.

841

137.

138

5.8

9.92

27.3

629

0,91

382

,414

–3

1.38

10.

839

124.

541

3.3

8.94

29.0

631

1,69

274

,850

–2

So

diu

m C

hlo

rid

e/S

od

ium

Bro

mid

e N

aC

l/N

aB

r (M

etr

ic)

Mix

ing

dry

Na

Cl

(99

%),

dry

Na

Br

(97

%)

an

d w

ate

r

Co

mp

osi

tio

n f

or

on

e m

3o

f fl

uid

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

MONOVALENT BRINES

2·24

Sp

eci

fic

Na

Cl

Na

Br

Gra

vit

yW

ate

r(9

9%

) d

ry(9

7%

) d

ryN

aC

lN

aB

rB

rC

l–T

CT

(SG

)m

3/m

3k

g/m

3k

g/m

3w

t %

wt

%m

g/L

mg

/L°

C

1.39

30.

836

112.

044

1.0

7.97

30.7

333

2,50

967

,421

–2

1.40

50.

833

99.7

468.

47.

0332

.38

353,

217

59,8

53–2

1.41

70.

830

87.1

496.

16.

1033

.99

373,

946

52,4

29–2

1.42

90.

828

74.8

523.

55.

1835

.58

394,

833

44,8

71–2

1.44

10.

825

62.3

551.

24.

2837

.14

415,

584

37,4

66–2

1.45

30.

822

49.7

578.

63.

4038

.67

436,

336

29,9

32–1

1.46

50.

819

37.4

606.

32.

5340

.18

457,

080

22,4

15–1

So

diu

m C

hlo

rid

e/S

od

ium

Bro

mid

e N

aC

l/N

aB

r (M

etr

ic)

Mix

ing

dry

Na

Cl

(99

%),

dry

Na

Br

(97

%)

an

d w

ate

r

Co

mp

osi

tio

n f

or

on

e m

3o

f fl

uid

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

MONOVALENT BRINES

2·25

Sp

eci

fic

Na

Cl

Na

Br

Gra

vit

yW

ate

r(9

9%

) d

ry(9

7%

) d

ryN

aC

lN

aB

rB

rC

l–T

CT

(SG

)m

3/m

3k

g/m

3k

g/m

3w

t %

wt

%m

g/L

mg

/L°

C

1.47

70.

817

24.8

633.

71.

6741

.67

477,

810

14,9

180

1.48

90.

814

12.6

661.

40.

8343

.13

498,

666

7,44

50

1.50

10.

811

0.0

688.

90.

0044

.56

519,

346

01

To c

alcu

late

par

ts p

er m

illio

n, d

ivid

e m

g/L

by th

e sp

ecif

ic g

ravi

ty.

So

diu

m C

hlo

rid

e/S

od

ium

Bro

mid

e N

aC

l/N

aB

r (M

etr

ic)

Mix

ing

dry

Na

Cl

(99

%),

dry

Na

Br

(97

%)

an

d w

ate

r

Co

mp

osi

tio

n f

or

on

e m

3o

f fl

uid

Con

tin

ued

from

pre

viou

s p

age

MONOVALENT BRINES

2·26

Specific NaCl NaBrGravity 1.2 SG 1.5 SG TCT

(SG) m3 m3 ° C

1.200 1.000 0.000 –5

1.212 0.960 0.040 –4

1.224 0.920 0.080 –4

1.236 0.880 0.120 –3

1.248 0.840 0.160 –3

1.261 0.800 0.200 –3

1.273 0.760 0.240 –3

1.285 0.720 0.280 –3

1.297 0.680 0.320 –3

1.309 0.640 0.360 –3

1.321 0.600 0.400 –4

1.333 0.560 0.440 –4

1.345 0.520 0.480 –4

1.357 0.480 0.520 –4

1.369 0.440 0.560 –3

1.381 0.400 0.600 –2

1.393 0.360 0.640 –2

1.405 0.320 0.680 –2

1.417 0.280 0.720 –2

1.429 0.240 0.760 –2

1.441 0.200 0.800 –2


NaCl/NaBr (Metric)

Blending 1.2 SG NaCl (liquid),

1.5 SG NaBr (liquid) and water



MONOVALENT BRINES

2·27

Specific NaCl NaBrGravity 1.2 SG 1.5 SG TCT

(SG) m3 m3 ° C

1.453 0.160 0.840 –1

1.465 0.120 0.880 –1

1.477 0.080 0.920 0

1.489 0.040 0.960 0

1.501 0.000 1.000 1



NaCl/NaBr (Metric)

Blending 1.2 SG NaCl (liquid),

1.5 SG NaBr (liquid) and water



MONOVALENT BRINES

2·28

Density 96% lb/gal NaHCO2 Water TCT@70° F lb/bbl bbl/bbl ° F

8.4 5.86 0.9929 31

8.5 12.23 0.9867 29

8.6 18.71 0.9801 27

8.7 25.31 0.9733 25

8.8 32.02 0.9661 23

8.9 38.86 0.9585 20

9.0 45.83 0.9506 18

9.1 52.92 0.9423 16

9.2 60.14 0.9337 13

9.3 67.49 0.9247 11

9.4 74.98 0.9153 8

9.5 82.60 0.9055 6

9.6 90.36 0.8953 3

9.7 98.26 0.8847 6

9.8 106.30 0.8737 9

9.9 114.50 0.8623 12

10.0 122.80 0.8504 15

10.1 131.30 0.8382 18

10.2 140.00 0.8254 22

10.3 148.80 0.8123 27

10.4 157.70 0.7986 32

10.5 166.90 0.7845 38

10.6 176.10 0.7700 44

10.7 185.60 0.7549 49

10.8 195.20 0.7394 54

10.9 205.00 0.7233 59

11.0 215.00 0.7068 70

Sodium Formate NaHCO2 (U.S.)

Mixing dry NaHCO2 (96%) and water


MONOVALENT BRINES

2·29

Density KHCO2

lb/gal Water dry KHCO2 TCT@60° F bbl/bbl lb/bbl wt % ° F

8.5 0.9896 7.2 2.0 30

8.6 0.9696 21.2 5.8 29

8.7 0.9593 28.1 7.6 28

8.8 0.9504 34.9 9.4 26

8.9 0.9410 41.7 11.1 25

9.0 0.9318 48.4 12.8 23

9.1 0.9135 61.9 16.0 20

9.2 0.9044 68.6 17.6 18

9.3 0.8953 75.3 19.1 15

9.4 0.8862 81.9 20.6 12

9.5 0.8771 88.6 22.1 10

9.6 0.8680 95.3 23.6 6

9.7 0.8496 108.8 26.4 3

9.8 0.8402 115.6 27.8 0

9.9 0.8308 122.4 29.2 –4

10.0 0.8213 129.2 30.6 –8

10.1 0.8116 136.1 32.0 –12

10.2 0.7920 150.0 34.7 –16

10.3 0.7820 157.0 36.0 –20

10.4 0.7719 164.0 37.3 –24

10.5 0.7617 171.2 38.6 –28

10.6 0.7514 178.3 39.9 –32

10.7 0.7303 192.7 42.4 –37

10.8 0.7196 199.9 43.7 –41

10.9 0.7087 207.2 44.9 –46

11.0 0.6978 214.6 46.2 –50

11.1 0.6868 221.9 47.4 –55

Potassium Formate KHCO2 (U.S.)

Mixing dry KHCO2 and water



MONOVALENT BRINES

2·30

Density KHCO2

lb/gal Water dry KHCO2 TCT@60° F bbl/bbl lb/bbl wt % ° F

11.2 0.6644 236.8 49.8 –59

11.3 0.6530 244.3 51.0 –64

11.4 0.6416 251.8 52.2 –69

11.5 0.6301 259.3 53.4 –73

11.6 0.6185 266.9 54.5 –75

11.7 0.5951 282.1 56.8 –69

11.8 0.5833 289.7 57.9 –63

11.9 0.5715 297.4 59.0 –57

12.0 0.5596 305.1 60.1 –51

12.1 0.5475 312.8 61.2 –45

12.2 0.5233 328.3 63.4 –39

12.3 0.5110 336.1 64.5 –33

12.4 0.4986 344.0 65.5 –28

12.5 0.4861 351.8 66.6 –21

12.6 0.4735 359.8 67.6 –15

12.7 0.4478 375.8 69.7 –9

12.8 0.4347 383.9 70.7 –3

12.9 0.4213 392.1 71.8 3

13.0 0.4077 400.4 72.8 9

13.1 0.3938 408.8 73.9 16

13.2 0.3795 417.3 74.9 22





MONOVALENT BRINES

2·31

Density KHCO2


8.4 0.0183 0.9817 30

8.5 0.0365 0.9635 29

8.6 0.0547 0.9453 28

8.7 0.0730 0.9270 26

8.8 0.0915 0.9085 25

8.9 0.1101 0.8899 23

9.0 0.1287 0.8713 20

9.1 0.1475 0.8525 18

9.2 0.1664 0.8336 15

9.3 0.1854 0.8146 12

9.4 0.2045 0.7955 10

9.5 0.2238 0.7762 6

9.6 0.2432 0.7568 3

9.7 0.2626 0.7374 0

9.8 0.2822 0.7178 –4

9.9 0.3019 0.6981 –8

10.0 0.3218 0.6782 –12

10.1 0.3418 0.6582 –16

10.2 0.3618 0.6382 –20

10.3 0.3821 0.6179 –24

10.4 0.4024 0.5976 –28

10.5 0.4229 0.5771 –32

10.6 0.4435 0.5565 –37

10.7 0.4642 0.5358 –41

10.8 0.4850 0.5150 –46

10.9 0.5060 0.4940 –50

11.0 0.5271 0.4729 –55


Blending 13.1 lb/gal KHCO2 (liquid) and water



MONOVALENT BRINES

2·32

Density KHCO2


11.1 0.5484 0.4516 –59

11.2 0.5698 0.4302 –64

11.3 0.5913 0.4087 –69

11.4 0.6129 0.3871 –73

11.5 0.6347 0.3653 –75

11.6 0.6567 0.3433 –69

11.7 0.6787 0.3213 –63

11.8 0.7009 0.2991 –57

11.9 0.7233 0.2767 –51

12.0 0.7458 0.2542 –45

12.1 0.7684 0.2316 –39

12.2 0.7912 0.2088 –33

12.3 0.8113 0.1887 –28

12.4 0.8372 0.1628 –21

12.5 0.8604 0.1396 –15

12.6 0.8837 0.1163 –9

12.7 0.9072 0.0928 –3

12.8 0.9309 0.0691 3

12.9 0.9547 0.0453 9

13.0 0.9786 0.0214 16

13.1 1.0000 0.0000 22


Blending 13.1 lb/gal KHCO2 (liquid) and water



MONOVALENT BRINES

2·33

13.1 Density 96% lb/gallb/gal NaHCO2 Water KHCO2 NaHCO2 KHCO2 TCT@70° F lb/bbl bbl/bbl bbl/bbl wt % wt % ° F

11.0 215.0 0.707 0.000 46.5 0.0 60

11.1 204.7 0.673 0.048 43.9 3.6 57

11.2 194.6 0.640 0.095 41.4 7.1 53

11.3 184.3 0.606 0.143 38.8 10.7 50

11.4 174.2 0.573 0.190 36.4 14.3 47

11.5 163.8 0.539 0.238 33.9 17.9 44

11.6 153.5 0.505 0.286 31.5 21.5 40

11.7 143.4 0.471 0.333 29.2 25.0 35

11.8 133.1 0.438 0.381 26.9 28.6 30

11.9 122.8 0.404 0.429 24.6 32.2 26

12.0 112.7 0.370 0.476 22.4 35.7 22

12.1 102.3 0.336 0.524 20.1 39.3 23

12.2 92.2 0.303 0.571 18.0 42.8 24

12.3 81.9 0.269 0.619 15.9 46.4 26

12.4 71.6 0.235 0.667 13.7 50.0 27

12.5 61.5 0.202 0.714 11.7 53.6 27

12.6 51.2 0.168 0.762 9.7 57.2 27

12.7 40.9 0.134 0.810 7.7 60.8 27

12.8 30.7 0.101 0.857 5.7 64.3 27

12.9 20.4 0.067 0.905 3.8 67.9 27

13.0 10.3 0.034 0.952 1.9 71.4 27

13.1 0.0 0.000 1.000 0.0 75.0 28

Sodium Formate/Potassium Formate

NaHCO2/KHCO2 (U.S.)

Mixing dry NaHCO2 (96%),

13.1 lb/gal KHCO2 and water


MONOVALENT BRINES

2·34

Density 17.5 lb/gal 13.1 lb/gallb/gal Density CsHCO2 KHCO2

@70° F (SG) bbl/bbl bbl/bbl

13.08 1.57 0.000 1.000

13.17 1.58 0.019 0.981

13.25 1.59 0.038 0.962

13.33 1.60 0.057 0.943

13.42 1.61 0.075 0.925

13.50 1.62 0.094 0.906

13.58 1.63 0.113 0.887

13.67 1.64 0.132 0.868

13.75 1.65 0.151 0.849

13.83 1.66 0.170 0.830

13.92 1.67 0.189 0.811

14.00 1.68 0.208 0.792

14.08 1.69 0.226 0.774

14.17 1.70 0.245 0.755

14.25 1.71 0.264 0.736

14.33 1.72 0.283 0.717

14.42 1.73 0.302 0.698

14.50 1.74 0.321 0.679

14.58 1.75 0.340 0.660

14.67 1.76 0.358 0.642

14.75 1.77 0.377 0.623

14.83 1.78 0.396 0.604

14.92 1.79 0.415 0.585

15.00 1.80 0.434 0.566

15.08 1.81 0.453 0.547

15.17 1.82 0.472 0.528

Cesium Formate/Potassium Formate

CsHCO2/KHCO2 (U.S.)

Blending 17.5 lb/gal CsHCO2 and

13.1 lb/gal KHCO2



MONOVALENT BRINES

2·35



15.25 1.83 0.491 0.509

15.33 1.84 0.509 0.491

15.42 1.85 0.528 0.472

15.50 1.86 0.547 0.453

15.58 1.87 0.566 0.434

15.67 1.88 0.585 0.415

15.75 1.89 0.604 0.396

15.83 1.90 0.623 0.377

15.92 1.91 0.642 0.358

16.00 1.92 0.660 0.340

16.08 1.93 0.679 0.321

16.17 1.94 0.698 0.302

16.25 1.95 0.717 0.283

16.33 1.96 0.736 0.264

16.42 1.97 0.755 0.245

16.50 1.98 0.774 0.226

16.58 1.99 0.792 0.208

16.67 2.00 0.811 0.189

16.75 2.01 0.830 0.170

16.83 2.02 0.849 0.151

16.92 2.03 0.868 0.132

17.00 2.04 0.887 0.113

17.08 2.05 0.906 0.094



CsHCO2/KHCO2 (U.S.)


13.1 lb/gal KHCO2



MONOVALENT BRINES

2·36



17.17 2.06 0.925 0.075

17.25 2.07 0.943 0.057

17.33 2.08 0.962 0.038

17.42 2.09 0.981 0.019

17.50 2.10 1.000 0.000

These formulations provided by CABOT.



CsHCO2/KHCO2 (U.S.)


13.1 lb/gal KHCO2


MONOVALENT BRINES

2·37


CsHCO2/KHCO2 (U.S.)


13.1 lb/gal KHCO2


Density CsHCO2 KHCO2

lb/gal 18.3 lb/gal 13.1 lb/gal Density@70° F bbl/bbl bbl/bbl SG

13.08 0.000 1.000 1.57

13.17 0.016 0.984 1.58

13.25 0.032 0.968 1.59

13.33 0.048 0.952 1.60

13.42 0.063 0.937 1.61

13.50 0.079 0.921 1.62

13.58 0.095 0.905 1.63

13.67 0.111 0.889 1.64

13.75 0.127 0.873 1.65

13.83 0.143 0.857 1.66

13.92 0.159 0.841 1.67

14.00 0.175 0.825 1.68

14.08 0.190 0.810 1.69

14.17 0.206 0.794 1.70

14.25 0.222 0.778 1.71

14.33 0.238 0.762 1.72

14.42 0.254 0.746 1.73

14.50 0.270 0.730 1.74

14.58 0.286 0.714 1.75

14.67 0.302 0.698 1.76

14.75 0.317 0.683 1.77

14.83 0.333 0.667 1.78

14.92 0.349 0.651 1.79

15.00 0.365 0.635 1.80

15.08 0.381 0.619 1.81

15.17 0.397 0.603 1.82


MONOVALENT BRINES

2·38


CsHCO2/KHCO2 (U.S.)


13.1 lb/gal KHCO2




15.25 0.413 0.587 1.83

15.33 0.429 0.571 1.84

15.42 0.444 0.556 1.85

15.50 0.460 0.540 1.86

15.58 0.476 0.524 1.87

15.67 0.492 0.508 1.88

15.75 0.508 0.492 1.89

15.83 0.524 0.476 1.90

15.92 0.540 0.460 1.91

16.00 0.556 0.444 1.92

16.08 0.571 0.429 1.93

16.17 0.587 0.413 1.94

16.25 0.603 0.397 1.95

16.33 0.619 0.381 1.96

16.42 0.635 0.365 1.97

16.50 0.651 0.349 1.98

16.58 0.667 0.333 1.99

16.67 0.683 0.317 2.00

16.75 0.698 0.302 2.01

16.83 0.714 0.286 2.02

16.92 0.730 0.270 2.03

17.00 0.746 0.254 2.04

17.08 0.762 0.238 2.05

17.17 0.778 0.222 2.06

17.25 0.794 0.206 2.07



MONOVALENT BRINES

2·39


CsHCO2/KHCO2 (U.S.)


13.1 lb/gal KHCO2




17.33 0.810 0.190 2.08

17.42 0.825 0.175 2.09

17.50 0.841 0.159 2.10

17.58 0.857 0.143 2.11

17.67 0.873 0.127 2.12

17.75 0.889 0.111 2.13

17.83 0.905 0.095 2.14

17.92 0.921 0.079 2.15

18.00 0.937 0.063 2.16

18.08 0.952 0.048 2.17

18.17 0.968 0.032 2.18

18.25 0.984 0.016 2.19

18.33 1.000 0.000 2.20

These formulations provided by CABOT.


MONOVALENT BRINES

2·40

Sodium Formate NaHCO2 (Metric)

Mixing dry KHCO2 (96%) and water


Specific NaHCO2 (96%)Gravity Water dry TCT

(SG) m3/m3 kg/m3 ° C

1.01 0.9927 17.26 –1

1.02 0.9875 32.36 –2

1.03 0.9822 47.68 –3

1.04 0.9766 63.23 –3

1.05 0.9707 79.02 –4

1.06 0.9647 95.05 –5

1.07 0.9583 111.3 –7

1.08 0.9518 127.8 –7

1.09 0.9450 144.6 –8

1.10 0.9379 161.6 –10

1.11 0.9306 178.9 –11

1.12 0.9230 196.4 –12

1.13 0.9151 214.2 –13

1.14 0.9070 232.3 –14

1.15 0.8986 250.6 –16

1.16 0.8899 269.2 –16

1.17 0.8810 288.1 –14

1.18 0.8717 307.3 –13

1.19 0.8622 326.8 –11

1.20 0.8524 346.6 –10

1.21 0.8423 366.6 –8

1.22 0.8318 387.0 –7

1.23 0.8211 407.7 –4

1.24 0.8100 428.6 –2

1.25 0.7987 449.9 0

1.26 0.7870 471.6 3


MONOVALENT BRINES

2·41

Sodium Formate NaHCO2 (Metric)

Mixing dry KHCO2 (96%) and water


Specific NaHCO2

Gravity Water (96%) dry TCT(SG) m3/m3 kg/m3 ° C

1.27 0.7750 493.5 6

1.28 0.7626 515.8 8

1.29 0.7499 538.4 11

1.30 0.7369 561.4 13

1.31 0.7235 584.7 15

1.32 0.7098 608.3 20


MONOVALENT BRINES

2·42

Specific KHCO2

Gravity Water dry KHCO2 TCT(SG) m3/m3 kg/m3 wt % ° C

1.01 0.9896 20.4 2.0 –1

1.02 0.9795 40.5 3.9 –2

1.03 0.9696 60.4 5.8 –3

1.04 0.9593 80.1 7.6 –3

1.05 0.9504 99.6 9.4 –4

1.06 0.9410 119.0 11.1 –5

1.07 0.9318 138.2 12.8 –6

1.08 0.9226 157.4 14.4 –7

1.09 0.9135 176.5 16.0 –8

1.10 0.9044 195.6 17.6 –9

1.11 0.8953 214.7 19.1 –11

1.12 0.8862 233.8 20.6 –12

1.13 0.8771 252.8 22.1 –13

1.14 0.8680 272.0 23.6 –15

1.15 0.8588 291.2 25.0 –16

1.16 0.8496 310.4 26.4 –18

1.17 0.8402 329.8 27.8 –19

1.18 0.8308 349.2 29.2 –21

1.19 0.8213 368.7 30.6 –23

1.20 0.8116 388.4 32.0 –25

1.21 0.8019 408.1 33.3 –26

1.22 0.7920 428.0 34.7 –28

1.23 0.7820 448.0 36.0 –30

1.24 0.7719 468.0 37.3 –32

1.25 0.7617 488.3 38.6 –34

1.26 0.7514 508.6 39.9 –36

1.27 0.7409 529.1 41.2 –39

Potassium Formate KHCO2 (Metric)




MONOVALENT BRINES

2·43

Specific KHCO2


1.28 0.7303 549.7 42.4 –41

1.29 0.7196 570.4 43.7 –43

1.30 0.7087 591.2 44.9 –45

1.31 0.6978 612.2 46.2 –48

1.32 0.6868 633.2 47.4 –50

1.33 0.6756 654.4 48.6 –52

1.34 0.6644 675.6 49.8 –55

1.35 0.6530 696.9 51.0 –57

1.36 0.6416 718.4 52.2 –60

1.37 0.6301 739.9 53.4 –61

1.38 0.6185 761.5 54.5 –58

1.39 0.6069 783.1 55.7 –56

1.40 0.5951 804.8 56.8 –53

1.41 0.5833 826.6 57.9 –50

1.42 0.5715 848.5 59.0 –48

1.43 0.5596 870.5 60.1 –45

1.44 0.5475 892.5 61.2 –42

1.45 0.5354 914.6 62.3 –39

1.46 0.5233 936.7 63.4 –36

1.47 0.5110 959.0 64.5 –33

1.48 0.4986 981.4 65.5 –31

1.49 0.4861 1003.8 66.6 –28

1.50 0.4735 1026.5 67.6 –25

1.51 0.4608 1049.2 68.6 –22

1.52 0.4478 1072.2 69.7 –19

1.53 0.4347 1095.3 70.7 –16






MONOVALENT BRINES

2·44

Specific KHCO2


1.54 0.4213 1118.6 71.8 –13

1.55 0.4077 1142.3 72.8 –10

1.56 0.3938 1166.2 73.9 –8

1.57 0.3795 1190.5 74.9 –5

1.58 0.3649 1215.1 76.0 –2





MONOVALENT BRINES

2·45


Blending 1.57 SG KHCO2 (liquid) and water


Density KHCO2

lb/gal 1.57 SG Water TCT@ 70° F m3/m3 m3/m3 ° C

1.01 0.0189 0.9811 –1

1.02 0.0338 0.9662 –2

1.03 0.0488 0.9512 –2

1.04 0.0639 0.9361 –3

1.05 0.0791 0.9209 –4

1.06 0.0944 0.9056 –5

1.07 0.1097 0.8903 –6

1.08 0.1252 0.8748 –6

1.09 0.1407 0.8593 –7

1.10 0.1563 0.8437 –8

1.11 0.1720 0.8280 –9

1.12 0.1877 0.8123 –10

1.13 0.2036 0.7964 –12

1.14 0.2195 0.7805 –13

1.15 0.2355 0.7645 –14

1.16 0.2516 0.7484 –15

1.17 0.2678 0.7322 –17

1.18 0.2840 0.7160 –18

1.19 0.3004 0.6996 –20

1.20 0.3168 0.6832 –21

1.21 0.3333 0.6667 –23

1.22 0.3499 0.6501 –24

1.23 0.3666 0.6334 –26

1.24 0.3834 0.6166 –28

1.25 0.4003 0.5997 –30

1.26 0.4173 0.5827 –32


MONOVALENT BRINES

2·46




Density KHCO2


1.27 0.4343 0.5657 –34

1.28 0.4515 0.5485 –36

1.29 0.4687 0.5313 –39

1.30 0.4860 0.5140 –41

1.31 0.5035 0.4965 –43

1.32 0.5210 0.4790 –46

1.33 0.5386 0.4614 –49

1.34 0.5563 0.4437 –51

1.35 0.5741 0.4259 –54

1.36 0.5919 0.4081 –57

1.37 0.6099 0.3901 –58

1.38 0.6280 0.3720 –54

1.39 0.6462 0.3538 –51

1.40 0.6644 0.3356 –47

1.41 0.6828 0.3172 –52

1.42 0.7012 0.2988 –49

1.43 0.7198 0.2802 –47

1.44 0.7385 0.2615 –44

1.45 0.7572 0.2428 –41

1.46 0.7761 0.2239 –38

1.47 0.7950 0.2050 –36

1.48 0.8141 0.1859 –33

1.49 0.8332 0.1668 –30

1.50 0.8525 0.1475 –27

1.51 0.8718 0.1282 –24



MONOVALENT BRINES

2·47




Density KHCO2


1.52 0.8913 0.1087 –22

1.53 0.9109 0.0891 –19

1.54 0.9305 0.0695 –16

1.55 0.9503 0.0497 –13

1.56 0.9702 0.0298 –10

1.57 0.9901 0.0099 –8


MONOVALENT BRINES

2·48

Specific %Gravity lb NH4CL bbl NH4CL

Density (SG) per bbl Water/ Weight/lb/gal at 60° F Brine bbl Brine Weight

8.4 1.007 7 0.990 1.98

8.45 1.013 10.5 0.981 3.0

8.5 1.020 19 0.969 5.3

8.6 1.031 30 0.940 8.4

8.7 1.044 42 0.919 11.5

8.8 1.055 53 0.900 14.4

8.9 1.068 65 0.881 17.4

9.0 1.079 77 0.860 20.4

9.1 1.128 88 0.840 23.0

9.2 1.103 100 0.819 25.8

9.3 1.139 135 0.750 33.9

NH4Cl Brine (U.S.)


MONOVALENT BRINES

2·49

Sp

eci

fic

So

luti

on

We

igh

tU

sin

g 9

4 t

o 9

7%

Ca

Cl 2

an

d N

aC

lU

sin

g 7

7 t

o 8

0%

Ca

Cl 2

an

d N

aC

l

Gra

vit

yF

resh

-F

resh

-p

si o

fF

ree

zin

g(S

G)

at

lb/g

al

at

lb/f

t3a

tC

aC

l 2N

aC

lw

ate

rC

aC

l 2N

aC

lw

ate

rft

Po

int

60

° F

60

° F

60

° F

lblb

ga

llb

lbg

al

De

pth

° F

1.21

10.1

75.5

629

8836

.836

8835

.80.

524

–4

1.22

10.2

76.3

152

7036

.864

7035

.10.

529

–10

1.23

10.2

576

.68

6262

36.8

76.5

6234

.70.

532

–12

1.24

10.3

77.0

572

5436

.889

5434

.30.

535

–15

1.25

10.4

77.8

8941

36.8

110

4133

.80.

54–2

1

1.26

10.5

78.5

510

432

36.7

128

3232

.80.

545

–26

1.27

10.6

79.3

116

2536

.514

325

32.6

0.55

–32

1.28

10.7

80.0

512

620

36.4

155

2032

.20.

555

–38

Co

mb

ina

tio

n S

od

ium

Ch

lori

de

–C

alc

ium

Ch

lori

de

So

luti

on

s

Ma

teri

als

to

pre

pa

re o

ne

ba

rre

l o

f fl

uid

Con

tin

ues

on

nex

t p

age

MONOVALENT BRINES

2·50

Con

tin

ued

from

pre

viou

s p

age

Sp

eci

fic

So

luti

on

We

igh

tU

sin

g 9

4 t

o 9

7%

Ca

Cl 2

an

d N

aC

lU

sin

g 7

7 t

o 8

0%

Ca

Cl 2

an

d N

aC

l

Gra

vit

yF

resh

-F

resh

-p

si o

fF

ree

zin

g(S

G)

at

lb/g

al

at

lb/f

t3a

tC

aC

l 2N

aC

lw

ate

rC

aC

l 2N

aC

lw

ate

rft

Po

int

60

° F

60

° F

60

° F

lblb

ga

llb

lbg

al

De

pth

° F

1.29

10.7

580

.42

131

1836

.316

118

32.0

0.55

8–4

0

1.30

10.8

80.7

913

516

36.3

167

1631

.70.

561

–42

1.31

10.9

81.5

414

413

36.2

178

1331

.30.

566

–24

1.32

1182

.29

151

1036

.118

610

31.0

0.57

1–1

2

1.33

11.1

83.0

415

98

3619

68

30.6

0.57

60

Co

mb

ina

tio

n S

od

ium

Ch

lori

de

–C

alc

ium

Ch

lori

de

So

luti

on

s

Ma

teri

als

to

pre

pa

re o

ne

ba

rre

l o

f fl

uid

MONOVALENT BRINES

2·51

Potassium Bromide KBr

Molecular Weight = 119.01

Relative Specific Refractivity = 0.627

Specific CrystallizationKBr by Density Gravity Temperaturewt % lb/gal (SG) ° F

1 8 1 32

1 8 1 31

2 8 1 31

2 8 1 31

3 8 1 31

3 9 1 30

4 9 1 30

4 9 1 30

5 9 1 30

5 9 1 29

6 9 1 29

6 9 1 29

7 9 1 29

7 9 1 28

8 9 1 28

8 9 1 28

9 9 1 27

9 9 1 27

10 9 1 27

10 9 1 27

11 9 1 26

12 9 1 25

13 9 1 25

14 9 1 24

15 9 1 23

16 9 1 23


MONOVALENT BRINES

2·52

Specific CrystallizationKBr by Density Gravity Temperaturewt % lb/gal (SG) ° F

17 9 1 22

18 10 1 21

19 10 1 20

20 10 1 20

22 10 1 18

24 10 1 16

26 10 1 15

28 10 1 13

30 11 1 11

32 11 1 9

34 11 1

36 11 1

38 11 1

40 11 1

CRC Handbook of Chemistry and Physics57th edition 1976–1977CRC Press


Potassium Bromide KBr

Molecular Weight = 119.01

Relative Specific Refractivity = 0.627

MONOVALENT BRINES

2·53

SodiumDensity Water Acetate Sodium Acetate TCTlb/gal bbl/bbl lb/bbl mg/L mg/L ° F

8.3 0.9976 1.75 1,401 3,598 32

8.4 0.9901 7.06 5,647 14,502 31

8.5 0.9739 17.92 14,330 36,785 29

8.6 0.9627 25.33 20,250 52,009 27

8.7 0.9517 32.90 26,300 67,556 24

8.8 0.9350 44.56 35,630 91,509 22

8.9 0.9234 52.54 42,010 107,883 19

9.0 0.9113 60.67 48,510 124,583 15

9.1 0.8987 68.95 55,130 141,592 12

9.2 0.8856 77.38 61,870 158,904 7

9.3 0.8720 85.96 68,730 176,513 3

9.4 0.8579 94.69 75,710 194,436 –1

9.5 0.8434 103.57 82,810 212,674 22

9.6 0.8286 112.62 90,050 231,263 28

9.7 0.8136 121.87 97,440 250,264 42

Sodium Acetate NaH3C2O2 (U.S.)

Mixing dry Sodium Acetate and water


Chapter 3EXAMPLE CALCULATIONS


3. EXAM

PLECALCULATIONS

EXAMPLE CALCULATIONS

Increase the Density of a Single-SaltSystem Using the Same Dry SaltIn order to increase the density of a single saltwith the same dry salt, you must have blendcharts that contain the pounds per barrel of saltand the water fraction. These equations applyfor any single salt as long as it is the same as thebase brine.

Do = Density of the original fluid in lb/galDf = Density of the final fluid in lb/gal

Wo = Water fraction of the original fluidWf = Water fraction of the final fluid

So = Salt of the original fluid in poundsSf = Salt of the final fluid in pounds

Vo = Volume of the original fluid in bblVf = Volume of the final fluid in bbl

Pounds of salt to add = ((Wo * Sf/Wf) – So) * Vo

Volume gained = (Wo/Wf * Vo) – Vo

Example using CaCl2 Table on page 1·5:

To weigh up 100 bbl of 9.0 lb/gal CaCl2 to 9.9 lb/gal CaCl2 with dry CaCl2

Pounds of salt to add = ((Wo * Sf/Wf) – So) * Vo

Pounds of salt to add = (0.9755 * 89.4/0.9346) –

37.2) * 100

Pounds of salt to add = 5,611 lb

Volume gained = (Wo/Wf * Vo) – Vo

Volume gained = (0.9755/0.9346 * 100) – 100

Volume gained = 4.4 bbl

3·1


Increase the Density of a Two-Salt System Using Dry BromideIn order to increase the density of a two-saltsystem with the dry bromide, you must haveblend charts that contain the pounds per barrelof salt and the water fraction. These equationsapply to both NaBr and CaBr2 additions. If usingNaBr, substitute NaBr in the following equa-tions for CaBr2.

Do = Density of the original fluid in lb/galDf = Density of the final fluid in lb/gal

Wo = Water fraction of the original fluidWf = Water fraction of the final fluid

Co = Chloride salt of the original fluidCf = Chloride salt of the final fluid

Bo = Bromide salt of the original fluidBf = Bromide salt of the final fluid

Vo = Volume of the original fluid in bblVf = Volume of the final fluid in bbl

Wa = Water to add to start the blend (bbl)Ba = Pounds of bromide salt to add

Vf = (Co/Cf) * Vo

Wa = Vo(Co * Wf/Cf) – Vo(Wo)

Ba = Vo(Co * Bf/Cf) – Vo(Bo)

3·2


Example:

To weigh up 100 bbl of 12.0 lb/gal CaBr2/CaCl2

to 12.5 lb/gal CaBr2/CaCl2 with dry CaBr2

Vf = Co/Cf * Vo

Vf = 194.1/183.7 * 100

Vf = 105.7

Wa = Vo(Co * Wf/Cf) – Vo(Wo)

Wa = 100(194.1 * 0.768/183.7) – 100(0.793)

Wa = 1.8 bbl

Ba = Vo(Co * Bf/Cf) – Vo(Bo)

Ba = 100(183.7 * 72.6/183.7) – 100(32.3)

Ba = 4,030 lb

3·3


How to Calculate Weight % SaltTo calculate the % by weight salt in a brinesystem, one must know the density and theamount of salt (lb/bbl) in the brine.

% by weight = Pounds of salt in the brinesystem/(density in lb/gal * 42)

For example:

To calculate the % by weight of an 8.5 lb/gal KCl.

% by weight = 11.6/(8.5 lb/gal * 42)

% by weight = 3.2% or ~3% KCl (by weight)

To convert % by weight or weight percent toparts per million (ppm) multiply by 10,000.

3% KCl (by weight or w/w) = 3 * 10,000 = 30,000 ppm

To convert parts per million (ppm) to milligramper liter (mg/L), divide ppm by specific gravityof the fluid.

To convert density into specific gravity, divideby density of water @ 70° F = 8.5/8.345

= 1.019

30,000 ppm = 30,000/1.019 = 29,452 mg/L

3·4

Chapter 4QHSE


4. QHSE

QHSE

4·1

Completion Fluids Safe Handling GuideThe HazardsLike all chemicals, oilfield completion fluids(brines) can be hazardous to your health if nothandled properly. Brines have unique chemicalproperties and consequently must be handleddifferently from conventional drilling muds.

Brines are salts dissolved in water. Brinesused in oil and gas well completions are for-mulated with sodium chloride (NaCl, tablesalt), potassium chloride (KCl), sodium bromide(NaBr), calcium chloride (CaCl2), calcium bro-mide (CaBr2), zinc bromide (ZnBr2), sodiumformate (NaHCO2), and potassium formate(KHCO2). Brines may also contain various vis-cosifiers, corrosion inhibitors and other addi-tives for special applications.

Water weighs 8.3 lb/gal (1 SG) while oilfieldbrines can weigh from 8.4 to 20 lb/gal (1.01 to2.4 SG), depending upon the amount and typeof salt added. Generally, as brines get heavierthey are more dangerous to handle and aremore damaging to equipment and theenvironment.

Hazardous Properties of Brines• Acidity (pH) — Zinc brines are acidic. • Absorption of water — Heavy brines contain

so much salt that they will absorb water fromtheir surroundings.

• Chemical reactions — Toxic chlorine orbromine gas can be released from brines.There are two circumstances where thiscould occur:1. When brines are exposed to the extremely

high temperatures of a fire, or

QHSE

2. When brines are exposed to strong oxidizingagents used to break viscosifiers.

• Toxicity — Brines can be toxic if large quanti-ties are swallowed. This is usually not a signifi-cant route of exposure at the rigsite.

Mixing Salts• Dry sodium/potassium/ammonium chloride

added to water reduces solution temperaturevery slightly

• Dry sodium/potassium bromide added towater raises solution temperature very slightly

• Dry calcium chloride/bromide added to waterraises solution temperature significantly – Temperature rise depends on rate of addition

• Addition of dry CaCl2 or CaBr2 can boil water

Effects of Exposure• Skin contact — The acidity and/or the ten-

dency of brines to absorb water from theirsurroundings means that they can be quiteirritating or even corrosive to the skin. The irri-tating effect of brines is usually delayed; youmay not feel anything for several minutes oreven hours after exposure.

• Eye contact — Brines are immediately andseverely irritating to the eyes. Permanent eyedamage may result from even short exposureto heavy brines. Wash eyes for at least 15 minafter exposure and get medical attention.

• Inhalation — Inhalation of brine mist or spraycan be irritating to the mucous membranes ofthe nose, mouth and throat.

• Ingestion — Swallowing brine may causenausea, vomiting and diarrhea in addition toirritation of the mucous membranes of thegastrointestinal tract. Swallowing large quan-tities may cause more serious toxic effects,

4·2

QHSE

depending on the density of the brine andthe additives that it contains.

DO NOT INDUCE VOMITING WHEN ZINC

BROMIDE BRINES ARE INJESTED.

Protecting Yourself

• Read and follow the instructions on the MSDS

Always have the Material Safety Data Sheets(MSDS) available on location for all chemicalsthat you handle. Read and follow all instruc-tions on the MSDS.

• Avoid exposure

Avoiding exposure to brines is always the bestway to protect yourself. However, this is notalways possible on the job. Whenever expo-sure is possible use the equipment, proceduresand precautions outlined below.

• Use the correct Personal Protective

Equipment (PPE)

The following special equipment is necessaryfor handling brines:

Eyes — Wear chemical splash gogglesdesigned to seal against the skin aroundboth eyes and give protection against splashesfrom any angle. A full face shield may be usedin addition to goggles to protect the face.

Body — Wear slicker suits in areas whereexposure is likely. Slicker suits are hot andinterfere with the body's natural cooling,therefore, a slower work pace or rotatingworkers may be necessary. Rubber or plasticaprons may be worn for some jobs, such ascarrying sacks. These are more comfortablethan slicker suits but do not give as muchprotection.

4·3

QHSE

Hands — Wear leak-proof gloves made ofnatural or synthetic-rubber material. Glovecuffs should be worn inside of slicker suitsleeves to prevent brine from running off ofsleeves into gloves. For some jobs it may benecessary to seal sleeves over glove cuffsusing tape to prevent brine from running intosleeves when hands are raised. Cloth glovesmay be worn over rubber gloves to provide abetter grip and protect the rubber gloves fromtearing. Do not use leather gloves.

Feet — Wear leak-proof rubber steel-toe boots.Do not use leather boots.

Respiratory — Use a NIOSH-approved P95half-mask disposable or reusable particulatemask for mist/aerosol. All respiratory protec-tion equipment should be used within a com-prehensive respiratory protection programthat meets the requirements of 29 CFR1910.134 (OSHA Respiratory ProtectionStandard) or local equivalent.

• Practice good skin care

Dermatitis, or skin irritation, is a commonproblem when handling brines. The following3-step program is designed to help you pre-vent dermatitis:

Protection — Before contact with brines applya barrier cream to areas that are not easilycovered by some other form of PPE. Use a bar-rier cream specifically designed to protectagainst water-based hazards. Barrier creamsshould be used in addition to the PPE men-tioned above, not as a substitute for it.

4·4

QHSE

Cleaning — Wash frequently; use hand soap,not harsh industrial cleaners.

Reconditioning — Contact with brines andfrequent washing of the skin can result inloss of the skin's natural oils and moisture.To prevent dry, chaffed, and irritated skin,apply a reconditioning skin lotion after workand as needed.

Over-the-counter hydrocortisone creammay be used to relieve minor skin irritation.Follow instructions and precautions providedby the manufacturer. If left untreated minor

skin irritation can progress rapidly, resultingin intense itching and blisters which canbecome infected. Cases of severe dermatitis,especially if infection is suspected, should bereferred to a doctor immediately.

• Safety equipment

Emergency eye washes and showers shouldbe installed and easily accessible in all areaswhere brines are used, especially on the rigfloor, shaker area and mud pits. Eye washesand showers should be plainly marked withsigns and workers should be trained in theirlocation and proper use.

• Rigsite precautions

Use pipe wipers when pulling pipe. Keep thepipe wiper below waist level so that brine willnot splash into workers’ faces.

Brines are slippery. Use non-slip surfaceson the rig floor, stairs and decks.

Rinse off tools periodically to provide abetter grip and prevent brine from beingtransferred to clothing.

4·5

QHSE

Make sure that brine storage containersand seals are strong enough to hold the brinewithout rupturing or leaking. Heavy-dutytanks should be used for brines weighing over13.5 lb/gal (1.62 SG).

Environmental IssuesThe Comprehensive Environmental Response,Compensation and Liability Act (CERCLA) andThe Federal Water Pollution Control Act (CleanWater Act) list zinc bromide as a hazardoussubstance with a Reportable Quantity (RQ) of1,000 lb (453.6 kg).

Brines may be toxic to aquatic plants andanimal life. Care should be taken to preventbrines from entering waterways. ContactM-I SWACO Environmental Affairs for moreinformation.

North SeaUnder the environmental regulations govern-ing offshore operations in the North Sea, allcompletion brines — with the exception of zincbromide — are considered acceptable for dis-charge. This includes sodium, potassium andcesium formate. Completion brines containingzinc bromide brines may still be used in excep-tional circumstances, with the prior approvalof the government environmental body respon-sible for the geographical region in which theoperation will take place.

4·6

Chapter 5TEMPERATURE AND PRESSURE


5.TEM

PERATUREAND

PRESSURE

TEMPERATURE AND PRESSURE

Temperature and Pressure Effectson Completion FluidCompletion fluids exhibit the typical volumetricresponse to temperature and pressure, i.e.,expanding with increasing temperature andcompressing with increasing pressure. In ashallow water or land-based wellbore, theexpansion of a completion fluid with temper-ature produces a more pronounced affecton volume than does pressure. This overallincrease in volume results in a fluid of lowerdensity at the bottom of the well than at thesurface. In deepwater environments however,the depth of cold water will impact the expan-sion/compression relationship such that thefluid at the mud line is heavier than that atthe surface. The combination of hydrostaticpressure and cold temperature can have cata-strophic effects unless the fluid is properly for-mulated to account for this environment.

Phase DiagramsTrue Crystallization Temperature (TCT) isthat temperature at which the brine solutionis fully saturated with respect to the least solu-ble salt. Figure 5.1 represents the TCT test resultsof an example CaCl2-CaBr2 completion brine.Included in the diagram is the first crystal toappear (FCTA) and the last crystal to dissolve(LCTD). Figure 5.2 presents the phase diagram(TCT v. Temperature) for various common com-pletion fluids. Crystallization of the fluid as aresult of hydrostatic pressure is referred to asPressurized Crystallization Temperature (PCT).Figure 5.3 shows the impact of pressure on the

5·1


TCT of a CaCl2-CaBr2 completion brine with aTCT of 40° F (4.4° C).

5·2

80

75

70

65

60

55

50

45

40

Temperature (° F)

Time

6:05:46 6:08:38 6:11:31 6:14:24 6:17:17 6:20:10 6:23:02 6:25:55

TCT = 57° F

FCTA

LCTD

g

Figure 5.1: Crystallization of a calcium

chloride/calcium bromide brine

70

60

50

40

30

20

10

0

-10

-20

-30

-40

-50

-60

Temperature (° F)

Density (lbm/gal)

CaBr2 TCTCaCl2 CT

NaCl TCTNaBr TCT

8 8.5 9 9.5 10 10.5 11 11.5 12 12.5 13 13.5 14 14.5 15 15.3

Figure 5.2: TCT diagram of various

completion brines


Hydrate SuppressionGas hydrates are a concern when working withaqueous fluids in deepwater. They can occurduring critical phases of deepwater completion(displacement, perforating, subsea BOP tests,well tests, flow back, etc.), leading to significantdowntime if not suppressed in the fluid design.Hydrate formation can be prevented by reduc-ing the gas-water thermodynamic equilibriumpoint. Dissolved salts, glycols and alcohols areexamples of substances that perform this func-tion. However, in most circumstances fluidproperties such as density will limit the optionsavailable. For example, below about 10.5 lb/gal(1.26 SG), calcium chloride is unable to preventhydrate formation at a pressure of 10,000 psi(689 bar) and 40° F (4.4° C). If a low-densitywater-based formulation is required, oxy-genated solvents such as ethylene glycol,propylene glycol, methanol, etc. have shown

5·3

60

55

50

45

40

35

30

25

TCT (° F)

Pressure (psi)

0 5,000 10,000 15,000

Figure 5.3: Effect of pressure on TCT of a 40° F

(4.4° C) TCT CaCl2-CaBr2 brine


5·4

themselves to be effective inhibitors. Figure 5.4gives an example of supplementing the hydrateinhibition of CaCl2 brine through addition ofethylene glycol.

Density PredictionThe ability to calculate the hydrostatic pressureat any point in a wellbore containing a columnof completion fluid is necessary for its optimumselection. Because hydrostatic pressure is cumu-lative with depth and is directly related to den-sity, which may be increasing with depth indeepwater or decreasing with depth as the tem-perature increases, it is necessary to mathemat-ically predict the density of the completion fluidunder the combined influence of compressionand temperature. The M-I SWACO proprietarycomputer program VIRTUAL COMPLETION FLUIDS*(VCF*) provides the means to accurately obtainthis necessary information.

12,00011,00010,000

9,0008,0007,0006,0005,0004,0003,0002,0001,000

0

Hydrate formation pressure (psi)

Density of CaCl2 (lb/gal)

9.3 9.4 9.5 9.6 9.7 9.8 9.9 10 10.1 10.2 10.3 10.4 10.5 10.6 10.7

CaCl2 requires hydrate inhibitor (MEG) to control hydrates to 10,000 psi

30%MEG

19%MEG

8.7%MEG

5.3%MEG

Figure 5.4: Hydrate protection of low-density

brine with monoethylene glycol; thermo-

dynamic hydrate protection of CaCl2 at 40° F

(4.4° C).


Bottomhole density is calculated with useof detailed PVT data for the behavior of the fluidin question. In the absence of such data, down-hole density and total hydrostatic pressure atdepth can be closely approximated by using thefollowing calculations and thermal expansionand compressibility factors provided in Tables 1and 2.

Total Hydrostatic Pressure in the Wellbore

Psih = 0.052 * Davg * TVD (1)

Where,

Average Brine Density in a Wellbore

(2000 – 0.052 * Cf * TVD) * Dsurf – 10 * Ve * (BHT – Ts)

Davg = (2)2000 – 0.104 * Cf * TVD

Ve = Temperature expansion factor,lbm/gal/100° F (Table 1)

Cf = Pressure compressibility factor,lbm/gal/1,000 psi (Table 2)

TVD = Total vertical depth (ft)

Dsurf = Density at surface, lbm/gal

BHT = Bottomhole temperature (° F)

Ts = Temperature at surface (° F)

5·5


5·6

Table 1. Expansibility of Brines at 12,000 psi

from 76° to 198° F

Brine Density Ve

Type (lbm/gal) (lbm/gal/100° F)

NaCl 9.42 0.24

CaCl2 11.45 0.27

NaBr 12.48 0.33

CaBr2 14.13 0.33

ZnBr2/CaBr2/CaCl2 16.01 0.36

ZnBr2/CaBr2 19.27 0.48

Table 2. Compressibility of Brines at

198° F from 2,000 to 12,000 psi

Brine Density Cf

Type (lbm/gal) (lbm/gal/1,000 psi)

NaCl 9.49 0.019

CaCl2 11.45 0.017

NaBr 12.48 0.021

CaBr2 14.30 0.022

ZnBr2/CaBr2/CaCl2 16.01 0.022

ZnBr2/CaBr2 19.27 0.031

Chapter 6TESTING PROCEDURES


6. TESTING

PROCEDURES

TESTING PROCEDURES

6·1

Marsh Funnel ViscosityScope and LimitationsThe Marsh funnel is used for routine field meas-urement of viscosity. It provides a quick andeasy procedure for monitoring viscosity of neatbrines, viscosified brines, spacers and reservoirdrill-in fluids. Changes in Marsh funnel vis-cosity can indicate that there may be polymerdegradation or contamination by solids orchemicals. Further testing or fluid-componentinformation is usually required to determinethe cause of the viscosity change.

References• API RP 13B-1, 3rd Edition, December 2003• M-I Drilling Fluids Engineering Manual, v.1.0,

M-I L.L.C. (July 1998)

Safety• Wear safety glasses• Gloves are required when handling corrosive

or hazardous fluids

Equipment and Chemicals Required• Marsh funnel• 1-qt receiving cup• Stopwatch • Thermometer

Calibration Procedure1. Obtain 1,500 mL freshwater and check

temperature.2. Adjust water temperature to 75 ±5° F

(24 ±2.5° C).3. Inspect Marsh funnel to make certain it is

not dirty or damaged.

TESTING PROCEDURES

4. Fill Marsh funnel to the bottom of the screenwith freshwater, covering orifice with fingerto prevent fluid from escaping.

5. Place filled Marsh funnel in upright positionover the 1-qt receiving cup.

6. Start stopwatch and remove finger fromfunnel orifice at the same time.

7. Stop stopwatch when fluid level in receivingcup reaches the 1-qt line.

8. One qt of water should take 26 ±0.5 sec.If your results vary from this time, repeatcalibration process. Take special care to cleanfunnel properly, and to remove finger fromfunnel orifice and start stopwatch at thesame time.

Procedure1. Obtain 1,500 mL sample and check

temperature. Record fluid temperature.2. Pour freshly collected sample into clean and

dry Marsh funnel until the fluid level reachesthe bottom of the screen, covering funnelorifice to prevent fluid from escaping.

3. Simultaneously remove finger from funnelorifice and start stopwatch.

4. Report result to the nearest second as Marshfunnel viscosity.

Fann 35 Viscosity: PV, YP, AV Gel StrengthsScope and LimitationsThe Fann 35 viscometer is used for measure-ment of viscosity, including PV, YP and 10-secand 10-min gel strengths. Additional usefulinformation can be obtained using the Fann 35for characterizing fluids, but these are the

6·2

TESTING PROCEDURES

primary values described in this procedure.These values can assist in evaluating carryingcapacity and quality of viscosified brine fluids,displacement spacers, fluid-loss pills and res-ervoir drill-in fluids. One can also detect pos-sible presence of polymer in clear brine fluidsthat can impact filterability and formationdamage potential.


M-I L.L.C. (July 1998)• VG Meter Calibration, Job Instructions Manual,

Western Hemisphere ISO Home Page, current version found at midhouhq-www01.corp.smith-intl.com

Safety• Wear safety glasses• Do not test fluids above 180° F (82° C), hollow

bob can explode when trapped moisturevaporizes. Use solid bob if higher temperaturetesting is necessary.

Equipment and Chemicals Required• Fann 35A or equivalent viscometer with

R1/B1/F1 configuration (standard rotor,bob and spring)

• Stopwatch • Thermometer• Calibration fluids

Calibration Calibration and repair of Fann 35 viscometersshould be performed by trained M-I SWACOpersonnel or outside vendors who are familiarwith the proper procedures.

6·3

TESTING PROCEDURES

Simple calibration checks can be performedby using special calibration fluids with viscosityversus temperature chart.

Calibration checks are quick and easy, andshould be performed regularly to ensure properequipment performance. 1. Select a viscosity standard near the viscosity

of fluids normally measured.2. Check that the zero RPM reading of the instru-

ment is 0 ± 0.5 dial readings.3. Measure temperature and viscosity at

600 RPM and 300 RPM.4. Compare Fann 35 reading at 300 RPM and

Fann 35 reading at 600 RPM divided by 2 tothe value shown for that temperature on thecalibration fluid chart.

5. These values should be ± 1.5 from thechart value.

Procedure for Apparent Viscosity,

Plastic Viscosity and Yield Point1. Mix sample to provide uniformity and

disrupt progressive gel structure.2. Pour sample into thermocup, place on

Fann 35 sample platform and raise untilfluid level is at the Fann 35 rotor-scribe line(above the two holes in the rotor).

3. Heat or cool sample to 120° F (49° C) whilerunning Fann 35 at 100 RPM. 100 RPM can beachieved by starting the motor in low speed(with switch down towards the back) and lift-ing red gear-shifter knob all the way up. Onlychange gears when the motor is running.

4. Once temperature has stabilized at 120° F(49° C), change speed to 600 RPM by depress-ing gear shifter knob all the way down withmotor still running, then switching the motor

6·4

TESTING PROCEDURES

to high speed by pushing the switch downand toward the front of the instrument.

5. Wait for a steady reading and record.6. Change speed to 300 RPM by switching the

motor back to low speed. Wait for a steadyvalue and record the 300 RPM value.

7. Plastic Viscosity (cP) = 600 reading – 300reading

8. Yield Point (lb/100 ft2) = 300 reading – PV9. Apparent Viscosity (cP) = 600 reading

2

Procedure for Gel Strength1. Maintaining the sample temperature at

120° F (49° C), stir sample at 600 RPM for10 sec.

2. Quickly adjust gear knob while motor is run-ning in preparation for taking 3 RPM reading.

3. Turn off viscometer and start stopwatch.4. After 10 sec have elapsed, turn the Fann 35

on to 3 RPM and watch dial reading increasethen fall off.

5. Record maximum value achieved as 10-secgel strength (lb/100 ft2).

6. Restir sample at 600 RPM for 10 sec.7. Quickly adjust gear knob while motor is run-

ning in preparation for taking 3 RPM reading.8. Turn off viscometer and start stopwatch.9. After 10 min have elapsed, turn the Fann 35

on to 3 RPM and watch dial reading increasethen fall off.

10. Record maximum value achieved as 10-mingel strength (lb/100 ft2).

6·5

TESTING PROCEDURES

TurbidityScope and LimitationsTurbidity is the measurement of light scatterusing an NTU meter. The value is reported inNephelometric Turbidity Units (NTU). This pro-cedure does not determine size or quantity ofinsoluble solids in brine.

References• API RP 13J, 3rd Edition, December 2003

Safety• Wear safety glasses

Equipment and Chemicals Required• Distilled or deionized water• NTU meter• Clean, dry sample cuvettes free from scratches

Procedure1. Turn on NTU meter.2. Insert standardizing cuvette into NTU meter

and calibrate, if necessary, by followingmanufacturer’s instructions.

3. Fill sample cuvette with brine to theappropriate level.

4. Clean outside of cuvette, then rinse withdistilled or deionized water.

5. Dry sample cuvette with lint-free cloth.6. Insert sample cuvette into NTU meter.7. Read NTU value after meter reading

has stabilized.

6·6

TESTING PROCEDURES

6·7

Total Suspended Solids Scope and LimitationsThis procedure quantifies insoluble solids inweight percent. Rinsing the filter with distilledor deionized water after filtration is importantwhen testing brines because soluble-solidscontent can contribute to erroneously highresults. Salt residue remaining on filter canalso contribute to long drying time becausethe salt is hygroscopic. A representative sampleis important, so unrepresentative trash, sticks,paper, etc. should be removed from samplebefore testing.


Safety• Wear safety glasses and chemically

resistant gloves

Equipment and Chemicals Required• Distilled or deionized water• Oven, set to 220° F ± 2° F (104° C ± 1° C)• Filters, 4.8 cm diameter, no organic binder• Membrane filter holder• 100 mL graduated cylinder• Balance, accurate to 5 places• Dessicator with appropriate dessicant• 20 mL wide tip pipette• Aluminum weighing pans

Procedure1. This test should be run in triplicate.2. Set up vacuum-filtration device and paper.

Place filter paper with rough side face-up.3. Filter 3 aliquots of 20 mL distilled or

deionized water.

TESTING PROCEDURES

4. Continue vacuum until all water is filtered.5. Remove filter, dry 1 hr at 220° F (104° C),

cool and store in dessicator until needed.6. Weigh prepared filter paper before filtering

brine sample.7. Wet paper with distilled or deionized water

to provide better seal.8. Obtain a representative brine sample, shake

brine sample for one minute to provideuniformity of insoluble solids.

9. Filter 100 mL brine. 10. Rinse graduated cylinder with distilled or

deoinized water to collect any remaininginsoluble solids, and pour this rinse waterthrough filter to remove any soluble mate-rial remaining on filter. Repeat this process3 times. Allow complete drainage of fluidbefore each rinse.

11. Apply vacuum until all liquid is removedfrom filter.

12. Remove filter paper from filtration deviceand dry 1 hr at 220° F (104° C) in preweighedaluminum pan.

13. Weigh filter after cooling in dessicator(~20 min).

14. Subtract final dried weight of filter andresidue from prepared filter paper weightplus aluminum pan weight.

15. Final weight must be at least 1 mg morethan initial weight or sample volume mustbe increased and the test rerun.

16. Calculate:TSS = Final weight (mg) – Initial weight (mg)

Sample volume (mL)

6·8

TESTING PROCEDURES

6·9

Solids by CentrifugeScope and LimitationsThis procedure quantifies solids byvolume percent.


Equipment and Chemicals Required• Bench centrifuge • 50 mL centrifuge tubes

Procedure1. Shake representative sample for 1 min to

provide uniformity of suspended solids.2. Fill two centrifuge tubes up to the 50 mL

mark with the sample fluid. Spin samples at1,500 to 2,500 RPM for 10 min.

3. After centrifuge has fully stopped spinning,open lid and remove tubes.

4. Solids, if present, should form a distinct layerat bottom.

5. Read this level on both tubes and add themtogether.

6. The volume percent of solids is equal to thetotal solids from Step 5 divided by 100.

TESTING PROCEDURES

Iron in Zinc and Non-zinc Brine:Colorimetric ProcedureScope and LimitationsFormation damage, cross-linking of polymers,and stabilization of brine/crude-oil emulsionsare some of the negative impacts of iron inbrine. Iron content can be measured with a testkit utilizing vacu-ampule and color compara-tors. The test procedure is applicable to all brinetypes including zinc bromide containing brines.This test measures total iron and does not dis-tinguish between species of iron. Iron concentra-tions up to 600 mg/L can be measured with goodreproducibility as determined by API RoundRobin testing. It is important to realize that themg/L reading must be divided by specific gravityto get a ppm value. This colorimetric procedurerequires subjective color observations to matchtest vial colors to standards. An alternate kit isavailable from CHEMets that utilizes a singleanalyte LED-based photometer.

References• CHEMets test procedure• API RP 13J, 3rd Edition, December 2003• Carpenter, J.F., et al. “A New Field Method for

Determining the Levels of Iron Contaminationin Oilfield Completion Brine,” SPE 86551, SPEFormation Damage Control Symposium,Lafayette, Feb 18–20, 2004

Safety• Read MSDS before conducting test• Wear safety glasses• Dispose of vacu-ampule as sharps/broken

glass waste

6·10

TESTING PROCEDURES

Equipment and Chemicals RequiredComplete Test Kit (CHEMets catalog numberK-6002) contains:• Refill, 30 CHEMets ampules (R-6002)• Acidifier solution, six 70 mL bottles (A-6001)• Activator solution, six 20 mL bottles (A-6002)• Sample cup, 50 mL, package of six (A-0027)• Syringe, 1 mL, package of six (A-0027)• Comparator, 0–100 mg/L (C-6002)• Comparator, 100–1,000 (C-6012)

Procedure1. Mix sample to ensure sample uniformity,

but do not include non-suspended solids.2. Use 1 mL syringe to add 0.5 mL of sample to

the 50 mL sample cup. Remove any bubblesfrom syringe by tapping syringe with tippointing upward.

3. Using a different 1 mL syringe, add 1 mL ofacidifier solution to sample cup.

4. Add 5 drops activator solution. (Use 10 dropsif the sample has 2% + organic content, i.e.EGMBE.)

5. Swirl cup and wait 2 min.6. Fill sample cup to 50 mL with iron-free water

(distilled or deionized preferred).7. Screw cap onto sample cup and shake to

mix contents.8. Remove cap, and place ampule in sample

cup. Snap tip by pressing ampule against theside of the cup. The ampule will fill, but willcontain a small bubble of air to aid in mixing.

9. Invert ampule several times, allowing bubbleto travel from one end of the ampule to theother each time, in order to mix contents.

6·11

TESTING PROCEDURES

10. Using the appropriate comparator, deter-mine iron content by matching color to thatof one of the standards. A bright-white lightor sunlight is preferable to fluorescent light-ing for an accurate reading. If the color isbetween two color standards, make a con-centration estimate.a. To use low range comparator, place the

ampule flat end downward, into the centeropening in the comparator. Rotate com-parator until the closest match isobserved.

b. To use high-range comparator, placeampule comparator in a nearly horizontalposition. Place ampule between colorstandards, moving it along the compara-tor until the closest match is observed.

11. Divide mg/L reading by specific gravity toobtain ppm iron in sample.

pH of BrineScope and LimitationsThe pH of neat brine is measured using acombination glass electrode containing adouble-junction reference electrode and thecorresponding meter. This type of electrode isrecommended in API RP 13J, and is less sensi-tive to high salinity and solids content thanmost other pH probes. Measurement of pH onneat (undiluted) brine is more reproduciblethan 1:9 Brine:Water dilutions, and is the APIrecommended procedure. Although ISFETprobes are perceived as being sturdier, the useof ISFET probes may result in lower pH readings.pH is generally defined as the negative log ofH+ activity; however, this definition does not

6·12

TESTING PROCEDURES

translate well to heavy brines. For practical pur-poses, pH is the value measured by a pH meterand is valuable as a relative value for trackingchanges and monitoring brine quality.

References• API RP 13J, 3rd Edition, December 2003• Prasek, B.B., et al. “A New Industry Standard for

Determining the pH in Oilfield CompletionBrines,” SPE 86502, SPE Formation DamageControl Symposium, Lafayette, Feb 18 –20, 2004


Equipment and Chemicals Required• pH meter with digital output, preferably

waterproof, shock-resistant and portable with0 to 14 pH range, temperature compensationoperable through temperature range 32° to150° F (0° to 66° C) and ± 0.1 pH unit resolu-tion, accuracy and repeatability

• Double-junction combination pH probe• Commercially available pH standards, prefer-

ably color-coded for easy identification• Thermometer with 32° to 220° F (0° to 104° C),

2° F (± 1° C) divisions, or better precision• Beaker or sample container• Distilled or deionized rinse water• Blotting tissue• Electrode storage beaker or container

6·13

TESTING PROCEDURES

pH meters and electrodes conforming to API RP13J requirements are readily available throughseveral laboratory equipment and scientificsupply outlets.

Calibration Procedure and

Care of Electrode

pH meter calibration should be checkedprior to first use and at least every 8 hrs ofcontinuous use.

1. Before calibration, rinse electrode with dis-tilled or deionized water, and inspect elec-trode for breakage and formation ofprecipitation or polymer coating. Clean orreplace electrode if it does not pass inspection.

2. Follow probe manufacturer’s calibration pro-cedure using the pH 7.0 standard buffer andeither the pH 4.0 or pH 10.0 standard,depending on anticipated sample pH. Buffertemperature should be at 75° ± 5° F (24° ±±2.5° C) before calibrating. (The pH value onthe container is valid for 75° F (24° C), anda table of buffer values versus temperatureis required if calibration is conducted at adifferent temperature).

3. After calibration recheck pH 7.0 buffer, and ifthe meter does not read 7.0 ± 0.1 recalibratepH meter and check again.

6·14

TESTING PROCEDURES

Test Procedure1. Mix sample to ensure sample uniformity.2. Place sample in beaker or other appropriate

clean container. 3. Immerse thermometer to level recommended

by manufacturer. Read and record sampletemperature.

4. Sample temperature should be 75° ± 5° F (24°± 2.5° C), and the same temperature as buffersused in calibration. If sample temperatureis more than 20° F (–7° C) from calibrationtemperature, temperature compensation isrequired. pH values are sensitive to temper-ature differences in highly acidic or highlybasic solutions.

5. Place electrode into sample and stir gently,allowing pH reading to stabilize. This usuallytakes less than 2 min. pH probe should not beleft in brine for over 5 min.

6. Read and record pH reading to the nearest± 0.1 pH unit.

7. Rinse pH probe using distilled or deionizedwater.

8. Return probe to storage container.

Important Considerations for pH Meter

Calibration and pH Measurement• Calibration should be checked more frequently

than every 8 hr if probe is getting older or iftesting samples with high polymer or claycontent, low pH (< 2), high pH (> 10), oilor zinc-containing brines

• Fresh pH buffers should be used every day• pH probes can often be brought back to good

performance by reconditioning including

6·15

TESTING PROCEDURES

soaking 10 min in 0.1 M HCl, 10 min in 0.1MNaOH, then recalibrating meter

• Do not allow probe to go dry. Store in pH 4buffer solution or as recommended by probemanufacturer.

• It is good practice to keep a backup electrodeon hand, and to replace electrodes at leastevery 6 months (or as recommended bymanufacturer)

• If pH measurement is erratic (especially if itstabilizes when stirring is discontinued), if pHstabilization is slow with non-zinc brine, or ifre-calibration is required on increasingly fre-quent basis imminent probe failure is likely.Attempt reconditioning probe, and obtain areplacement probe before failure occurs.

Crystallization Point DeterminationScope and LimitationsThe crystallization temperature of brine isthe temperature at which the brine willform solids, either salt crystals or ice (givenenough time and nucleating conditions). TrueCrystallization Temperature (TCT) is the valuereported. Precipitation of salt crystals can causeequipment plugging, viscosity increase and lossof density.



6·16

TESTING PROCEDURES

Equipment and Chemicals Required• Ice bath (with salt)• Digital thermometer with Thermistor probe• Concentric test tubes (two needed, one small

enough to fit inside the other)• DE (or other seed material)

Test Procedure1. Prepare an ice bath with the appropriate tem-

perature. Use the following guidelines whenpreparing the ice bath:

• When the TCT is expected to be 40° F (4° C)or higher, prepare a 32° F (0° C) bath bymixing an equal volume of ice and water

• When the TCT is expected to be 40° F (4° C)or lower, prepare a 5° F (–15° C) bath usingan equal volume of ice and water with thewater containing 25% by weight of sodiumchloride

• When the TCT is expected to be 20° F (–7° C)or lower, prepare a –40° F (–40° C) bath bymixing ice with an equal volume of pow-dered calcium chloride. Caution: This bath

can cause freezer burns.

2. Place the fluid into the smaller test tube andinsert the smaller test tube into the largertest tube.

3. Put a pinch of DE into the fluid and carefullystir with the thermometer. The test liquidlevel must be at the thermometer immersionlevel.

4. Immerse the test tubes into the ice bathand carefully stir with the thermometer.The cooling rate should be no greater than1° F (0.5° C) per minute.

6·17

TESTING PROCEDURES

6·18

5. The temperature will decrease to a certainpoint, then increase and begin to level off to aconstant temperature. Observe the fluid andthermometer during these changes.

• When crystals begin to form, the correspon-ding temperature is called the First Crystalto Appear (FCTA)

• From this point, the temperature willalmost immediately rise and begin tostabilize at a constant temperature. Thiscorresponding temperature is the TrueCrystallization Temperature (TCT). This isthe value reported as the crystallizationtemperature.

6. Begin warming the test tube at a rate of 1° F(0.5° C) per minute by reciprocating in andout of the ice bath. The temperature at whichthe last crystal dissolves is the Last Crystal toDissolve (LCTD).

7. API 13J requires that Crystallization Pointdetermination be performed in triplicate toensure accuracy. An FCTA and TCT within5° F (2.5° C) of each other is usually indicativeof accurate results.

Note: The inner test tube can be placed directlyinto the ice bath until the solution temperatureis within 5° F (2.5° C) of the expected TCT. Thenplace the sample test tube into the larger testtube. Wipe moisture off inner test tube first.

TESTING PROCEDURES

Calcium and Magnesium in Monovalent Brine and Formation WaterScope and LimitationsTotal hardness (calcium and magnesiumtogether) is determined by following proce-dure A. By following both procedure A andprocedure B, separate calcium content andmagnesium content values are obtained.


M-I L.L.C. (July 1998)

Safety• Read MSDS before conducting test• Wear safety glasses

6·19

Am

bie

nt

tem

per

atu

re

Time

FCTA = First crystal to appearTCT = True crystallization pointLCTD = Last crystal to dissolve

Cooling cycle Heating cycle

FCTA

TCT

LCTD

Figure 6.1

TESTING PROCEDURES

Equipment and Chemicals Required• EDTA (Standard Versenate) solution 0.01M• Strong buffer solution (ammonium hydroxide/

ammonium chloride)• Calmagite Indicator solution• Titration dish, 100 to 150 mL, preferably white• Three graduated pipettes:

• One 1 mL pipette• One 5 mL pipette• One 10 mL pipette

• 50 mL graduated cylinder• Distilled or deionized water• Glass stirring rod• 8N NaOH or KOH solution• Calcon Indicator or Calver II• Procelain spoon/spatula• Masking Agent: 1:1:2

triethanolamine:tetraethylenepentamine:water (by volume)

Procedure A (total hardness as Ca2+)1. Add approximately 20 mL of distilled water

to titration vessel.2. Add 1 mL of the water or filtrate to be tested.3. Add 1 mL of strong buffer solution.4. Add about 6 drops of Calmagite and mix with

stirring rod. A wine red color will develop ifcalcium and/or magnesium is present.

5. Using a pipette, titrate with StandardVersenate Solution, stirring continuously,until the sample first turns to blue with noundertint of red remaining.

6·20

TESTING PROCEDURES

6. Record the number of mL of StandardVersenate solution used as “A.”

7. Calculate total hardness as Ca2+ (mg/L) =

A x 400mL of sample

CaCO3 (mg/L) = A x 1,000

mL of sample

Procedure B (calcium and magnesium

separately)1. Add approximately 20 mL of distilled water to

the titration vessel.2. Add the same amount of water or filtrate to

be tested as used in procedure A.3. Add 1 mL masking agent.4. Add 1 mL of 8N NaOH or KOH and ∏ porcelain

spoonful (0.2 g) of Calcon Indicator and mixwith stirring rod.

5. Titrate with Standard Versenate solution untilthe indicator turns from wine red to bluewith no undertint of red remaining.

6. Record the number of mL of StandardVersenate required as “B.”

7. Calculate calcium (mg/L) = B x 400mL sample

8. Calculate magnesium (mg/L) = (A – B) x 243mL sample

6·21

TESTING PROCEDURES

Brine DensityScope and LimitationsThis procedure applies to measuring density ofa brine at surface and correcting the density to70° F (21° C).



Equipment and Chemicals Required• Hydrometer calibrated at 60° F (16° C)• Hydrometer Cylinder• Thermometer

Note: If you do not know the approximate den-sity of the fluid to be checked, start with a low-range hydrometer and work your way up to thecorrect range. This technique will prevent thebreaking of the heavier hydrometers as they fallthrough the lighter density fluids.

Procedure1. Pour a sample of the fluid to be weighed into

the hydrometer cylinder to within ± 1 in.(25.4 mm) from the top.

2. Gently place the hydrometer into the cylinderand spin it as you release it into the fluid.

3. Allow the hydrometer to stabilize and readthe specific gravity from the spindle. Takeyour reading from the bottom of the meniscus.

4. Record the temperature of the sample using aFahrenheit thermometer.

6·22

TESTING PROCEDURES

Calculation1. Convert the hydrometer reading (specific

gravity) to lb/gal by multiplying the specificgravity x 8.334. This factor relates to the den-sity of water at 60° F (16° C), the temperatureat which the hydrometer is calibrated.

2. Calculate the density correction to 70° F(21° C) using the following equation:

Dc = Dm+ [ CF(Tm – 70) ]

Where:

Dc = Corrected Density

Dm = Measured Density in lb/gal

CF = Hydrometer Correction Factor (see table on page 6·24)

Tm = Temperature of Sample

ExampleHydrometer reading of 1.742 SG at 100° F (38° C)

8.334 x 1.74 = 14.5 lb/gal at 100° F (38° C)

Dc = 14.5 + 0.00363 (100 – 70)

Dc = 14.5 + 0.00363 (30)

Dc = 14.5 + 0.1089

Dc = 14.6 lb/gal at 70° F (21° C)

6·23

TESTING PROCEDURES

6·24

Hydrometer Correction Factors1

Correction Factor Density (lb/gal per ° F) (lb/gal @ 70° F)

0.00284 8.5

0.00291 9.0

0.00297 9.5

0.00302 10.0

0.00307 10.5

0.00313 11.0

0.00318 11.5

0.00324 12.0

0.00330 12.5

0.00337 13.0

0.00344 13.5

0.00353 14.0

0.00363 14.5

0.00374 15.0

0.00386 15.5

0.00400 16.0

0.00416 16.5

0.00434 17.0

0.00454 17.5

0.00476 18.0

0.00501 18.5

0.00528 19.01API RP 13J, 3rd Edition, December 2003

TESTING PROCEDURES

6·25

It is important to read and use all of the num-bers on the scale of the hydrometer whenmaking density calculations. Omitting a num-ber can make a significant difference. The scaleis read as follows:

Each mark has a valueof .002. The first markbelow 1.800 is readas 1.802. The fifthmark is 1.810, theseventh mark is1.814, etc. To calcu-late the density,multiply the readingon the hydrometertimes 8.334.

1800

20

40

60

80

1900

Etc.

1.826

1.850

1.882

TESTING PROCEDURES

6·26

M-I SWACO Completion Fluids

Hydrometer Ranges

Hydrometer Specific Density Range Gravity (lb/gal)

1.000–1.200 1.0–1.2 8.33– 9.99

1.200–1.400 1.2–1.4 9.99–11.66

1.400–1.600 1.4–1.6 11.66–13.33

1.600–1.800 1.6–1.8 13.33–14.99

1.800–2.000 1.8–2.0 14.99–16.66

2.000–2.200 2.0–2.2 16.66–18.33

2.200–2.400 2.2–2.4 18.33–19.99

Note: These are approximate hydrometerranges. Depending on the manufacturer, thescale may overlap into the next higher range,i.e., 1.200 to 1.420 or 1.400 to 1.620. The scaleon the hydrometer may not have a decimalpoint, so a reading of 1200 indicates an SG of 1.2.

TESTING PROCEDURES

Submitting Samples to Technical Center LaboratoriesScope and LimitationsThis procedure applies to submitting samplesfor testing at the Technical Center in Houston,Texas.

References• Sample Submission Form, current version

found at midhouhq-www01.corp.smith-intl.com (R&E)

• CFR 49, Section 172, accessible at www.pgoaccess.gov\ecfr

• QHSE Manual, current version found at midhouhq-www01.corp.smith-intl.com (QHSE)

Safety• Include MSDS with sample. Label and package

according to DOT.

Procedure for submitting and

packaging a sampleFirst you must obtain a copy of the sample sub-mission from the Web site, or use a copy of theattached form. You can either send in a hardcopy or send it in electronically. This form helpsthe various departments follow the progress ofyour sample.

Then package your sample, include anMSDS, and send it to the following address:M-I SWACO, 5950 North Course Dr., Houston,Texas, 77072. Remember to send it to the atten-tion of the Completion Fluids Laboratory. Pleaseinclude a note with a brief description of thesample, where it’s from, what testing is required,and a contact name and phone number.

6·27

TESTING PROCEDURES

Package and label sample according to com-pany, shipper and DOT requirements. Section 14of the M-I SWACO MSDS includes the DOT clas-sification. The packaging of samples is for themost part common sense. Do not package oilsamples in plastic containers. Oil-base productswill dissolve plastic, this includes bottles andbags. Never label oil samples with grease pens.Package the sample with some thought and itwill arrive in one piece with the labels readable.

Environmental samples require specialhandling, depending on the test that is required.

6·28

TESTING PROCEDURES

Name of submitter:

M-I SWACO entity or Non-M-I SWACO company:

Location:

Phone number and E-mail:

Date submitted:

Report date requested:

Report to:

Lab master number:

Sample identification: (Provide as full andcomprehensive information as is available)

Objective description of problem:

What question(s) do you wish to haveanswered about the sample submitted?(Please be clear and objective)

6·29

TESTING PROCEDURES

Type of report required:

Data only: (Define data requested)

Data and discussion: (Define data requiredand specific issues/questions to address)

Justification for report deadline requested:

What will you do with the report? (Will it beprovided to end-use customer? Is it forinternal use?, etc.)

Special handling information:

Is sample toxic?� Yes � No

Please note that every field, with the

exceptions of the Lab Master Number and

contract acceptance must be completed

when received for the request to be accepted

in a timely manner.

Sample fate:1. Return (will be made to location address

above unless advised otherwise):2. Dispose of:3. Retain for additional testing:

6·30

RDF TESTING PROCEDURES



Methylene Blue CapacityDescriptionThe methylene blue capacity of drilling fluid isan indication of the amount of reactive clays(bentonite and/or drill solids) present as deter-mined by the Methylene Blue Test (MBT). Themethylene blue capacity provides an estimateof the total Cation Exchange Capacity (CEC)of the drilling-fluid solids. Methylene bluecapacity and cation exchange capacity are notnecessarily equivalent, the former normallybeing somewhat less than the actual cationexchange capacity.

Methylene blue solution is added to a sam-ple of drilling fluid (which has been treatedwith hydrogen peroxide and acidified) untilsaturation is noted by formation of a dye “halo”around a drop of solids suspension placed onfilter paper. Variations of the procedure usedon the drilling fluid can be performed on drillsolids and commercial bentonite to allow anestimate of the amount of each type of solidpresent in the fluid.

Drilling fluids frequently contain substancesin addition to reactive clays that adsorb methyl-ene blue. Pretreatment with hydrogen peroxide(see Procedure, Item b) is intended to removethe effect of organic materials such as lignosul-fonates, lignites, cellulosic polymers, polyacry-lates, and the like.

EquipmentThe following equipment is needed to performthe methylene blue test:

6·32


a. Methylene blue solution: 3.2 grams reagentgrade methylene blue (C16H18N3SCl)/L (1 cm3 = 0.01 milliequivalent) (CAS #61-73-4).

Note: The moisture content of reagent grademethylene blue must be determined each timethe solution is prepared. Dry a 1.000-gram por-tion of methylene blue to a constant weight at200° ±5° F (93° ±3° C). Make the appropriate cor-rection in the weight of methylene blue to betaken to prepare the solution as follows:

g =

b. Hydrogen peroxide: 3% solution (CAS #7722-88-5)

c. Dilute sulfuric acid: approximately 5 newtonsd. Syringe (TD): 2.5 cm3 or 3 cm3

e. Erlenmeyer flask: 250 cm3

f. Burette (TD): 10 cm3, micropipette: 0.5 cm3, orgraduated micropipette: 1 cm3

g. Graduated cylinder (TD): 50 cm3

h. Stirring rodi. Hot platej. Whatman No. 1 filter paper, or equivalent

ProcedureFollow this procedure to perform the MBT:a. Add 2 cm3 of drilling fluid (or suitable volume

of drilling fluid to require from 2 to 10 cm3 ofmethylene blue solution) to 10 cm3 of waterin the Erlenmeyer flask. To assure thatexactly 2 cm3 are being added, use thefollowing procedure:

3.2weight of dried sample

Weight of sample to be taken

6·33


1. The syringe should have a capacity of morethan 2 cm3 — generally 2 or 3 cm3. Byusing a larger syringe, it is not necessaryto remove the air trapped in the syringe.

2. The air or gas entrained in the drillingfluid must be removed. Stir the drillingfluid to break the gel and quickly draw thedrilling fluid into the syringe. Then, slowlydischarge the syringe back into the drillingfluid, keeping the tip submerged.

3. Again, draw the drilling fluid into thesyringe until the end of the plunger isat the last graduation on the syringe(for example, at the 3-cm3 line on a3-cm3 syringe).

4. Deliver 2 cm3 of drilling fluid by pushingthe plunger until the end of the plunger isexactly 2 cm3 from the last graduation onthe syringe. Thus, in a 3-cm3 syringe, itwould be at the 1-cm3 line.

b. Add 15 cm3 of 3% hydrogen peroxide and0.5 cm3 of sulfuric acid. Boil gently for10 min, but do not allow to boil to dryness.Dilute to about 50 cm3 with water.

c. Add methylene blue to the flask in incre-ments of 0.5 cm3. If the approximate amountof methylene blue solution necessary toreach the endpoint is known from previoustesting, larger increments (1 to 2 cm3) can beused at the beginning of the titration. Aftereach addition of methylene blue solution,swirl the contents of the flask for about 30sec. While the solids are still suspended,remove one drop of liquid with the stirringrod and place the drop on the filter paper.The initial endpoint of the titration is

6·34


reached when dye appears as a blue orturquoise ring surrounding the dyed solids.

d. When the blue tint spreading from the spotis detected, shake the flask an additional2 min and place another drop on the filterpaper. If the blue ring is again evident, thefinal endpoint has been reached. If the bluering does not appear, continue as before (seeItem C) until a drop taken after 2 min showsthe blue tint.

CalculationReport the Methylene Blue Capacity (MBT) ofthe drilling fluid, calculated as follows:

=

Alternately, the MBT can be reported aspounds per barrel bentonite equivalent (basedon bentonite with a cation exchange capacity of70 meq/100 grams) calculated as follows:

1.=

2.=

Note: The pounds per barrel bentonite equiva-lent (from Equations 1 or 2) is not equal to theamount of commercial bentonite in the drillingfluid. Reactive clays in the drill solids contributeto this quantity as well as commercial bentonite.

2.85 (bentonite equivalent, lb/bbl)

Bentonite equivalent, kg/m3g,

5 (methylene blue, cm3)Drilling fluid, cm3

Bentonite equivalent, lb/bbl

Methylene blue, cm3

Drilling fluid, cm3

Methylene bluecapacity, cm3/cm3

6·35


6·36

M-I SWACO Recommended Procedures for Measuring Low-Shear-Rate Viscosity (LSRV) for FLOPRO FluidsThe following standardized procedures are rec-ommended when measuring LSRV of a FLOPRO*fluid. These procedures are designed to negateartifacts produced from variances in test proce-dure. Every effort should be made to use theseprocedures in order to make valid comparisonsbetween wells.

EquipmentTesting will be made using the Brookfield^LVDV-II+ or LVDV-III digital viscometer withguard leg and cylindrical spindles (#1-4). TheLVDV-II+ is the most widely used viscometer.The LVDV-III model has a wider speed selectionand also has a programmable feature neitherof which is necessary for FLOPRO applications.The spindle viscosity ranges at .3 RPM usingthe LVDV-II+ or LVDV-III are: #1 to 20,000 cP,#2 to 100,000 cP, #3 to 400,000 cP and #4 to2,000,000 cP.

When ordering a Brookfield viscometer spec-ify LVDV-II+ or LVDV-III with cylindrical spin-dles. The LV prefix designates the proper springtorque for the viscosity ranges M-I SWACOdesires. A set of four appropriately sized cylin-drical spindles will be sent. Also input voltageand frequency should be indicated when order-ing. The units are available in 115, 220 or 230volts AC and 50 or 60 Hertz frequency.

Other necessary equipment includes thelarge OFI thermo cup (3∏-in. [82.6-mm] dia by^Mark of Brookfield Engineering Laboratories, Inc.


4-in. [101.6-mm] deep) and a mixing device tohelp heat the fluid sample evenly.

LocationLocate the Brookfield where a stable power sup-ply is available. It should also be located wherevibrations from the rig are minimal. Rig vibra-tions may contribute to inaccurately low LSRVmeasurements. Dust may damage the electron-ics or the bearings so a dust-free atmosphereshould be located.

SetupRemove the viscometer from the case. Installgear assembly on stand with rack and insertBrookfield viscometer post in assembly andtighten clamp screw. Level viscometer by rotat-ing it slightly on the stand and/or by adjustingfeet. Use the bubble level on the top as a guide.

Plug temperature probe into receptacle onthe back of the viscometer. Make sure powerswitch on the rear of the viscometer is OFF. Plugpower cord into receptacle on the back of theviscometer and plug into appropriate AC socket.The AC input voltage and frequency must be

within the appropriate range as shown on the

name plate of the viscometer.

Note: The DV-II+ must be earth grounded to

ensure against electronic failure!

This is a delicate electronic instrument. Careshould be taken to avoid power surges and fre-quency variations. Disconnect the viscometerwhen not in use.

Pour the FLOPRO fluid to be tested to within ahalf inch of the top of the Thermo cup and heatto desired temperature. The fluid sample shouldbe tested at the same temperature as the other

6·37


rheological properties. The sample should bestirred while heating to equalize the tempera-ture throughout the sample. A Hamilton Beachtype mixer may be used. Stir at a slow rate toavoid overshearing the fluid which may resultin polymer degradation. Avoid entrapping airwhile stirring. Entrapped air will result in erro-neous readings.

InitializingWhile heating the sample, remove the rubberband holding the viscometer shaft in place. Theviscometer uses a gem bearing and calibratedspring. Avoid impact and twisting of the shaft.Always replace the rubber band when not usingthe viscometer.

Turn on the viscometer. The digital screenwill display the operations as the viscometerautozeroes itself. The following screen descrip-tions are for the LVDV-II+ viscometer, the mostwidely used model.

When the power is on the screen will flash“Brookfield DV-II+ LV Viscometer,” then “Version3.0.” The screen then automatically changes to“Remove spindle. Press any key.” Press any ofthe yellow keys and the display changes to“Autozeroing Viscometer.” After autozeroing thescreen will display “Replace spindle. Press anykey.” Select the appropriate cylindrical spindlefor the desired viscosity. Most applications willuse the number 2 spindle. Note the spindles aremarked on the neck.

Attach the spindle by threading it onto theshaft. Note these are left-handed threads. Holdthe shaft in one hand to prevent damage to thespring and bearing while tightening the spin-dle. After tightening the spindle, press one of

6·38


the yellow buttons on the key pad. The defaultdisplay will appear on the screen.

Viscometer DisplayThe screen will look something like this:

Values may vary according to what was lastused.

The upper left corner displays viscometerreadings these may be in the following units:

% Viscometer Torque (%)cP Viscosity (cP or mPa)SS Shear Stress (always 0 due to spindle

configuration)SR Shear Rate (always 0 due to spindle con-

figuration)The default units for the LVDV-II+ is %. The

value in the upper left corner should be <+1.0 %when not in use. A value greater may indicatedamage to the bearing or spring.

M-I SWACO is using viscosity in cP (centipoise)as the standard reading. To select the appropri-ate units, press Select Display key until the cPvalue appears. The SI unit mPa·s is equivalent tocP (40,000 cP = 40,000 mPa·s).

The upper right hand value is the spindlecode. The code allows the viscometer to cor-rectly calculate viscosity for a given spindlegeometry. The code for the #2 spindle is S62

and for the #3 spindle it is S63. If the correctcode is not on the screen, press Select Spindle

key. The S will blink. Use the orange up anddown arrow keys to search for the correct spin-dle code. When the correct code is found, press

% 0.0 S62

0.0 RPM 70.5° F

6·39


the Select Spindle key and this code willbecome the default code.

This viscometer can test viscosity at .3, .5, .6,1.0, 1.5, 2, 2.5, 3, 6, 10, 12, 20, 30, 50, 60 and 100RPM. To set the speed, press the orange arrowkeys until the desired speed appears to the rightof RPM. M-I SWACO is doing all testing at .3 RPM.When the proper value appears press the setspeed key. Note: The viscometer is now run-

ning, press the Motor ON/OFF key to stop

the viscometer, but hold the desired speed

in memory.

The value in the lower right is temperatureas noted by the temperature probe.

The viscometer is now ready for runninga test.

Note: In order to have SI units displayed,

hold the Auto Range key while turning on the

viscometer. To get temperature in ° C hold the

Select Display key while turning on the power.

TestingAfter setting up the viscometer and heating thesample to test temperature a test can be per-formed. Centralize the Thermo cup beneath theviscometer. Boundary effects caused by eccen-tric placement may alter LSRV readings. Make

sure the guard leg is in place to avoid damage

to the spindle, bearings and spring. Lower theviscometer until the recess in the spindle shaftis at the top of the fluid. While lowering the vis-cometer hold up under the front to preventexcessive vibration.

Set a timer for three minutes and turn onthe viscometer motor with the Motor ON/OFF

button. Take viscosity readings at 1 min, 2 minand 3 min while the viscometer is running.

6·40


These values should be labeled LSRV1, LSRV2and LSRV3, respectively. Part of the first minutewill involve torquing the spring. Generally thefluid will reach its maximum viscosity withinthe 3-min time. The 3-min reading may actuallybe less than the 2-min reading. If the 3-minreading is less than the 2-min reading thespindle is probably slipping as it “drills a hole”in the fluid.

After the test, turn off the viscometer andraise the spindle above the fluid.

CleanupTurn off the viscometer. Remove the spindle,then the guard leg. Wash them thoroughly.Replace the guard leg and reinstall the rubberband on the shaft. Keep the viscometer awayfrom water and dust and unplug it when not inuse to avoid power surges.

CalibrationCalibration fluids are available from Brookfieldand their agents. The viscometer should be cali-brated regularly. The procedures are outlined inthe “Brookfield Digital Viscometer OperatingInstructions Manual,” which is included withthe viscometer. This manual also contains moredetailed information not discussed here.

SummaryThe M-I SWACO standard LSRV test for FLOPRO

fluids is outlined in the following steps.1. Use Brookfield LVDV-II+ viscometer at .3 RPM.2. Use spindle 2 for LSRV <100,000 cP, spindle 3

for LSRV >100,000 cP.3. Test sample at same temperature as other

flow properties.

6·41


6·42

4. Use OFI 3∏-in. (82.6-mm) diameter thermocup.

5. Run test with guard leg in place.6. Take LSRV readings at 1-min intervals over

3 min. Run viscometer throughout 3-mintime period.

DIAL READING * FACTOR = Brookfield viscosityin cP (mPa).


Field Test Procedure for Drill Solids Determination Required equipment and material• Top loading balance• Hot plate with magnetic stirrer• API filter press and accessories• 250-mL beaker

Required chemicals• 15% Hydrochloric Acid (HCl) — use with

caution• Defoamer1. Weigh equivalent of 35 mL of mud into

250-mL beaker.2. Add several drops of defoamer.3. Add stirring bar to beaker and place on stirrer

at slow speed.4. Slowly add 50 mL of 15% HCl, don’t let sample

foam over. This might take a few minutes.5. After all HCl has been added, place on hot

plate and bring to boil (this will break downthe polymer so the sample will filter). (Forfluids using NaCl as the bridging material,add 50 mL of water to dissolve the bridgingmaterial.)

6. Weigh API Whatman 50 filter paper.7. Cool sample and add to API filter cell.

Filter sample.8. Take out filter paper with solids and put

in oven until dry.9. Weigh and record weight of filter paper

with solids.

6·43


10. Subtract original weight of filter paper (step#6) from final weight of filter paper withsolids (step #9). This is reported as drillsolids.

CalculationsFor 35 mL of mud (1/10 bbl equivalent):• Weight of solid residue x 10 = lb/bbl of

drill solids (Note: 9.1 lb/bbl of drill solids =1% by volume of drill solids)

6·44

Chapter 7DISPLACEMENT TECHNOLOGY


7.D

ISPLACEMENTTECHNOLOGY

DISPLACEMENT TECHNOLOGY

Drilling Mud to Brine DisplacementsFor a mud-to-brine displacement to be suc-cessful, certain basic criteria must be met.The casing in the hole should be cleaned ofmud. The completion fluid in the hole shouldcleanup quickly with common filtration prac-tices. The emulsified, dirty (requiring disposal)or trash fluid coming out of the hole shouldbe minimized.

A guide for the cleanliness of the casing is todetermine the degree of mud removal from thedrill pipe when it is pulled from the hole follow-ing the displacement. Completion fluid claritycan be judged by a Nephelometric TurbidityUnit (NTU), a relative light-scattering method,or Total Suspended Solids (TSS), which is quan-titative. How quickly the desired NTU or TSSlevels are achieved, if at all, after displacementis one measure of displacement success. Thevolume of fluid lost to emulsified interface orsolids contamination can be gauged to measurerelative success based on pre-job determinations.

The indicators of criteria for success are vari-able, depending upon the goals of the comple-tion and the conditions of the wellbore. In oneset of conditions, a displacement may succeedif the NTU after one circulation is <100; underanother set of conditions, a NTU >40 is an indi-cator that the displacement did not attain itsgoal. In one case, 80 bbl of contaminated brinemay reflect good practice; in another, 40 bblmay be unacceptable.

7·1


Displacement TechniquesDisplacements are designated according to thedirection in which they are pumped and thefluid which follows the chemical spacers intothe hole.

In the Forward technique, displacing fluidsare pumped down the workstring and up thecasing annulus and pump pressure is appliedto the workstring. In the Reverse technique, dis-placing fluids are pumped down the casingannulus and up the workstring and pumppressure is applied to the annulus.

In the Direct method, drilling mud is dis-placed by cleaning spacers followed by comple-tion fluid. In the Indirect method, drilling mudis displaced by cleaning spacers or availablewater (seawater or drill water) followed by ahole-volume of available water. Only later isthe available water displaced out of the hole bycompletion fluid. The Balanced method is onetype of direct displacement. In it, the spacersare weighted to balance the density of the mudso that differential pressures (between hydro-static and formation or liner top test) are mini-mized during pumping of the displacement.The Staged method is a seldom-used butimportant technique in which the wellboreis displaced in stages, the upper portion first,usually indirectly, followed by the remaininglower portions.

Spacer TypeDisplacements of mud to brine are performedusing chemical spacers that are intended toremove all remnants of the mud from casingand tubulars. Muds are typically categorizedas Oil-Base (OBM), Synthetic-Base (SBM) and

7·2


Water-Base (WBM). Spacers used to breakdownand remove these three mud systems differ intheir chemical composition.

Water is the best solvent for WBM. A high-pH solution of caustic soda in drill water orseawater is very effective at destroying theintegrity of WBM. A surfactant (SAFE-SURF* W

or WN) in drill water or seawater can be used tofurther clean the pipe and water-wet the pipesurface. A viscous pill is often used to sweepmud solids and debris out of the hole. Somecombination of similarly designed spacers willsuffice to clean the hole of water-base mud,always in conjunction with best displacementpractices.

OBM and SBM are more complex systemsand more difficult to remove from pipe sur-faces. Oil is the best solvent for removing eitherof these systems, but at some point a chemicaltransition must be made to water-wet the pipesurface. M-I SWACO recommends initiating thisaqueous transition immediately following thebase oil pre-flush. This spacer, called the tran-sition spacer, must be based on chemistry thatis compatible with the mud, the base oil andthe cleaning or wash spacer that follows.Compatibility tests performed prior to the dis-placement determine the composition of thistransition spacer and confirm that massive orcomplex emulsions will not form at the inter-faces of the displaced and displacing fluids.

Cleaning or wash spacers follow the transi-tion spacers in sequence. They are also moredifficult to determine for OBM and SBM thanfor WBM. Surfactants (SAFE-SURF O, E or NS)and solvents (SAFE-SOLV* OM, E or 148) are less

7·3


effective at cooler temperatures, such as mightbe seen at a deepwater mudline or even in a shal-low well. Higher concentrations of surfactantand solvent are required for removing higherweight OBM and SBM than for removing lowerweight muds. Also combinations of surfactantand solvent will exhibit differing effects whencleaning OBM or SBM. Synthetic muds are gener-ally more tenacious about gripping the pipe sur-face. Laboratory tests should be run to determinethe effectiveness of these spacers prior to per-forming a displacement of OBM or SBM.

M-I SWACO OBM and SBM displacement rec-ommendations typically consist of a weighted,viscous transition spacer, one or two cleaningspacers (of solvent/surfactant combined orindividually) and a viscous separation spacer.Regardless of mud type, following the separa-tion spacer one drum of flocculant (FILTER FLOC*)in 100 bbl seawater or brine is often used tohelp carry solids to the surface. If the flocculantis added to brine in a direct displacement, thebrine can be directed to the return pit with therest of the active brine system.

Spacer SizeThe lead or transition spacer in an OBM or SBMdisplacement should be sized to eliminate theintermixing of the fluids ahead of and behind it.(This is less of a critical issue in WBM displace-ments, but the same design techniques apply.)Conventional practice defines this interval as500 to 1,500 ft (150 to 450 m) of coverage inthe largest annular area, depending upon theunique experience of the design engineer.However, if two wells are compared, both with95⁄8-in. (244-mm) casing and 4-in. (102-mm) drill

7·4


pipe, one 8,000 ft (2,440 m) deep and the other20,000 ft (6,100 m) deep, conventional practicesuggests these two wellbores require identicallysized transition spacers. M-I SWACO recom-mends the transition spacer be sized based onthe well capacity, typically 10% of the totalannular volume. This accounts for annular sizeas well as well depth. In this case, the 8,000-ft(2,438.4-m) well will have a 25 to 50 bbl (4 to8 m3) transition spacer while the 20,000-ft(6,096-m) well will have a 75 to 100 bbl (12 to16 m3) transition spacer. For logistical conven-ience, the spacer size is rounded up or down tofit portable storage tanks, if necessary.

The size of the cleaning spacer should bedetermined by the total surface area to becleaned, contact time and flow rate required forcleaning and concentration of wash chemical.It has been estimated that the average mud filmon the casing and tubing wall is between 1⁄64-and 1⁄32-in. (0.4- and 0.8-mm) thick. The volumeof this mud film can be calculated based on thesize and length of the drill pipe and casing.Since cleaning spacers will become contami-nated with mud over the course of the displace-ment, a well-designed cleaning spacer will havea concentration great enough to provide effec-tive chemical activity in the latter stages ofthe displacement. A basic design begins withenough spacer volume and wash chemical con-centration to account for mud contaminationup to 25%.

Based on this criteria, M-I SWACO recom-mends cleaning spacers sized at a minimumof 4 times the estimated volume of mud filmon the total area of tubing and casing, or,

7·5


enough concentration to effectively clean whencontaminated with mud at 25% volume. If thatvolume/concentration is sufficient to achievethe necessary contact time for effective clean-ing at the displacement pump rate, no size/con-centration adjustment is required. However, ifpre-job spacer testing indicates more contacttime or concentration is needed, spacer size/concentration should be adjusted accordingly.

Factors that may cause a further increase ofcleaning spacer size are: dead space in blendingpits and lines, inability to rotate and/or recipro-cate, inability to get the cleaning spacer in tur-bulent flow in part of the wellbore or poor mudconditioning (especially stagnant mud in high-temperature conditions).

Pump Rate and Flow RegimePump rate for a mud-to-brine displacementshould be maintained between two limits.The minimum limit is that rate required toachieve turbulent flow in the cleaning spacer.The maximum limit is that pump rate whichlowers the contact time of the cleaning spacerbelow the acceptable level as determined byprior lab testing.

It is generally recognized that the cleaningspacer will be most effective when it is in tur-bulent flow. Turbulence is usually attributedto a surfactant-based Newtonian fluid with aReynolds’ Number (NRe) >4,000 (2,200 <4,000being transitional flow). Experience in displace-ment implementation suggests using a higherlower-limit in design criteria, often on the orderof NRe ~ 6,000 to 8,000 if possible. Factorswhich determine the NRe of a fluid are its den-sity, Apparent Viscosity (AV), velocity and area

7·6


of flow. NRe is inversely proportional to thefluid viscosity. Since cleaning spacers are non-viscous, a high NRe can usually be achievedwith relative ease.

Spacer ChemicalsSpacers are designed using surfactants, sol-vents, viscosifiers and flocculants. M-I SWACOhas developed a line of displacement spacerproducts that are designed to promote wellborecleaning while minimizing rig time and mate-rial waste. This product line is called the SAFE*Series.

Surfactants — SAFE-SURF W, WN and

NS are surfactant blends intended for use inremoving water-base mud residues. All aredesigned for use in freshwater or seawaterand contain strong water-wetting surfactants.The pH of these blends varies from very high(W) to near neutral (WN).

SAFE-SURF O, E and NS are formulated forremoval of OBM and SBM. These surfactantscan be blended in freshwater or seawater andare effective when blended in salt brine. pHranges from very low (O) to moderately high (E).The products are formulated to satisfy differingregulatory requirements in various parts of theworld. Surfactants are used at 3 to 20% byvolume in spacer solutions.

Solvents — SAFE-SOLV E, OM and 148 aresolvent/surfactant blends intended for use inOBM and SBM displacements. They contain noaromatic hydrocarbons or toxic alkyl phenols.These solvents are used in displacement spacersat percentages between 3 and 35% and arepumped neat when used to pickle pipe forpipe-dope removal. SAFE-T-PICKLE* is a special

7·7


7·8

solvent developed for removal of pipe dope.SAFE-T-PICKLE is run as a neat solvent.

Viscosifiers — M-I SWACO prefers the use ofshear-thinning polymers when possible in muddisplacements. DUO-VIS*, DUO-VIS L, FLO-VIS*Land FLO-VIS PLUS are xanthan polymer systemsthat are used to build viscous spacers. DUO-VIS

is unclarified xanthan, FLO-VIS L is liquid clari-fied xanthan and FLO-VIS PLUS is coated, clari-fied powder. The proper product is selectedbased on well conditions and completion goals.

SAFE-VIS*, SAFE-VIS OGS, SAFE-VIS LE,

SAFE-VIS E and SAFE-VIS HDE are HEC polymersystems also used to viscosify displacementspacers. SAFE-VIS is dry powder, OGS is pre-slurried in a synthetic carrier that passes oiland grease and static sheen tests required inthe Gulf of Mexico and HDE is pre-slurried ina synthetic carrier to enable viscosification ofhigh-density brine. SAFE-VIS is typically recom-mended at 3.5 lb/bbl (10 kg/m3). SAFE-VIS OGS,

LE and E are used between 0.75 to 1.5 gal/bbl(19 to 38 kg/m3). SAFE-VIS HDE is recommendedbetween 3 and 5 gal/bbl (63 and 105 kg/m3).

Flocculants — SAFE-FLOC* I and FILTER FLOC

are used to flocculate dispersed solids and tohelp bring solids to the surface. SAFE-FLOC I isoften used in brine reclamations or added onlocation when dissolved iron creates a clarityproblem in the completion brine. It can be addedat 0.25 to 1% by volume to the working brinesystem to help coagulate and then flocculatecolloidal iron. FILTER FLOC is most often includedin the first 100 bbl (16 m3) of seawater or brinethat follows the displacement spacer sequence


into the hole. This helps bring suspended solidsto the surface where they can be filtered out ofthe working system.

Mechanical AidsMechanical aids consist of those elementswhich are neither chemical nor hydraulic,such as mud conditioning, pipe rotation andreciprocation and cleaning tools.

Mud conditioning may be the most under-stated stage of the displacement process. Mudproperties, i.e., PV and YP, should be reduced tominimum values prior to displacement. In mostdisplacement applications, a few additionalhours spent properly conditioning the mudcan save an extra day of hole cleaning.

Guidelines are available for rate of rotationduring circulation and displacement. Pipe rota-tion is critical for hole cleaning in hole angles>30°. Reciprocation also helps disturb mudadhering to the pipe wall. It is generally recom-mended that pipe reciprocation be performedduring mud circulation and during the displace-ment only after the spacers have entered thecasing annulus. To keep fluid flowing on-bottomduring displacement, reciprocation should belimited to one joint of pipe, rather than onestand, during that time.

Casing cleaning tools are an integral com-ponent of mud displacement. The M-I SWACOSPEEDWELL division provides casing brushes andscrapers, jetting tools, magnets and boot bas-kets that are put in-string during the casingclean-out. Refer to the SPEEDWELL tools sectionin this manual.

7·9

Chapter 8VISCOSIFIERS AND FLUID-LOSS CONTROL


8. VISCOSIFIERS

ANDFLUID-LOSSCONTROL

VISCOSIFIERS AND FLUID-LOSS CONTROL

Loss of completion fluids to permeable forma-tions will usually impair the production ofhydrocarbons. Increasing water saturation, scal-ing and emulsion formation are examples offormation damage that can occur. Furthermore,if the rate of losses during the completionprocess is too great, continuing with operationssuch as tripping in and out of the hole may notbe possible. As a result, controlling fluid losses isan important consideration when designingand carrying out the completion. Whereas bothmechanical and chemical means of controllinglosses are available, in many cases, mechanicalmeans are either impractical or simply not suit-able. Therefore, fluid losses are very often con-trolled by chemical means, i.e., spotting ‘pills’of one sort or another. An important featureof these pills is that they control losses withthe least possible damage to the productivityof the well.

Reducing the density of the completion fluidto lessen the differential pressure between thewellbore and the formation is an effectivemeans of reducing the rate of losses. However,adjusting the brine density requires an accurateknowledge of both the Bottomhole Pressure(BHP) and the hydrostatic pressure exerted bythe brine. The density of the completion fluidis selected to provide a certain overbalancepressure in the wellbore, often 200 to 300 psi(13.8 to 20.7 bar). In deep, hot wellbores, littlemargin of error is available. Consequently, den-sity reduction is often not allowed unless reli-able data is provided that can assure that adensity-cut is an acceptable option.

8·1


Pills commonly used to control downholelosses include, solids-free viscous pills, cross-linked polymer pills and those containing solu-ble, sized bridging particles such as calciumcarbonate or sodium chloride. Unlike the cross-linked and filter-cake building systems, solids-free viscous pills do not stop losses, but rather,reduce the rate of loss. The effectiveness of a vis-cous pill depends on the length and permeabil-ity of the thief zone, the differential pressure,the viscosity of the pill under downhole condi-tions and just as important, the quality of itspreparation. To be truly solids-free and to be asnon-damaging as possible, viscous pills shouldbe sheared and filtered (minimum 10 micronabsolute) to eliminate “fish eyes” that will act asplugging solids and make breakers and clean-up techniques much less effective.

Typically, these viscous pills are preparedwith a polymer that is soluble in the completionfluid, provides viscoelastic behavior, maintainsviscosity under downhole conditions and canbe “broken” with available breakers such asacids, enzymes and oxidizers. The most com-mon examples include Hydroxyethylcellulose(HEC), and Xanthan Gum (XC). In all cases, thehigh-purity, clarified versions of these polymersshould be used. Lower grade versions of HECand XC, or non-clarified systems such as manyof the guar gums and carboxy-celluloses, aregenerally not recommended. M-I SWACO offershigh-purity polymer systems within theSAFE-VIS (HEC) and FLO-VIS (XC) product lines.Synthetic polymers that are neither acid solubleor acid compatible are not recommended unlessextreme conditions warrant such use.

8·2


Cross-linked pills offered by M-I SWACO(SAFE-LINK*) are based on a derivatized HEC inwhich anionic functional groups are graftedonto the polymer backbone and cross-linkedwith Magnesium Oxide. The cross-linkingcauses the polymer to form a 3-dimensionalnetwork which produces a gel structure withthe consistency a thick gelatin. Similar cross-linked systems are available in the industry,some of which are mixed on the rig, requiringspecial blending units and a trained technicianto properly prepare. The SAFE-LINK systems arepre cross-linked in base brine and supplied tothe rig in 5-gal (18.9 L) buckets. No specialblenders or training is required to mix thesepills. The SAFE-LINK gel is simply added to a vis-cous HEC pill or to the base brine, stirred (notsheared) and pumped. SAFE-LINK pills are sup-plied with densities from 11 to 16 lb/gal (1.32to 1.92 SG).

When the solids-free, linear gel or cross-linked pills are ineffective, pills that form anexternal filter cake are required. Only solublebridging agents such as calcium carbonate orsodium chloride should be used in these appli-cations. The particle size distribution of thesolids in these pills is selected to bridge eitheron the surface of the formation (OPTIBRIDGE*pills) or on the inside surface of the productionscreen (SEAL-N-PEEL* pills). These systemsrequire knowledge of the screen type and/orformation pore size. In addition to the basebrine and the sized particles, such solids-containing pills use shear thinning polymerswith good low-shear-rate viscosity to carry andsuspend the solids and a soluble binding agent

8·3


to form a low-permeable matrix in combina-tion with the solids. Xanthan gum and starchare the most common examples of these addi-tives. Because these pills form a filter cake ofextremely low permeability, and in some cases,form an impermeable “plug” in a perforationtunnel, they can be more difficult to clean upthan their solids-free counterparts and usuallyrequire a post-placement cleanup treatment.On the other hand, SEAL-N-PEEL pills seal onthe production screen surface with very littlematrix invasion and contain surface tensionreducing agents that allow the filter cake to“peel” from the surface with minimal draw-down pressure.

HECHydroxyethylcellulose (HEC) is a nonionic, ethylether derivative of cellulose. It is the most com-mon polymer used to viscosify clear brine com-pletion fluids. It is the only polymer soluble inall standard, non-formate completion fluids,regardless of density. Dry HEC polymer must beadded slowly when used to viscosity brine; oth-erwise the brine immediately wets the surfaceof the polymer before it has a chance to disperse.This leaves a dry inner core surrounded by ahydrated outer layer (fish eyes) that is nearlyimpossible to hydrate further and must be fil-tered. Shearing and filtering is recommendedwhen preparing HEC pills, especially if the pillis to be used for fluid-loss control.

Adding dry HEC to concentrated brine willusually require heat to fully hydrate and todevelop complete viscosity profile. The amountof heat required to easily hydrate HEC in high

8·4


density brine is a function of the total salt insolution, the amount of HEC added, the shearrate of the mix and the total time. A generalrule of thumb for fluid systems above about12 lb/gal (1.44 SG) is 120° to 140° F (48.8° to60° C), mixed for 6 to 10 hrs under high shear.Operationally, this means circulating the fluidthrough a centrifugal pump until the temper-ature is reached, slowly adding the polymerand continuing to circulate for 6 to 10 hrs oruntil the viscosity no longer increases withadditional mixing. In order to minimize theformation of “fish eyes,” it is important to addpolymer slowly and ensure that all lumps of dryHEC are completely desegregated before adding.

HEC is completely acid soluble. The pre-mium grades produce less than 0.1 wt % residueafter exposure to HCl. HEC pills can be “broken”with HCl and organic acids and mild oxidizers.

HEC can be stabilized at temperaturesgreater than 250° F (121.1° C), depending on thebase brine. Contact your M-I SWACO representa-tive for recommendations.

SAFE-VISSAFE-VIS is a high-grade, clarified HEC polymer.It is a glyoxylated form of HEC with an averagemolecular weight of approximately 1,000,000daltons. This glyoxyl coating retards hydrationuntil either time, temperature or solution pH(above about 7) strips the coating from the sur-face. This retardation allows a more controlledand full hydration. SAFE-VIS is used to viscosifyfreshwater, seawater or brine fluids used inworkover and completion operations. SAFE-VIS

is normally added at concentrations of 2 to

8·5


4 lb/bbl (0.9 to 1.8 kg/bbl) for viscous pillsand 0.1 to 0.5 lb/bbl (0.05 to 0.23 kg/bbl) fordrag reduction.

SAFE-VIS is packaged in 50-lb (22.7-kg)multi-wall, waterproof sacks.

SAFE-VIS HDE SAFE-VIS HDE liquid viscosifier is a suspensionof high-quality HEC polymer in water-solublecarrier. It is specially formulated for high den-sity CaCl2, CaCl2/CaBr2, CaBr2, CaBr2, CaCl2/CaBr2/ZnBr2 and most other divalent brines.Treatments usually range between 2 to 5 gal/bbl(7.6 to 18.9 L/bbl) of completion fluid. Specialmixing procedures are required for ZnBr2

fluids in the 15 to 16.5 lb/gal (1.8 to 1.98 SG)density range.

SAFE-VIS HDE is packaged in 5-gal (18.9-L)plastic cans. SAFE-VIS HDE contains 4.5 lb(2.04 kg) HEC per 5-gal (18.9-L) can.

SAFE-VIS OGSSAFE-VIS OGS liquid viscosifier is a suspensionof high-quality HEC polymer in a water dis-persible, synthetic carrier. SAFE-VIS OGS liquidviscosifier is specially formulated to pass Oiland Grease, LC50 and Static Sheen Test require-ments for offshore GoM use. The product vis-cosifies single salt CaCl2 and CaBr2 brinesand all monovalent-salt brines. Treatmentsusually range between 0.5 to 1.5 gal/bbl (1.9to 5.7 L/bbl) of completion fluid.

SAFE-VIS OGS is packaged in 5-gal (18.9-L)plastic cans. SAFE-VIS OGS contains 16.5 to 17 lb(7.5 to 7.7 kg) HEC per 5-gal (18.9-L) can.

8·6


SAFE-VIS LESAFE-VIS LE liquid viscosifier is a suspension ofhigh-quality HEC polymer in a highly purifiedmineral oil carrier (UK OCNS category “D” rat-ing). SAFE-VIS LE is designed to viscosify single-salt CaCl2 brines and all monovalent-salthalide brines. Treatments usually rangebetween 0.5 to 1.5 gal/bbl (1.9 to 5.7 L/bbl)of completion fluids.

SAFE-VIS LE is packaged in 5-gal (18.9-L) plas-tic cans. SAFE-VIS LE contains 16.5 to 17 lb (7.5 to7.7 kg) HEC per 5-gal (18.9-L) can.

SAFE-VIS ESAFE-VIS E liquid viscosifier is a suspensionof high-quality HEC polymer in a highly puri-fied mineral oil carrier. SAFE-VIS E is designedto viscosify single-salt CaCl2 brines and allmonovalent-salt halide brines. Treatmentsusually range between 0.5 to 1.5 gal/bbl (1.9to 5.7 L/bbl) of completion fluids.

SAFE-VIS E is packaged in 5-gal (18.9-L) plasticcans. SAFE-VIS E contains 16.5 to 17 lb (1.9 to5.7 L/bbl) HEC per 5-gal (18.9-L) can.

8·7


HEC Mixing ProceduresI. Rigsite preparation for HEC fluid-loss

pills using SAFE-VIS1 (25-bbl high-vis

pill with 4-lb/bbl [1.8-kg/bbl] HEC

as example)1. Prepare a 25-bbl viscous fluid-loss pill approx-

imately 24 hrs prior to needing to pump thepill. The recommended pill loading for fluid-loss control is 4-lb/bbl (1.8-kg/bbl) HEC.

2. Prepare a pill as follows:3. Transfer 25-bbl filtered brine into Mixing Pit.4. Open 2 bags SAFE-VIS HEC and add to brine

through the hopper slowly (10 to 20 minper bag).

5. Mix at high speed and shear pill throughpump and hopper.

6. Adjust pH to 8 to 9 with caustic soda (NaOH).7. As pill begins to thicken, check Fann 35 rheol-

ogy. Shear until readings level off for severalsamples (6/3 RPM readings should be at least80% of 200/150 at room temperature).

8. Filter pill through 10-micron filter cartridgesinto pit not used for mixing pill.

9. Pill is now ready to pump. Allow it to setuntil needed, continued blending shouldnot be required.

1SAFE-VIS Dry HEC should only be used for freshwater and under-saturated brines such as seawater or saltwater less than about9 lb/gal (1.1 SG) density. SAFE-VIS HEC powder is coated with a pHsensitive anti-dispersing agent that allows its addition to freshwateror under-saturated brine without its premature hydration whichleads to the formation of fish eyes. This coating is stripped off thepolymer above a pH of 7, after which, hydration is rapid.

8·8


Example rheology listed below:

II. Rigsite preparation for HEC pills

using SAFE-VIS E/OGS/LE Liquid HEC1

(25-bbl high-vis pill with 4-lb/bbl

[1.8-kg/bbl] HEC as example)1. Prepare a 25-bbl viscous fluid-loss pill approx-

imately 24 hrs prior to needing to pump thepill. The recommended pill loading for fluid-loss control is 4-lb/bbl (1.8-kg/bbl) HEC

2. Prepare a pill as follows:3. Transfer 25-bbl filtered brine into Mixing Pit.4. Open 6 buckets of SAFE-VIS E/OGS/LE and

thoroughly stir the contents of each bucket.5. Dump all buckets through the hopper (1 to 2

min per can). If unable to add all cans throughhopper, add cans directly into pit as close toagitator blades as possible.

6. Shear pill through pump and hopper.7. As pill begins to thicken, check Fann 35 rheol-




1SAFE-VIS E/OGS/LE Liquid HEC should only be used for brines with asignificant amount of “free water.” Fully saturated brines are noteasily viscosified with non-water-soluble, liquid SAFE-VIS products.High shear and/or heat is required when viscosifying saturatedbrines with these products.

8·9

6 rpm 170 @ 72° F

3 rpm 140 @ 72° F



III. Rig site preparation for HEC pills

using SAFE-VIS HDE liquid HEC1

(25-bbl high-vis pill with 4-lb/bbl

[1.8-kg/bbl] HEC as example)1. Prepare a 25-bbl viscous fluid-loss pill approx-

imately 24 hrs prior to needing to pump thepill. The recommended pill loading for fluidloss control is 4-lb/bbl (1.8-kg/bbl) HEC.

2. Prepare a pill as follows:3. Transfer 25-bbl filtered high density brine

into Mixing Pit.4. Open 20 buckets of SAFE-VIS HDE and thor-

oughly stir the contents of each bucket.5. Dump all buckets through the hopper as

quickly as possible (5 to 10 sec per can). Ifunable to add all cans through hopper, addcans directly into pit as close to agitatorblades as possible.

6. Shear pill through pump and hopper.7. As pill begins to thicken, check Fann 35 rheol-




1SAFE-VIS HDE Liquid HEC can be for any brine and does not requireexcess shear or heat. SAFE-VIS HDE contains 4.5-lb (2-kg) HEC per5-gal (18.9-L) bucket.

8·10

6 rpm 170 @ 72° F

3 rpm 140 @ 72° F



Cross-Linked HEC PillsSAFE-LINK 110 and 140SAFE-LINK fluid-loss pills are comprised of achemically modified HEC polymer, cross-linkedwith high pH. SAFE-LINK pills are used to controlloss of clear brine fluid to the formation byapplying a very viscous material across the for-mation face, virtually stopping the flow of brineinto the formation. SAFE-LINK pills are designedto work in seawater, NaCl, NaBr, KCl, CaCl2,CaBr2, and ZnBr2 brine ranging from 8.6 toabout 16 lb/gal (1.92 kg/L). SAFE-LINK 110weighs 11 lb/gal (1.32 kg/L). SAFE-LINK 140weighs 14 lb/gal (1.68 kg/L). SAFE-LINK 160weighs 16 lb/gal (1.92 kg/L). SAFE-LINK isdegradable by hydrochloric acid, acetic acid,formic acid and temperatures greater than250° F (121.1° C), however, these pills can bestabilized to temperatures greater than 250° F(121.1° C) with proprietary stabilizing agents.

SAFE-LINK is pre cross-linked and packaged in5-gal (18.9-L) pails. No additional cross-linkingis required on the rig. A fluid-loss pill is mixed bysimple addition of the SAFE-LINK material toviscosified or non-viscosified completion brine.

SAFE-LINK Mixing Instructions:For a 60-ft (18.2-m), 7∑-in. (190.5-mm) perfo-rated interval, mix a 10-bbl pill as follows:

Add 32 pails of SAFE-LINK additive to 260 gal(984.2 L) of either viscosified or non-viscosified

8·11

6 rpm 170 @ 72° F

3 rpm 140 @ 72° F


completion brine. Stir gently with a lightningmixer or paddle mixer to slurry the SAFE-LINK

additive into the brine. Do not over-shear theslurry; the slurry should be lumpy or stringywhen pumped.

Note: Due to the SAFE-LINK additive’s cross-linking mechanism, differential pressure greaterthan 2,000 psi (137.9 bar) is not advisable.

Pills Containing Bridging SolidsSEAL-N-PEEL

SEAL-N-PEEL is a uniquely engineered fluid-loss-control pill, designed specifically as a contin-gency for all high-rate gravel-pack or water-packcompletions. SEAL-N-PEEL provides superb sup-plemental fluid-loss control when mechanicaldevices either fail or are unavailable. It depositsan impenetrable filter cake against the insidesurface of the screen assembly. When the wellis ready to go on stream, the cake simply peelsaway, using production pressure and flow asthe lift-off mechanism. The SEAL-N-PEEL base isblended on location or at an M-I SWACO facilityand transported to location in 25-bbl MPT tanks.Carbonate is added to the base fluid prior topumping the pill downhole.

The SEAL-N-PEEL lift-off pressures aretypically < 5-psi (0.34 bar) on average.

A volume of intact SEAL-N-PEEL — that is,a pill that has not been diluted with brine —must reach screens to be effective. Dilutionoccurs in interface with brine while pumpingdown workstring and in annular volumebetween ports that pill exits workstring and topof gravel-pack packer. The spacers pumpedahead of solids-laden pill are used to ensure

8·12


that this intact pill will reach screens. Pumprates while pumping SEAL-N-PEEL must begreater than loss rate to formation.

Consult M-I SWACO technical lab for opti-mum formulation.

SEAL-N-PEEL Mix Instructions (15 bbl)1. Add 14 bbl of the SEAL-N-PEEL base gel

to blender.2. Add recommended carbonate at 1 to 2 min

per sack to blender.3. Blend at medium speed until smooth mixture

appears (15 min maximum).4. Blend at slow speed until pill is pumped.5. Pump recommended SEAL-N-PEEL base spac-

ers ahead and behind of solids-laden pillbased on the following table:

• Reduce loss rate to formation by filling annu-lus with seawater to reduce hydrostatic head.

• Pump rate while spotting pill must be greaterthan loss rate.

• Spot pill as close to gravel-pack packeras possible.

• A balanced pill is recommended.• Record loss rate before pill spotted, after pill

in place, volume spacers, volume pill withcarbonate, pump rate while spotting pill andlosses while spotting pill.

• Increase volume to 25 bbl of SEAL-N-PEEL withcarbonate for extreme losses.

8·13

Loss rate Spacer Volume

< 25 bbl/hr 3 bbl

25 – 45 bbl/hr 6 bbl

> 45 bbl/hr 9 bbl


OPTIBRIDGE PILLSOPTIBRIDGE pills are designed using proprietarysoftware that examines data from the targetedformation, including maximum pore size open-ing and permeability and combines that inputwith the bridging-particle information.OPTIBRIDGE software automatically generates atarget line of the optimum blend of particlesthat will effectively minimize solids and filtrateinvasion. Once the optimum blend is known,the ratio of bridging materials is matched tothe formation characteristics. A fit-for-purposeblend made of either calcium carbonate or saltwill effectively seal the formation.

Sized-Salt PillsSized-salt pills can be used in a broad densityspectrum ranging from 10.5 to 17.0 dependingon the base brine and concentration of bridgingsolids utilized. Typically salt pills are mixed insaturated sodium chloride brine, but they canalso be used with potassium chloride, calciumchloride, sodium bromide, calcium bromide andzinc bromide as long as the base brine is satu-rated with respect to sodium chloride to preventsolubilizing the sized sodium chloride bridgingsolids. These fluid-loss control systems have aunique synergistic blend of polymers whichcreate optimum rheological and suspensionproperties providing long-term stability, andcontingent to the thermal extender packageused they can withstand bottomhole temper-atures up to 325° F (162.7° C).

Optimized particle-size distributions sealformations and completion screens over a wide

8·14


range of permeability minimizing formationdamage. Sized-salt pills can be removed with anacid soak to destroy the internal polymers andan unsaturated (with respect to sodium chlo-ride) brine to dissolve the sodium chloridebridging agents. Consult M-I SWACO technicallab for optimum pill and breaker formulation.

Bridgesal Ultra SuperfineMixing ProcedureBefore adding Bridgesal^ Ultra Superfine, thebase brine must be saturated with respect tosodium chloride to prevent the bridging saltfrom being dissolved. Refer to sodium chloridesaturation tables for each respective base brine.

Mixing Instructions1. Start with the desired amount of brine in a

clean slugging pit or mixing tank. 2. Add ∑ can (2.5 gal [9.46 L]) of DEFOAM 2* for

every 20 bbl of fluid.3. If necessary, add the required amount of

EVAPORATED SALT through the mud hopperat 2 to 3 min per sack for saturation withrespect to NaCl.

Note: After saturating the brine withsodium chloride, it should be filtered to ensurethe removal of any particles above 44 microns.If Ultrasal 5 or 10 is used to saturate the brine,no filtering is required.4. Add the required amount of Bridgesal Ultra

Superfine (50 to 70 lb/bbl [22.6 to 31.8 kg])through the mud hopper at 6 to 8 min persack. Add additional DEFOAM 2 as needed tocontrol foaming.

8·15

^Bridgesal is a mark of Texas Brine Corporation.


5. If additional FL-7 Plus^ is needed add througha hopper at 6 to 8 min per sack.

6. If CaCl2 brine is used, add 2 to 5 lb/bbl (0.9 to2.27 kg) of pH buffer through a hopper at 3to 4 min per sack.

7. Allow the pill to agitate for 30 to 45 min priorto pumping downhole.

Note: If a mud hopper is not available, addall products at maximum agitation as possiblewhile circulating through a pump. If the BHTis above 250° F (121.1° C), contact an M-I SWACOrepresentative.

Bridgesal Ultra Mixing ProcedureBefore adding Bridgesal Ultra, the base brinemust be saturated with respect to sodium chlo-ride to prevent the bridging salt from beingdissolved. Refer to sodium chloride saturationtables for each respective base brine.

Mixing Instructions1. Start with the desired amount of brine in a

clean slugging pit or mixing tank. 2. Add ∑ can (2.5 gal [9.46 L]) of DEFOAM 2 for

every 20 bbl of fluid. 3. If necessary, add the required amount of

EVAPORATED SALT through the mud hopperat 2 to 3 min per sack for saturation withrespect to NaCl.

4. Add the required amount of Bridgesal Ultra(50 to 60 lb/bbl [22.6 to 27.2 kg]) throughthe mud hopper at 6 to 8 min per sack.Add additional DEFOAM 2 as needed tocontrol foaming.

5. If additional FL-7 Plus is needed add through ahopper at 6 to 8 min per sack.

8·16

^FL-7 Plus is a mark of Texas Brine Corporation.


6. If CaCl2 brine is used, add 2 to 5 lb/bbl (0.9 to2.27 kg) of pH buffer through a hopper at 3 to4 min per sack.

7. Allow the pill to agitate for 30 to 45 min priorto pumping downhole.

Note: If a mud hopper is not available, addall products at maximum agitation as possiblewhile circulating through a pump. If the BHTis above 250° F (121.1° C), contact an M-I SWACOrepresentative.

Hysal Superfine/Hysal HD PillHysal Superfine and Hysal HD are fluid prod-ucts designed to be used in high density brines(12.5 to 18.2 lb/gal [1.49 to 2.18 SG]).

Mixing Procedures12.5 to 16 lb/gal (1.49 to 1.92 SG)

1. Add 0.5 gal/bbl (1.89 L/bbl) of Hysal Activatorto the brine.

2. Add 100 lb/bbl (45.4 kg/bbl) of HysalSuperfine at 6 to 8 min per sack througha hopper.

3. Allow the slurry to mix, circulating through achoke to generate temperature, for approxi-mately 4 hrs.1

16 to 17.5 lb/gal (1.92 to 2.1 SG)

1. Add 0.5 gal/bbl (1.89 L/bbl) of Hysal Activatorto the brine.

2. Add 100 (45.4 kg/bbl) of Hysal HD at 6 to 8min per sack through a hopper.

3. Allow the slurry to mix, circulating through achoke to generate temperature, for approxi-mately 4 hrs.1

1HEC polymer may be supplemented into the pill mix (at 2 to3 lb/bbl [0.9 to 1.36 kg/bbl]) for initial viscosity enhancement untilstarches are thermally activated at bottom-hole temperatures.

8·17


17.5 to 18.2 lb/gal (2.1 to 2.18 SG)

Note: Formulations from 17.5 to 18.2 lb/gal(2.1 to 2.18 SG) should be verified by laboratorytesting.

If the BHT is over 250° F (121.1° C), contact an

M-I SWACO representative.

8·18

Chapter 9CORROSION INHIBITION AND PACKER FLUIDS


9. CORROSIONINHIBITION

ANDPACKERFLUIDS

CORROSION INHIBITION AND PACKER FLUIDS

M-I SWACO offers corrosion inhibitors, oxygenscavengers and biocides to minimize or preventcorrosion in completion, workover and reservoirdrill-in fluid systems.

SAFE-CORSAFE-COR* is an amine-based corrosion inhibitorthat forms an inert film on downhole oilfieldtubulars. SAFE-COR should be used as the pri-mary inhibitor for all non-zinc bromide packer-fluid applications in which Corrosion ResistantAlloys (CRA) material is used for productiontubing and the maximum temperature is lessthan 350° F (177° C). The standard inhibitortreatment of 55 U.S. gal/100 bbl (13.1 L/m3)should be applied. An oxygen scavenger shouldbe added at standard dosage and biocide whenappropriate (less than saturated salt). Formate-based brines for high-temperature applicationsdo not strictly require a chemical corrosioninhibitor in the presence of CRAs. In such cases,a pH buffer, such a potassium carbonate, shouldbe added to reduce the rate of corrosion. Oxygenscavenger and/or biocide may be added in caseswhere under-saturated formate brines are used.

SAFE-COR 220XSAFE-COR 220X is a brine-soluble amide-corrosion inhibitor comprising a solution ofglycoside-amide in water. Typical treatmentlevel is 1 to 1.3% by volume (55 gal/100 bbl[13.1 L/m3]). SAFE-COR 220X is recommended forCO2 and H2S environments when the tempera-ture is <250° F (<121° C).

9·1


SAFE-COR ESAFE-COR E corrosion inhibitor is a modifiedamine-type additive formulated to protect alloilfield tubular goods, for solubility in clearbrine completion fluids and to minimize envi-ronmental impact. It helps prevent generalcorrosion attack on casing, tubing and down-hole tools in contact with completion brines.SAFE-COR E is a highly concentrated productdesigned and packaged for use in solids-freeworkover and completion brines.

SAFE-COR HTSAFE-COR HT is a high-temperature corrosioninhibitor effective in ZnBr2 solutions. It is asolution of an inorganic sulfur salt in water.Typical treatment level is 0.33% by volume(55 gal/400 bbl [3.27 L/m3]). SAFE-COR HT,which forms a protective, very thin film ofiron-sulfide scale, should be used only for

carbon-steel tubulars.

SAFE-SCAV NASAFE-SCAV* NA is a bisulfite-based oxygenscavenger for non-calcium brines. Typical treat-ment level is 0.025% by volume (1 gal/100 bbl[0.24 L/m3]).

SAFE-SCAV CASAFE-SCAV CA is an oxygen scavenger forcalcium-based brines. An organic salt. Typicaltreatment level is 15 lb/100 bbl (0.43 kg/m3).

9·2


SAFE-SCAV HSSAFE-SCAV HS is a brine-soluble, amine-basedhydrogen sulfide scavenger. Typical treatmentlevel is 0.025% by volume (1 gal/100 bbl[0.24 L/m3]).

Application of SAFE-COR CorrosionInhibitors in Packer FluidsCorrosion inhibition is recommended whenclear-brine completion fluids are used aspacker fluids. Corrosion rate data for non-zincbromide brines suggest these brines are notgenerally corrosive. Most non-zinc bromidebrines show an average corrosion rate of lessthan 5 milli-inches per year (m.p.y.) to oilfieldgrade carbon steel at temperatures up to 350° F(177° C). Zinc bromide fluids are inherentlyacidic. These brines can be very corrosive ifnot adequately inhibited.

Organic filming inhibitors, such as SAFE-COR,SAFE-COR E and SAFE-COR 220X, act by forminga protective barrier or film on the surface ofthe metal. Film-forming inhibitors consist of apolar group and a long, non-polar (hydrocarbon)chain. The polar group contains what is referredto as a heteroatom, i.e., oxygen, phosphorous,sulfur or more typically, nitrogen. The nitrogencontaining molecules are most typically amines.The molecular structure of these amines is suchthat “free” electrons are capable of forming achemisorptive bond with metallic iron. Thisbond holds the molecular “head” onto the sur-face of the metal and the hydrocarbon “tail”acts as a “film” — thus the name “filmingamine.” The strength of the adsorptive bond

9·3


and how long this bond lasts depends on theenvironment, i.e., the molecular structure of thechemical, the solubility of the material in theaqueous medium (brine), movement of fluidacross the surface, physical disruption, etc.

The amines used for packer-fluid applica-tions are much different than those used inproduction applications. The amines in packerfluids must be completely soluble in the brine,whereas most production chemical amines areoil soluble or water dispersible. The ability ofa packer-fluid amine to maintain its adsorbedlayer is greatly enhanced by the fact that oncein place, no aggressive movement of fluid occurs,nor does a concentration gradient exist to allowdiffusive forces to act. The fact that it is a closedsystem, the amine is not chemically reacted ordestroyed as part of the filming process and thebrine contains a relatively high concentration ofamine, self “healing” can occur and the filmshould last indefinitely.

SAFE-COR HT is an inorganic inhibitor thatacts at the anodic site, reacting with the oxi-dized iron by a chemical reaction forminga thin, protective layer. SAFE-COR HT is athiocyanate-based inhibitor and, like othersulfur-based products, should not be usedwith chrome alloys.

The primary chemical species directlyinvolved in the corrosion process include acidand oxygen. Besides the alkaline inhibitor, cor-rosion inhibition should include: 1) eliminatingoxygen in the brine, and 2) increasing pH wherefeasible. Other species such as sulfur, chloridesand certain bacteria also impact the corrosionprocess. Bacteriacides should be added to those

9·4


fluid systems that would allow bacteria to grow.Although not specific, brines with a density lessthan about 11.0 lb/gal (1.32 SG) should be treatedwith biocide for packer-fluid use.

CRA TubingCorrosion Resistant Alloys (CRA) have beenused extensively in wellbore construction overthe last couple of decades. With the develop-ment of deeper, hotter and higher-pressuredwells, new generation CRAs are being producedthat possess greater Yield Strength (YS) thanprevious versions. For example, “Super” and“Hyper” grade 13% chromium stainless steels(13-Cr) achieve yield strengths of 95 to 110 ksi andabove, by alloying the iron-chromium withhigh percentages of molybdenum, nickel andother alloying elements. These higher strengthsare more prone to Stress Corrosion Cracking(SCC) than their lower-strength counterparts.

As their name suggests, CRA tubulars anddownhole equipment are generally resistantto corrosive environments and each is selectedfor an application for which it is best suited.Depending on the amount and type of alloyingelements and homogeneity of the microstruc-ture, localized corrosion such as pitting canlead to sudden and catastrophic cracking fail-ure. 13-Cr stainless steel is the most commonMartensitic Stainless Steel (MSS) used for itsresistance to sweet acid-gas (CO2) corrosion,however, these materials are susceptible tolocalized H2S attack. For sour-gas corrosion,higher-chrome alloys, such as the DuplexStainless Steels (DSS) of 22%-Cr, 25%-Cr and

9·5


9·6

28%-Cr, or even pure nickel-chrome alloys, suchas Inconel and Hastelloy ,̂ are used. Althoughmore resistant to H2S, these higher alloys areprone to hydrogen embrittlement under certainconditions. Regardless of the metallurgy, thehigher-strength materials are always moreprone to environmentally induced SCC thanlower-strength materials or equal-strength low-alloy, carbon steel. SCC is a corrosion phenome-non related to the metallurgy, internal andexternal stresses and the corrosiveness of theenvironment in which the metal resides.

Thiocyanate (SCN–) decomposes at hightemperature and forms H2S. Consequently, theuse of a thiocyanate corrosion inhibitor, such asSAFE-COR HT with 13-Cr or DSS material is usedfor tubing is not recommended.

The other important environment identifiedas increasing the risk of SCC with CRA materialsis chloride content. Chloride Stress CorrosionCracking (CSCC) of high-strength 13-Cr and even22-Cr DSS has been reported. Whereas, in mostof these reported cases, sulfur or thiocyanatehas also been identified in the packer fluid, therole of the chloride ion (Cl–) should not beoverlooked. At least in some high-strength13-Cr cases, chlorides were implicated in CSCCwithout evidence of sulfur of any type. For thisreason, M-I SWACO recommends using a chlo-ride-free packer fluid when it is placed behind>80 ksi YS 13-Cr steel at temperatures greaterthan about 200° F (93° C).

^Mark of Haynes International, Inc.


9·7

Flu

id T

yp

eD

en

sity

Te

mp

era

ture

Me

tall

urg

yIn

hib

ito

r P

kg

.C

on

cen

tra

tio

n

Wat

er8.

334

lb/g

al<3

50°

FSt

and

ard

/CR

ASA

FE-C

OR

55 g

al/1

00 b

bl(9

98 k

g/m

3 )(<

176°

C)

(13.

1 L/

m3 )

S AFE

-SC

AV

NA

5 ga

l/50

0 bb

l(.2

38 L

/m3 )

Glu

te 2

55

gal/

500

bbl

(.238

L/m

3 )C

aust

ic S

oda

To p

H 9

.5

Wat

er8.

334

lb/g

al>3

50°

FSt

and

ard

/CR

AG

lute

25

5 ga

l/50

0 bb

l(>

176°

C)

(.238

L/m

3 )C

aust

ic S

oda

To p

H 9

.5

Form

ates

All

den

siti

es<4

00°

FSt

and

ard

/CR

AK

car

bon

ate

5 lb

/bbl

(<20

4° C

)(1

4.3

kg/m

3 )

Con

tin

ues

on

nex

t p

age


9·8

Flu

id T

yp

eD

en

sity

Te

mp

era

ture

Me

tall

urg

yIn

hib

ito

r P

kg

.C

on

cen

tra

tio

n

Na-

K/C

l-B

rA

ll d

ensi

ties

<350

° F

Stan

dar

dSA

FE-C

OR

55 g

al/1

00 b

bl(<

176°

C)

(13.

1 L/

m3 )

Glu

te 2

515

lb/1

00 b

bl(.4

28 k

g/m

3 )C

aust

ic S

oda

To p

H 9

.5

Na-

K/C

l-B

rA

ll d

ensi

ties

>350

° F

Stan

dar

dC

onta

ct M

-I S

WA

CO

Tec

hn

ical

Ser

vice

s(>

176°

)

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age


9·9

Flu

id T

yp

eD

en

sity

Te

mp

era

ture

Me

tall

urg

yIn

hib

ito

r P

kg

.C

on

cen

tra

tio

n

Na-

K/C

l-B

rA

ll d

ensi

ties

<350

° F

CR

ASA

FE-C

OR

55 g

al/1

00 b

bl(<

176°

C)

(13.

1 L/

m3 )

S AFE

-SC

AV

CA

15 lb

/100

bbl

(.428

kg/

m3 )

Glu

te 2

55

gal/

500

bbl

(.238

L/m

3 )C

aust

ic S

oda

To p

H 9

.5

CaC

l 2-C

aBr 2

All

den

siti

es<3

50°

FSt

and

ard

SAFE

-CO

R55

gal

/100

bbl

(<17

6° C

)(1

3.1

L/m

3 )S A

FE-S

CA

VC

A15

lb/1

00 b

bl(.4

28 k

g/m

3 )

Con

tin

ued

from

pre

viou

s p

age

Con

tin

ues

on

nex

t p

age


9·10

Flu

id T

yp

eD

en

sity

Te

mp

era

ture

Me

tall

urg

yIn

hib

ito

r P

kg

.C

on

cen

tra

tio

n

CaC

l 2-C

aBr 2

All

den

siti

es>3

50°

FSt

and

ard

Con

tact

M-I

SW

AC

O T

ech

nic

al S

ervi

ces

(>17

6° C

)

CaB

r2A

ll d

ensi

ties

<350

° F

CR

ASA

FE-C

OR

55 g

al/1

00 b

bl(<

176°

C)

(13.

1 L/

m3 )

S AFE

-SC

AV

CA

15 lb

/100

bbl

(.428

kg/

m3 )

ZnB

r 2A

ll d

ensi

ties

<350

° F

Stan

dar

dSA

FE-C

OR

HT

55 g

al/4

00 b

bl(<

176°

C)

(3.2

7 L/

m3 )

S AFE

-SC

AV

CA

15 lb

/100

bbl

(.428

kg/

m3 )

S AFE

-SC

AV

HS

5 ga

l/10

0 bb

l(1

.19

L/m

3 )

Con

tin

ued

from

pre

viou

s p

age

Con

tin

ues

on

nex

t p

age


9·11

Flu

id T

yp

eD

en

sity

Te

mp

era

ture

Me

tall

urg

yIn

hib

ito

r P

kg

.C

on

cen

tra

tio

n

ZnB

r 214

.5 t

o 16

.5 lb

/gal

<300

° F

CR

ASA

FE-C

OR

55 g

al/1

00 b

bl(1

,737

to

(<14

9° C

)(1

3.1

L/m

3 )1,

977

kg/m

3 )SA

FE-S

CA

VC

A15

lb/1

00 b

bl(.4

28 k

g/m

3 )

ZnB

r 214

.5 t

o 16

.5 lb

/gal

>300

° F

CR

AC

onta

ct M

-I S

WA

CO

Tec

hn

ical

Ser

vice

s(1

,737

to

(>14

9° C

)1,

977

kg/m

3 )

ZnB

r 2>1

6.5

lb/g

al>2

00°

FC

RA

Con

tact

M-I

SW

AC

O T

ech

nic

al S

ervi

ces

(>1,

977

kg/m

3 )(>

93°

C)

Con

tin

ued

from

pre

viou

s p

age

Chapter 10FILTRATION


10. FILTRATION

FILTRATION

10·1

FILTRATION

Filtration is a process used to remove suspendedmaterials from liquids. In completion fluids, thesuspended materials can include weightingagents, drill solids, perforating debris, sand,scale, rust, etc. These suspended materials, ifleft in the liquid, can damage the permeabilityof the formation.

By selecting the proper filtration method,fluids can remain clean and non-damagingand the process can be accomplished in acost-effective manner.

Two types of filtration are used in comple-tion and workover operations:

1. Depth filtration utilizing a filter press withrecessed chamber plates and DE.

2. Surface filtration-using cartridges.In most cases the combination of these units

provides the most efficient filtration package.

Equipment Design Diatomaceous Earth (DE)

Filtration System A Diatomaceous Earth (DE) filtration systemincludes a downstream double-pod cartridgefiltration unit, which acts as a polishing unitand a guard unit against DE bleed-through.• The plate and frame unit should have O-ring

gasket plates to eliminate leakage whilefiltering.

• All drain ports in the drip pan beneath theplates of the filter press should be plugged toensure all of the filter cake and fluid trappedbetween the plates is collected when the pressis opened. Fluid can then be salvaged.

10·2

FILTRATION

• Prior to the regeneration process, proper blow-down with air is required to remove fluidtrapped in the filter cake within the recessedchambers of the plates and within the mani-fold system of the press.

• All filtration units should have an apronrunning the full length of the drip pan areato above the plates on both sides of the pressto eliminate potential spill while the pressis opened for regeneration of DE. Any fluiddropped into the drip pan of the press ispumped (diaphragm) into a MPT tank or othersuitable holding vessel. This tank is checked forreclaimable fluid, which can be decanted intoanother MPT tank or into the rig’s active system.

• All hoses on the filtration unit should haveball valves that can be closed or opened duringoperation. This allows the operator to closethe valve at the disconnect point, saving fluidwhen repositioning equipment, rigging up orrigging down. The trapped fluid from the hosesis evacuated back into the pit system, elimi-nating spillage and offer maximum recovery.Portable troughs at the disconnect points arerecommended.

Pod Cartridge Filter UnitTypically, these units are “dual pod” construc-tions with interconnecting piping for eitherparallel, in-series or bypass configuration. Thevessels or housings hold disposable cartridges.The number of cartridges per vessel may varyper manufacturer. This equipment is desirableon lightweight fluids and small inexpensivebrine cleanups. Also, the lightweight and small

10·3

FILTRATION

footprint makes cartridge filtration more favor-able over larger DE units if the cartridge unitcan maintain the parameters of filtration(cleanliness, pump rate, density).

10·4

Type of Fluid Expected Filtration PackageComments Solids Loading Required

Fresh seawater Low 2- or 10-micronDump on return absolute cartridge

from well filters

Light brine Low 2- and/or Dump on return 10-micron

from well or pre-filterfilter for reuse, cartridge filteri.e., NaCl/KCl

Medium-weight Low 2- and/orbrine filter for 10-micron

reuse, i.e., CaCl2 pre-filtercartridge filter

Medium-weight High Pre-filterbrine filter for 10-micron

reuse, i.e., CaCl2 and/or 2-micronabsolute cartridge

filter or DEsystem and 2-or 10-micron

cartridge filter

Heavy-weight Low/High DE system withbrine filter for 2/10 cartridge

reuse, i.e., NaBr, filtersCaBr2, K formate

Very heavy-weight High DE system withbrine, i.e., ZnBr2 2/10 cartridge

filters

Filtration Requirement Summary

FILTRATION

MI SWACO Filtration Equipment and Materials

All filtration presses are manufactured withbackup hydraulic systems. The filter press isequipped with dual-hydraulic pumps. Filterplates are gasket sealed. Extra filter clothes aresent out to assure operations with no downtime.

M-I SWACO maintains 1,600-ft2 (148.6-m2),1,500-ft2 (139.4-m2), 1,135-ft2 (105.4-m2), 800-ft2

(74.3-m2), and 600-ft2 (55.7-m2) filter presses.All presses are designed to be stackable. AllM-I SWACO slurry skids are equipped withdual downstream guard units equipped tohold five (5) platinum cartridges per pod.The unique design of platinum cartridges usessegregated flow channels and flow chambers tomaximize the effective surface area of pleatedfilter media within a 6∏-in. (158.8-mm) ODcartridge.

One platinum series cartridge filter isdesigned to replace up to ten standard 2.5-in.(63.5-mm) OD standard cartridges of similarlength. Available in a variety of media, this car-tridge can be constructed with metal end capsand cores for high-temperature applications.

With maximum recommended flow rates of100 gal/min (378.5 L/min) this platinum seriesfilter is the solution to achieving optimum per-formance while minimizing filtration cost.

M-I SWACO also maintains stand-alone dualpod units. These units can be loaded with everysize filter available.

The M-I SWACO 65-bbl blending tanks havetwo impeller blades to assure proper blendingaction. The tanks are equipped with chemical

10·5

FILTRATION

hoppers with jetted action. They have 6-in.(152.4-mm) slope discharges for properdischarge to connect for tank drainage.

M-I SWACO utilizes turbo shear units toshear viscous pills and blend chemicals.Shear pumps are powered with a skid-mounted diesel engine.

M-I SWACO has 3-bbl wet tanks with air-powered motors.

M-I SWACO provides DE bulk tanks that holdone (1) ton of Diatomaceous Earth. The tankshave safe holding racks mounted on top of thefiltration-slurry skids for safe operations. Thesetanks are equipped with air-operated vibrators.

Pallet boxes that hold two pallets can beloaded from the top and sides. These boxes keepproducts and equipment environmentally safe.

M-I SWACO stocks three grades of diatoma-ceous material: fine grade, medium grade andcoarse grade. DE is available in bulk tanks, 50-lb(22.7-kg) sacks at 18 sacks per pallet and 25-lb(11.3-kg) sacks at 40 sacks per pallet.

M-I SWACO equipment has certified slingsand uses shackles for safe transfer of equipment.Hoses have stainless steel connections withsafely lock ears and are pressure tested and cer-tified. Hoses are labeled for easy identification.

10·6

FILTRATION

10·7

Flow RatesFilter life is longest at low flow rates. As a guide,optimum flow rates should not exceed .5 to.75 GPM (1.9 to 2.8 L/min) per square foot offilter area. Thirty-inch (762-mm) cartridge filtersshould be operated at 1.5 GPM (5.7 L/min) or lessper filter for maximum life and efficiency. Forty-inch (1,016-mm) pleated surface filter cartridgescan be operated at flow rates from 7 to 20 GPM(26.5 to 75.7 L/min) based on micron size selectedand filter area. Systems should be sized to handlemaximum flow-rate conditions plus 10%. Filtersshould be changed before differential pressurereaches 40 psi (2.8 bar).

Serial FiltrationSerial filtration will increase the life of the fil-ters. A 10- or 30-micron absolute prefilter willextend the life of more expensive 2-micronabsolute final filters. When depth-type cartridgesare used, 25- to 50-micron filters are generallyeffective prefilters ahead of 2- to 5-micronfinal filters.

FILTRATION

10·8

DE Filtration Dimensions and SpecificationsPlate and Frame Skid DE Units

1. Unit size: 1,600 ft2 (148.6 m2) Manufacturer: U.S. Filter^Size (L x W x H): 288 x 57 x 91

(7,315 x 1,448 x 2,311 mm)Weight: 28,000 lb (12,701 kg)Filtration surface area: 1,600 ft2 (148.6 m2)

2. Unit size: 1,500 ft2 (139.4 m2) Manufacturer: U.S. FilterSize (L x W x H): 276 x 57 x 91


Micron Size gal/min bbl/day

16-element 1 96 3,291

filter housing 3 144 4,937

5 240 8,229

10 288 9,874

25 336 11,520

50 384 13,156

20-element 1 120 4,114

filter housing 3 180 6,174

5 300 10,286

10 360 12,343

25 420 14,400

50 480 16,457

Maximum Flow Rates

^Mark of U.S. Filter Corporation.

FILTRATION

3. Unit size: 1,135 ft2 (105.4 m2) Manufacturer: U.S. FilterSize (L x W x H): 242 x 57 x 91


4. Unit size: 800 ft2 (74.3 m2) Manufacturer: U.S. FilterSize (L x W x H): 201 x 57 x 91

(5,105 x 1,448 x 2,311 mm)Weight: 20,000 lb (9,072 kg)Filtration surface area: 800 ft2 (74.3 m2)

5. Unit size: 600 ft2 (55.7 m2) Manufacturer: U.S. FilterSize (L x W x H): 211 x 79 x 100

(5,359 x 2,007 x 2,540 mm)Weight: 19,000 lb (8,618 kg)Filtration surface area: 600 ft2 (55.7 m2)

All M-I SWACO DE filtration presses and slurryskids are stackable. Maximum filtration ratesare 12 to 14 bbl/min. This is clean fluid withlittle or no solids. Average filtration rate is10 bbl/min. This takes into account solids anddensity. Things that effect filtration rates are:Density, viscosity, and solids content of thefluid. Mechanically, filtration rates decrease asthe length of the pump suction increases.

Slurry Skids1. • 1,600-, 1,500- and 1,135-ft2

(148.6-, 139.4- and 105.4-m2) units• The slurry skids are 155 x 96 x 101 in.

(3,937 x 2,438 x 2,565 mm)

10·9

FILTRATION

10·10

• The weight of the slurry skid is 12,000 lb(5,443 kg)

• The slurry skids are equipped with acartridge dual pot containing 5 platinumcartridges

• Each cartridge pod contains 5 cartridges• Each platinum cartridge is 40 in.

(1,016 mm) long• It takes approximately 10 min to change a

set of platinum cartridges• The slurry skid may be stacked on top of the

filter press• Each slurry skid is equipped with a ladder

and a yo-yo device for fall protection

2. • 800-ft2 (74.3-m2) units• The slurry skids are 120 x 66 x 89 in.

(3,048 x 1,676 x 2,261 mm)• The weight of the slurry skid is 8,000 lb

(3,629 kg)• The cartridge dual pods are separate for the

slurry skid• Each cartridge pod contains 19 cartridges

and is 29.5 in. (749.3 mm) in length• It takes approximately 15 min to change a

set of cartridges• Each cartridge weighs 1.5 lb (0.68 kg)• The slurry skid may be stacked on top of the

filter press• Each slurry skid is equipped with a ladder

and a yo-yo device for fall protection

3. • 600-ft2 (55.7-m2) units• The filter press and slurry skid are built

into one skid• The total weight 19,000 lb (8,618 kg)

FILTRATION

• The dimensions are 211 x 79 x 100 in. (5,359 x 2,007 x 2,540 mm)

• Each cartridge pod contains 19 cartridgesand is 29.5 in. (749.3 mm) in length

• It takes approximately 15 min to change aset of cartridges

• Each cartridge weighs 1.5 lb (0.68 kg)

Pump Skids1. Pump skid for all units:

Engine type: Detroit 353/371-in.3 100hpPump manufacturer: Gorman-Rupp^UBB60-BPump size: 4 x 4 in. (101.6 x 101.6 mm)self-priming centrifugalOutput: 14.5 bbl/min at 75 psi (5.2 bar)Skid size (L x W x H): 10 ft 6 in. x 3 ft x 5 ft 5 in.

(3m 152.4 mm x 0.91 m x1.5 m 127 mm)

Weight: 6,000 lb (2,722 kg)

Miscellaneous Equipment and SafetyDE Bulk Tanks• Tank size (L x W x H): 48 in. x 60 ft x 90 in.

(1,219 mm x 18.3 m x2,286 mm)

• DE bulk tanks hold 1,500 lb (680 kg) ofDE Material

• DE bulk tanks weigh 850 lb (386 kg) empty

Operational Applications• DE averages 1 lb/ft2 (4.88 kg/m2)• Filtration cycles average 1 bbl/ft2 (1.71 kg/m2).

This also depends on solids content.

10·11

^Mark of Gorman-Rupp Company.

FILTRATION

Chemical Injection Pump• Type: Air• Size: 2 in. (50.8 mm)• Manufacturer: Versa-Matic^

(anti-freeze device)

Hose Basket• Size (L x W x H): 22 x 4 x 3 (6.7 x 1.2 x 0.9 m)• Weight: 4,500 lb (2,041 kg)• Feet of hoses: 120 ft of 4-in.

(36.6 m of 101.6-mm) suction hose and240 ft of 3-in. (73.2 m of 76.2-mm)discharge hose

• Other hoses: 40 ft of 2-in. (12.2 m of 50.8-mm) hose and300 ft of 1-in. (91.4 m of 25.4)-mm) hose

Waste Pump• Type: Air• Size: 3 in. (76.2 mm)• Manufacturer: Versa-Matic

(anti-freeze device)

Safety Considerations• Ladders are provided with our units• Yo-yo fall protection devices are included• Hand rails are provided with slurry skids

DE bulk tanks reduce risk of back injuries.

For safe working and operating conditions,M-I SWACO requires 3 ft (0.9 m) of clearancearound its equipment.

10·12

^Mark of Versa-Matic Pump Company.

Chapter 11SPEEDWELL TOOLS


11. SPEEDW

ELLTOOLS

SPEEDWELL TOOLS

To create synergy between chemicals and toolswhen cleaning a marine riser and wellboreM-I SWACO has integrated the SPEEDWELL

cleanup tool product line into its total wellborecleanup package. Following are descriptionsand specifications of the primary tools andsupport programs in the SPEEDWELL portfolio.

OPTISPEED* tool utilization program — AnExcel^ spreadsheet with four variables: (1) aver-age spread cost per day, (2) short-trip rate in feetor meters per hour, (3) tool cost and (4) toolmakeup and breakout time. If the operator isgoing to short trip the scraper brush tools in thewellbore, the OPTISPEED tool utilization programwill calculate not only the cost of each incremen-tal scraper brush tool in each casing section, butapproximate placement of the tools as well.

SPEEDDRAW* tool draw program — For gener-ating a well diagram that shows the recom-mended cleanup tools and the recommendedtool placement based on the output data fromthe OPTISPEED tool utilization program.

Short tripping tools — Used to pull out of thehole with the workstring far enough to brushand scrape the areas in the casing or linerbeyond the reach of the previous scraper brushtool. Afterwards, run back to the bottom ofthe hole to ensure the removal of any debrisadhered to the inside of the pipe.

Scraper — A tool that scrapes the inside of thecasing or liner(s) to remove cement sheath,scale and other debris.

11·1

^Mark of Microsoft Corporation.

SPEEDWELL TOOLS

Brush — A tool that brushes and disturbs mudsolids and other debris adhered to the inside ofthe casing or liner(s).

SPEEDWELL PUP* tool — A proprietary modularcasing cleaning tool that includes a tool jointat the top for ease of handling and safety. ThePUP tool can be assembled with four carriersfor brushes, scrapers or magnets.

SPEEDWELL SHORTY* tool — A cost-effective,proprietary modular casing cleaning tool. Asopposed to the four carriers of the PUP Tool,the SHORTY tool has two or three carriers.

Downhole debris filtration tool — A tooldesigned to filter debris and particulate fromthe fluid toward the bottom of the wellbore.

Boot Basket — Another term for a junk basketand is used to catch debris that is dislodgedfrom the wellbore, BOP stack and/or riser.

Jetting Tool — Used to dislodge debris by jet-ting or water blasting the inside of the BOPstack and/or riser.

Riser Brush — A specially designed tool tobrush the inside of marine risers.

Magnets — Used to remove ferrous debris fromthe wellbore.

Chemical cleaning — The use of chemicalsto clean the inside of casings, liners andmarine risers.

Mechanical cleaning — The use of cleanuptools to clean the inside of casings, liners andmarine risers.

Total riser/wellbore cleanup — Using chemicaland cleanup tools together with optimizedhydraulics to clean the inside of casings, liners

11·2

SPEEDWELL TOOLS

and marine risers. Properly combining chemicaland mechanical cleaning is the most effectiveand efficient type of cleanup, as it delivers anoptimum, total cleanup package.

The modular SPEEDWELL PUP SystemThe modular tool design eliminates the needfor a pup joint rental while providing brushand scraper carriers, as well as additional items,all on one tool.

One-piece mandrel is constructed of high-yieldsteel, is designed for drilling cement and has noexternal fasteners.

Larger-bore mandrels allow the fluid to do itswork, promoting better circulation and reversecirculation for solids removal.

One tool carries everything: scrapers, brushes,magnets, gauge rings and handling features inaddition to providing excellent annular bypassso solids can exit the cased hole.

Double-crimped, stainless steel

brushes stand up to harsh operat-ing conditions and do not rotate.They outperform carbon steel,straight-wire brushes that becomebrittle and break from chemicalexposure and movement. Wearvalues have been established toensure continuous brush contactthroughout the run.

11·3

SPEEDWELL TOOLS

Centralizers rotate independently

of the workstring to reduce wearon casing and liner. SPEEDWELL caneliminate the need for a gauge ringby placing a centralizer at drift onyour PUP tool.

Non-rotating magnets can be runon the same mandrel with scraperand brush carriers, eliminating theneed for additional tools on yournext project.

Junk basket carriers can be placedon the PUP mandrel, just likebrushes, scrapers and magnets.The baskets have an unrestricted,360° opening at the top.

Two styles of non-rotating

scraper blades: Knurled-face-stylefor aggressive cleaning andsmooth-face-style for specialrequests. Wear values have beenestablished to ensure continu-ous blade contact throughoutthe run.

SPEEDWELL modular tool design

allows you to run the tool with aregular box down to eliminate abit sub. We can also furnish bit ormill, already made up on the tool.

11·4

SPEEDWELL TOOLS

The SPEEDWELL PUP ToolThe modular, all-in-one cleanuptool designed specifically for yourapplication.

Tool Features

PUP tools can be delivered in avariety of combinations. The man-drel pin and sub box are designedwith a proprietary connection toreduce risk of mechanical failure.

Tool Benefits

• Custom helix-design scraperblades with aggressive, knurledsurfaces scrape up and down,making short trips more effective

• Double-crimped, stainless steelbrushes do not rotate and standup to harsh operating conditions.They outperform carbon steel,straight-wire brushes thatbecome brittle and break fromchemical exposure and pro-longed movement.

• Powerful, non-rotating magnetscan be run on the same mandrel with scraperand brush carriers, eliminating the need foradditional tools

• Junk basket carriers can also be mountedon the PUP mandrel, similar to the brushes,scrapers and magnets. These baskets have anunrestricted, 360° opening at the top for easydebris collection.

• Centralizers rotate independently of the work-string to reduce wear on casing and liner.SPEEDWELL can eliminate the need for a gauge

11·5

SPEEDWELL TOOLS

11·6

ring by placing a centralizer at drift on thePUP tool.

• The tool design incorporates an integral pupjoint to facilitate tool pickup with standarddrill pipe elevators and slips: no drill collar-type clamp required

• Non-rotating, self-cleaning, spiral brush andscraper arrangement allows unrestrictedannular flow for better solids/debris removal

• Interchangeable bottom sub eliminates theneed for crossovers and bit subs

• The large ID enhances reverse circulationfor faster cleanups

• The robust, non-rotating design allows thetool to be used while drilling cement

The SPEEDWELL THISTLE*Cementing Brush PlugAn alternative for wellbore clean-outs.• Cleans full strings of pro-

duction casing or tiebacksto the surface

• Spiral pattern of brushesprovides optimum brush-ing efficiency as plug ispumped down the casing

• Works with seawateror completion-fluiddisplacement

• Elastomer body is easily drilled by anytype of bit

• Combination brush/plug is loaded andlaunched from “double” plug containers

• Can be run with conventional bottom plug(s)• Available for several sizes of production casing

SPEEDWELL TOOLS

11·7

The SPEEDWELL SHORTY ToolThe versatile, all-in-one cleanup toolfor your wellbore when economy isparamount.

Tool Features

The SPEEDWELL modular designallows the completion engineer toconfigure a tool design for specificapplications or requirements.SHORTY tools can be configured ina variety of combinations.

Tool Benefits

• The modular design allows one tool to carryscrapers, brushes, magnets, junk baskets,centralizers and/or gauge rings

• Custom helix-design, bi-directional scraperblades with aggressive, knurled surfaces,scrapes up and down, making short tripsmore effective. Wear values have been estab-lished to ensure continuous contact through-out the run.

• Double-crimped, stainless steel brushes do notrotate and stand up to harsh operating condi-tions. They outperform carbon steel, straight-wire brushes that become brittle and breakfrom chemical exposure and movement. Wearvalues have been established to ensure contin-uous brush contact throughout the run.

• Powerful, non-rotating magnets can be runon the same mandrel with scraper and brushcarriers, eliminating the need for additionaltools and reducing risk

• Junk basket carriers can be mounted onthe mandrel, just like brushes, scrapers andmagnets. The baskets have an unrestricted

SPEEDWELL TOOLS

11·8

360° opening at the top for easy debriscollection.

• Centralizers rotate independently of theworkstring to reduce wear on casing and liner.SPEEDWELL can eliminate the need for a gaugering run by placing a centralizer at drift onthe tool.

• No external fasteners, no risk of having a com-ponent being dislodged into the wellbore

• Non-rotating, self-cleaning spiral brush andscraper arrangement allows unrestrictedannular flow for better solids/debris removal

• Interchangeable bottom sub eliminates theneed for crossover and bit subs, eliminatingthe risk of having a component being dis-lodged into the wellbore

• The large ID enhances reverse circulation forfaster cleanups


SPEEDWELL TOOLS

The SPEEDWELL Liner

Top Test Packer (LTTP)Performs a positive or negative test on the liner.

Tool Features

The SPEEDWELL Liner Top Test Packer(LTTP) is designed to perform a neg-ative test on the liner top to ensureliner top integrity before changingfluids. The LTTP is designed to pre-vent premature setting while run-ning in the hole and also allows afull complement of wellbore cleanuptools to be run above and below. Running thetool while drilling the Plug Back Total Depth(PBTD) and testing the liner top reduces triptime and operating cost.

Tool Use

Choose the desired set-down weight by alteringthe number of shear pins used in the tool. TheLiner Top Test Packer provides a generousbypass area to permit acceptable trip times.SPEEDWELL recommends the use of a SHORTY

Scraper-Magnet tool just below the LTTP toensure a clean sealing area. A go/no-go gaugering can be provided to dress off the liner top.Once the test area is clean, set down on theLTTP and shear the pins, closing the bypassarea and sealing off the packer. After the test,a simple straight pickup is required to unseatthe packer and re-open the bypass area.

Tool Benefits

• Large internal bypass area permits faster tripspeeds and eliminates swabbing caused byelement expansion

11·9

SPEEDWELL TOOLS

11·10

• LTTP is an integral component of one-tripdisplacement system

• Easy handling around the rig floor• Easy activation is achieved by set-down weight• Easy deactivation is achieved by straight pickup• Tool design will allow reverse circulation• Robust design allows tool to be used while

drilling cement

The SPEEDWELL Multi-Action

Circulating Valve (MACV)For bypassing fluid and increasing annular velocity.

Tool Features

The SPEEDWELL Multi-ActionCirculating Valve (MACV) allowscommunication of fluid fromthe workstring to the casing annu-lus when increased AVs are neces-sary to enhance wellbore cleaning.The upper string can be rotatedwhile the lower string remainsstationary. The operator can main-tain more efficient AVs by diverting flowabove the tool.

Tool Use

Choose the desired shear pin rating. Install theMACV to allow circulation above the liner topor mud motor. Set down on the liner hanger toshear the pins, and pick up to open the circulat-ing valve. No torque will be transmitted belowthe valve.

SPEEDWELL TOOLS

Tool Benefits

• No trip speed limitation• Large bypass area increases displacement

efficiency• Shear weight – variable setting • Unlimited cycles• Rotation isolation • Circulation bypass valve above mud motor• Increase annular velocity in casing • Robust design allows tool to be used while

drilling cement

The SPEEDWELL PUP

Finger BasketCost-effective, easy-to-use, mechanicalwellbore debris-removal tool.

Tool Features

The SPEEDWELL Finger Basket isdesigned to withstand pipe rotationand reciprocation without hamperingoperations. The PUP Finger Basket’sdesign traps the larger debris gener-ated when drilling/milling varioustypes of plugs and other downholeequipment. The debris is captured bytwo events: activation of the fingerswhile pulling out of the hole, and dur-ing conventional circulating up theannulus. The generous basket annulusdoes not impede the fluid’s ability toremove debris from the well.

11·11

SPEEDWELL TOOLS

Tool Use

Install the SPEEDWELL PUP

Finger Basket in the work-string to capture and removelarge debris generated duringdrilling of plugs and retain-ers, jetting operations, chemi-cal displacements andcleanups. The PUP FingerBasket complements theSPEEDWELL PUP Scraper/Brush/Magnet tool, theSPEEDWELL PUP Quick-TripJetting Tool and theSPEEDWELL PUP Riser Brush.

Tool Benefits

• The tool’s design incorpo-rates an integral pup jointto facilitate tool pickup withstandard drill pipe elevatorsand slips: no drill collar-typeclamp required

• Large entry and capacityallow for effectivedebris collection

• Allows solids to becirculated out of thewellbore

• When pulling out of thehole, the tool captures largerproblematic debris that could not be circulatedout of the hole

• The large ID enhances reverse circulation,complementing faster cleanup


11·12

SPEEDWELL TOOLS

11·13

The SPEEDWELL Quick-Trip

Jetting ToolRemoves debris from the BOP, casing and wellhead.

Tool Features

The SPEEDWELL Quick-Trip JettingTool is a mechanical device thatenhances the cleaning efficiencyof the other cleanup tool assembliesby providing jetting action in theBOP stack, marine riser and/or thecasing/wellhead area. Versatiledesign complements any drillingor completion operation.

Tool Use

Place the SPEEDWELL Quick-TripJetting Tool in areas where debris is not easilyaccessible to scrapers, brushes or magnets, andwhere no metal-to-metal contact is desirable.The Quick-Trip Jetting Tool should be used inconjunction with the SPEEDWELL Quick-TripBoot Basket or the SPEEDWELL Finger Basketto assist in the removal of contaminants bypreventing debris from re-entering theclean wellbore.

The SPEEDWELL PUP Riser Brush complementsthe jetting tool by allowing the fluid and debristo circulate freely through the tool and out ofthe marine riser.

SPEEDWELL TOOLS

Tool Benefits

• The tool design incorpo-rates an integral pup jointto facilitate tool pickupwith standard drill pipeelevators and slips: no drillcollar-type clamp required

• Simple design makes the tool easy and safeto handle for the rig crew

• Spiral jet design ensures maximum effectivecoverage

• Available in 7- through 14-in. (177.8- through355.6-mm) OD to maximize jetting velocities

• No darts or balls required to activate ordeactivate the tool


11·14

SPEEDWELL TOOLS

11·15

The SPEEDWELL PUP

Riser BrushThe robust design keepsyour completion free ofsolids and debris.

Tool Features

The SPEEDWELL PUP RiserBrush utilizes threestainless steel non-rotating brush rings toremove debris from themarine riser or innerproduction riser ID.The design of the toolprovides a flow paththrough the brush-ring carrier, with themajority of the flowpassing through 62 in.2

(40,000 mm2) of flowarea in the brush carrier,minimizing pressure drops above andbelow the tool.

Tool Use

The SPEEDWELL PUP Riser Brush can be run as astand-alone tool, and it is typically run in con-junction with the SPEEDWELL PUP Quick-TripBoot Basket or SPEEDWELL PUP Finger Basketto protect the well from debris re-enteringthe well while jetting the BOP. The large flow-through area of the tool provides several advan-tages. It will not impede the fluid’s ability to liftdebris out of the well while jetting the subseastack BOP, it will reduce the effects of surge orswab while tripping, and it eliminates the need

SPEEDWELL TOOLS

for a junk basket above the tool. The workstringcan be rotated and reciprocated with theSPEEDWELL PUP Riser Brush in the string. Thenon-rotating brush carriers reduce the risk ofdamaging the riser.

Tool Benefits

• Easier, safer handling with the integral pupjoint to facilitate tool pickup with standarddrill pipe elevators and slips: no drill collar-type clamp required

• Aggressive, non-rotating stainless steelbrushes (synthetic brushes available)

• Debris can be effectively circulated throughand around the housing

• The large mandrel ID enhances reversecirculation

• Available in 133⁄8- through 24-in. (339.7-through 609.6-mm) OD

• Large flow-through area reduces the prob-ability of fluid compression while trippingin the hole or pulling out of the hole


11·16

Chapter 12INTERVENTION FLUID SYSTEMS


12. INTERVENTIONFLUID

SYSTEMS

INTERVENTION FLUID SYSTEMS

12·1

FLODENSE APDescriptionOwing to its submicron-sized particles, theunique WARP* FLODENSE* AP system allows forflow through the annulus with minimum dis-persion and exhibits reduced sag and settle-ment. FLODENSE AP particles have a settling rate10,000 times less than barite. The fluid can beformulated for different applications with aver-age densities between 17.5 lb/gal (2.1 SG) up to20.5 lb/gal (2.46 SG).

FLODENSE AP also can be used as a viscous,lubricious and solids-free fluid that is engi-neered to fall through the annulus withminimal dispersion.

ApplicationsFLODENSE AP fluids are ideal for operationsrequiring a fluid to pass through very narrowapertures with minimum dispersion and arebeneficial in combating uncontrolled releaseof pressure from a sealed casing string.

Features• Engineered with either micron-sized particles

or solids-free• Fluid passes in snakelike fashion through

very narrow apertures• Can be formulated with densities up to

20.5 lb/gal (2.46 SG) • Can be used as a viscous, lubricious and

solids-free fluid system• Flexible system

Benefits• Reduces or controls annular pressures• Provides hydrostatic control


12·2

• Produces minimum dispersion when fallingthrough the annulus

• Can be used in very narrow apertures whenengineered with micron-sized particles

• Reduces sag and settlement compared tocompeting systems

• Addresses the critical safety, environmentaland economic consequences of SustainedCasing Pressure (SCP)

FLOPRO CTDescriptionFLOPRO CT is a specialized intervention-fluidsystem featuring hydraulically optimized rheol-ogy, lubrication and density. With its relativelyflexible formulation FLOPRO CT can be built witha wide variety of base fluids, including fresh-water, seawater, potassium chloride, sodiumchloride, calcium chloride, sodium bromide,sodium formate, potassium formate andcesium formate. FLO-VIS L, a premium-gradeclarified xanthan gum, is responsible for theelevated Low-Shear-Rate-Viscosity (LSRV) of thesystem. This high-yielding biopolymer is also dis-persible and imparts the LSRV without adverselyaffecting the overall gross viscosity of the system.

ApplicationsFLOPRO CT is ideal for a wide range of coiled-tubing applications, including deeper wellswith higher angles and working in corkscrewedtubing. The solids-free FLOPRO CT system is idealfor removing debris from the wellbore andclearing the way for the insertion of productiontools. With FLOPRO CT, the hole typically can becleaned thoroughly in one trip.


Features• Shear thinning rheological profile

with high LSRV • Low coefficient of friction • Zero or minimal solids• Inhibitive fluid • Provides drag reduction • Wide density range

Benefits• Reduces mechanical friction and coil wear• Promotes hole cleaning and solids suspension • Minimizes pressure loss and coil wear • Minimal reservoir damage • Enables entering higher-angle deeper wells

not previously attainable • Simplified cleanup

SAFETHERM

DescriptionThe SAFETHERM* insulating packer fluid iscustom-designed and blended for a wide rangeof cold-temperature production applications. Anaqueous, water-miscible, or oil-soluble fluid isdesigned to minimize the conduction of heataway from the production string, while sup-pressing convective heat loss in the annulus. Thisuniquely engineered packer fluid dramaticallyreduces the risks associated with the formationof hydrates, paraffin, asphaltene and the myriadof other problems that can jeopardize productionin these environments. The fluids are formulatedfrom an inherently low-thermal-conductivitybase fluid and contain no suspended solids.SAFETHERM fluids can be formulated for densities

12·3


ranging from 8.33 to 12.5 lb/gal (1 to 1.5 SG) andis inhibitive to corrosion.

SAFETHERM is hydraulically optimized toyield low plastic viscosity with elevated LSRVand yield stress. Its flat rheological profile iswhat enables it to remain thermally stablefrom 125° to 175° F (52° to 79° C) over extendedperiods and is inhibitive to corrosion. Thishydraulically efficient fluid can be mixed andpumped on the rig, eliminating the expenseassociated with an adjoining pumping boat.It can be pumped at high rates through smalltubing and orifice valves. In addition, thecomponents of SAFETHERM were particularlyselected to have minimal environmentalimpact, thereby mitigating the effects of spillsor other unforeseen events.

The proprietary TPRO ST* computer modelcomplements SAFETHERM and the M-I SWACOin-house thermal conductivity testing appa-ratus. The unique computer model is capableof simulating Newtonian and non-Newtonianfluid behavior in an annulus to calculate temper-ature regression during production and shut-in.

ApplicationsSAFETHERM is specially engineered for deep-water, permafrost and other cold-temperatureenvironments. As an insulating annular fluid,SAFETHERM is compatible with a wide rangeof fluids, elastomers and other components.

Features• Minimizes heat conduction, convective

heat loss • Easily mixed and pumped on the rig• Environmentally acceptable components

12·4


• Utilizes proprietary heat-transfercomputer model

• Thermally stable• pH buffered and corrosion inhibitive

Benefits• Prevents production-line blockage,

casing-string collapse• Compatible with wide range of elastomers

and fluids • Production compatible with available surface

processing equipment• Calculates heat regression during production

and shut-in• Helps maximize production• Reduces costs

12·5

Chapter 13RESERVOIR DRILL-IN FLUIDS


13. RESERVOIRD

RILL-INFLUIDS

RESERVOIR DRILL-IN FLUIDS

13·1

The decision on how to drill the reservoir is criti-cal to the success of the completion. In fact, thetype of Reservoir Drill-In Fluid (RDF) chosen candrive the entire completion decision process.M-I SWACO offers five primary RDF systems:DIPRO*, FLOPRO* NT, FAZEPRO*, VERSAPRO*, andNOVAPRO*. To aid in the selection of a system fora particular application, M-I SWACO employsthe proprietary RDFx* computer software. Asample screen display is shown below.


M-I SWACO RDF SYSTEMSDIPRO

DIPRO is a high-density water-base ReservoirDrill-In Fluid (RDF) system, designed for usein divalent brines. DIPRO utilizes a synergisticinteraction of components to produce excellentsuspension characteristics while maintainingextremely low, high-shear-rate viscosities.Optimized bridging particle selection andbiopolymer-free formulations provide a remov-able, ultra-low permeability filter cake. An idealcandidate for production-zone drilling inhighly deviated and horizontal wells, DIPRO

typically is easy to mix at the rigsite or mudplant without specialized shearing equipment.A temperature of 105° F (41° C) is the minimumtemperature required starting a mix. DIPRO

can be used in high-density divalent brines, i.e.,CaBr2, CaCl2, ZnBr2/CaBr2, MgCl2, MgBr2, andwhere bottomhole pressures require 11.5 to17.5 lb/gal (1.38 to 2.1 SG) densities.

Features

• Stable rheologies • Formulated from multi-functional

synergistic components • Can be formulated from more economic

mixed-salt base brines• Consistently low fluid loss• No pre-hydration of polymer required• Extremely low, high-shear-rate viscosities

Benefits

• Non-damaging reservoir drill-in fluidcapability in >13.5 lb/gal (1.62 SG) range

• Excellent drilling properties • Minimized formation damage potential

13·2


• Reduced Equivalent Circulating Densities (ECD)• Designed for maximum compatibility with

completion method• Enhanced filter-cake removal• Precisely controlled particle size

13·3

Product Concentration

Divalent base brine ~ 0.96 bbl

DI-TROL* 6.0 – 10.0 lb/bbl

DI-BALANCE* 0.50 – 2.0 lb/bbl

SAFE-CARB* 2 3.0 lb/bbl

SAFE-CARB* 10, 20, 40 and/or 250 22.0 – 35.0 lb/bbl

Typical Formulation


13·4

Pro

du

ctF

un

ctio

ns

De

scri

pti

on

CaC

l 2, C

aBr 2

, CaC

l 2/C

aBr 2

CaB

r 2/Z

nB

r 2C

aCl 2

/CaB

r 2/Z

nB

r 2D

ensi

ty a

nd

sh

ale

inh

ibit

ion

Bas

e br

ine

DI-

TRO

LFl

uid

-los

s co

ntr

ol, v

isco

sity

Star

ch d

eriv

ativ

e

DI-

BALA

NC

Ep

H c

ontr

ol, v

isco

sity

Inor

gan

ic c

omp

oun

d

SAFE

-CA

RB

2, 1

0, 2

0, 4

0 an

d/o

r 25

0Po

re-t

hro

at b

rid

gin

gO

pti

mal

ly s

ized

cal

ciu

m c

arbo

nat

e

DI-

BO

OST

* (o

pti

onal

)V

isco

sity

sta

bili

zati

onG

lyco

l ble

nd

Pro

du

ct F

un

ctio

ns

an

d D

esc

rip

tio

ns


DI-TROL and DI-BALANCE components worktogether to build Low-Shear-Rate Viscosity (LSRV)without producing high ECDs.

DI-TROL is a unique dual-function viscosifierand filtrate reducer for the DIPRO system. It isa specially processed, high-molecular-weight,branched-chain starch derivate, that generateselevated LSRV and functions as a fluid-loss-control agent in divalent salt brines. It worksin conjunction with calcium carbonate to formthe basis of the filter cake.

DI-BALANCE is a fine-particle-size, highlyreactive inorganic magnesium compound thatinteracts in a synergistic manner with DI-TROL

to enhance the LSRV.DI-BOOST additive is water-miscible glycol

ether that enhances the initial rheologicalproperties of the DI-PRO system.

13·5

Fluid density, lb/gal 11.6 – 17

Plastic viscosity, cP 15 – 35

Yield point, lb/100 ft2 15 – 35

3 rpm 2 – 7

LSRV 0.0636 sec–1, cps 10,000 – 40,000

HTHP, mL/60 min @ 150° F (66° C) <5

Typical DIPRO Properties


FAZEPRO

FAZEPRO* is unique, in that it is the industry’sonly invert-emulsion fluid that can be convertedfrom an oil-wet state to a water-wet statethrough a simple reduction in pH. By simplyadjusting the pH of either the breaker solutionor the completion brine, the wettability of thefilter cake is transformed from an oil-wet stateto water wet. FAZEPRO can use any type of baseoil (diesel, mineral oil and synthetic) normallyused in invert-emulsion RDF systems.

Features

• Oil-base mud drilling performance• Cleans up like water-base mud• Versatility in selection of base fluid

Benefits

• Exhibits invert-emulsion fluids drillingperformance

• Can be built using diesel, mineral oil orsynthetic-base fluid

• Easily converted from an oil-continuous phase(oil-wet) to a water-continuous phase (water-wet) by using acid to reduce the pH to below 7

• Deposited filter cake can be removed usingtypical oilfield acids, i.e., citric, acetic, HCl, etc.

• Compatible with gravel-packing operationswhere a breaker can be placed in the gravel-pack carrier fluid

FAZEPRO is a reversible, invert-emulsion sys-tem. The residual filter cake is reversed from anoil-wet state to a water-wet state by creating alow-pH (<6) environment in the wellbore. Thiscan be done with acids or chelants. In addition,the internal phase can be made with differentbrines to provide the required density withminimal solids.

13·6


13·7


Base fluid (diesel synthetic, mineral oil, olefin, paraffin) 0.517 bbl

CaCl2, CaBr2, NaCl, NaBr 0.368 bbl

VG-69*, VG-PLUS* 1.0 – 5.0 lb/bbl

FAZE-MUL* 8.0 – 12.0 lb/bbl

FAZE-WET* 1.0 – 4.0 lb/bbl

Lime 5.0 – 9.0 lb/bbl

ECOTROL* for high HT applications 0.5 – 1.5 lb/bbl

SAFE-CARB 2, 10, 20, 40 and/or 250 60.0 lb/bbl

Typical Formulation

Product Functions

Base fluid (synthetic, Provides continuous phase mineral oil, olefin, paraffin) for system

CaCl2, CaBr2, NaCl, NaBr Internal phase inhibition

VG-69, VG-PLUS Viscosity

FAZE-MUL Primary emulsifier

FAZE-WET Wetting agent/HTHPfluid-loss-control agent

Lime Alkalinity

ECOTROL Fluid-loss control for temperature >250° F (125° C)

SAFE-CARB 2, 10, 20, 40 Acid-soluble and/or 250 bridging material

Product Functions


FAZE-MUL is the primary emulsifier and wet-ting agent for the FAZEPRO system. It has theunique ability to reverse to an oil/syntheticin-water emulsion. For the best possible com-pletion cleanup lower the pH to below 6.0.

FAZE-WET surfactant is the secondary wet-ting agent and it increases the preferential wet-ting of solids by the continuous, non-aqueousphase. It also provides stable HTHP filtration-control characteristics and increases the fluid’sresistance to contamination.

13·8

Fluid density, lb/gal 9.0 – 12.0


Yield point, lb/100 ft 220 – 25

3 rpm 5 – 7

Pom – Alkalinity of whole mud (mL) <3.0

Electrical stability (volts) 500 – 800

HTHP, mL/30 min @ 200° F (95° C) <5.0

Oil/brine ratio 80/20 – 60/40

Typical FAZEPRO Properties


FLOPRO NTFLOPRO* NT is used primarily for open-hole com-pletions including sand control and non-sandcontrol requirements. The main focus is to min-imize formation damage, completion compati-bility and cleanup. FLOPRO NT is purpose-builtfor each specific application.

Features

• Non-damaging• Low lift-off• High return permeability• Ultra-Low permeability filter cake• Customized formulations• Precisely controlled particle-size distribution

of bridging agent• Extremely low coefficient of friction • Promotes low skin values• Rheologically engineered• High LSRV• Environmentally acceptable

Benefits

• Maximizes production• Reduces remediation costs• Higher production rates sooner• Minimal lift-off required, faster cleanup• Minimizes solids and fluid invasion of the

producing formation • Reduces pump pressures• Maximizes ROP, saves drilling time• Excellent hole-cleaning profile• Reduces cleanup and disposal costs• Works with any completion assembly

13·9


FLOPRO NT is the premier M-I SWACO water-base Reservoir Drill-In Fluid (RDF) system. Itis a comprehensive system that begins todemonstrate its benefits while drilling theproductive interval. These benefits continuethroughout the process of putting the wellon production.

The system is used primarily for open-holecompletions including sand control and non-sand control requirements. The main focus isto minimize formation damage, completioncompatibility, maximum drillability andcleanup. The differences between this systemand other water-base RDF systems include:product positioning, the utilization of “NewTechnologies” and component flexibility.FLOPRO NT is purpose-built for each specificdrilling and completion application.

13·10


Base fluid (brine) — halide or formates 0.96 bbl

FLO-VIS* PLUS, FLO-VIS NT 0.75 – 2.0 lb/bbl

DUAL-FLO*, FLO-TROL* 4.0 – 8.0 lb/bbl

Greencide 25G 0.5 – 1.0 gal/100 bbl

Caustic Soda, MgO, KOH 0.5 – 1.0 lb/bbl

SAFE-CARB 2, 10, 20, 40 and/or 250 25.0 – 30.0 lb/bbl

KLA-GARD*, KLA-STOP* 4.0 – 8.0 lb/bbl

Typical Formulation


13·11

Pro

du

ctF

un

ctio

ns

De

scri

pti

on

Bas

e fl

uid

(bri

ne)

Den

sity

an

d s

hal

e in

hib

itio

n

Bas

e br

ine

FLO

-VIS

PLU

S, F

LO-V

ISN

TV

isco

sity

pro

per

ties

, esp

ecia

lly L

SRV

Prem

ium

gra

de

xan

than

gu

m

DU

AL-

FLO

, FLO

-TR

OL

Flu

id-l

oss

con

trol

Mod

ifie

d s

tarc

h

Gre

enci

de

25G

Bac

teri

cid

eG

luta

rald

ehyd

e

Cau

stic

Sod

a, M

gO, K

OH

pH

Alk

alin

ity

SAFE

-CA

RB

2, 1

0, 2

0, 4

0 an

d/o

r 25

0B

rid

gin

g ag

ent,

flu

id-l

oss

Op

tim

ally

siz

ed c

alci

um

car

bon

ate

con

trol

, den

sity

KLA

-GA

RD

, KLA

-STO

PSh

ale

inh

ibit

orA

min

e ty

pe

of s

hal

e in

hib

itor

s

Pro

du

ct F

un

ctio

ns

an

d D

esc

rip

tio

ns


FLO-VIS PLUS is a high yield, premium-grade,clarified xanthan gum. It is both clarified anddispersible. It produces elevated LSRV and fragilegel strengths.

FLO-VIS NT is a high-yielding, xanthan gumbiopolymer. It is non-clarified and non dis-persible. It imparts elevated LSRV while not hav-ing an adverse effect on the overall apparentviscosity.

DUAL-FLO and FLO-TROL are both specialstarch derivates used primarily for filtrationcontrol. They are both non-ionic and act syner-gistically with FLO-VIS PLUS and FLO-VIS NT toenhance the LSRV.

KLA-GARD or KLA-STOP reduces the swellingof sensitive shale.

13·12




3 rpm 10 – 15

pH 8.5 – 10.0

LSRV 0.0636 sec–1, cps 40,000 – 60,000

HTHP, mL/30 min @ 150° F (66° C) <5.0

Typical FLOPRO NT Properties


VERSAPRO, NOVAPRO and PARAPRO

NOVAPRO (synthetic), VERSAPRO (diesel or mineraloil) and PARAPRO (paraffin) Reservoir Drill-InFluid (RDF) systems are non-damaging, invert-emulsion fluids used for drilling developmen-tal wells designed for both cased and openhole completions. These RDFs are designedto minimize formation damage problemssuch as oil wetting, emulsion blocking, andsolids plugging, yet retain OBM/SBM advan-tages — such as rate of penetration, lubricityand wellbore stability.

Due to the higher priority of minimizing for-mation damage and compatibility with com-pletion assemblies, these fluids are differentfrom typical invert-emulsion fluids in theirdesign and application. The emulsifier/wettingagent package, the type and size of bridgingmaterial — indeed, all materials required forthe job — are reviewed for the best combina-tion of drilling and completion characteristics.The NOVAPRO/VERSAPRO/PARAPRO family of flu-ids is versatile, providing tremendous flexibilityfor numerous applications.

VERSAPRO

The invert-emulsion-base VERSAPRO* reservoirdrill-in fluid system features low fluid loss,high ROP and excellent wellbore stability. TheVERSAPRO system is designed to minimize for-mation damage by forming a thin, durable,Ultra-Low-permeability filter cake on the face ofthe formation, thereby minimizing fluid andsolids invasion into the formation. Products arecarefully selected for compatibility with thereservoir and completion method to maximize

13·13


productivity. VERSAPRO can be used with eitherdiesel, or mineral oil as a base fluid.

Features

• Can be built using diesel, or mineral oil-base fluid

• Exhibits all the drilling advantages ofconventional invert-emulsion fluids

• Designed to be compatible with completionmethod

Benefits

• Minimizes formation damage• Reduces fluid and solids invasion• Maximizes productivity

13·14

Component Concentration

Base oil 50 – 70% vol

Brine internal phase 30 – 50% vol

VG-PLUS 0.5 – 2.0 lb/bbl

VERSAPRO P/S, VERSACOAT*, VERSAWET* 4.0 – 6.0 lb/bbl

ECOTROL 1.0 – 2.5 lb/bbl



Typical Formulation


VERSAPRO systems are non-damaging,invert-emulsion fluids with (diesel or mineraloil as base). These systems are designed tominimize formation damage.

VERSAPRO LS provides all the benefits of aVERSAPRO system. It utilizes calcium carbonatefor bridging and weighting. It contains at least30 lb/bbl (13.6 kg/bbl) for optimum bridging.

VERSAPRO SF is a pill designed without solidsto displace VERSAPRO from the hole when thereis pre-existing filter cake only. Do not useVERSAPRO SF to drill the formation.

13·15

Product Function

Base oil Continuous

Brine Internal phase

VG-PLUS Viscosifier

VERSAPRO P/S, VERSACOAT, Primary emulsifierVERSAWET

ECOTROL Supplemental fluid-loss control

Lime Alkalinity

SAFE-CARB 2,10,20,40, Acid-solubleand/or 250 bridging material

Product Functions




3 rpm 5 – 15


Electrical stability (volts) >300

HTHP, mL/30 min @ 250° F(121° C) – 5 micron disk <5.0

Typical VERSAPRO Properties


NOVAPRO

The synthetic-base NOVAPRO* system featureslow fluid loss, high ROP and excellent wellborestability. The NOVAPRO system is designed tominimize formation damage by forming a thin,durable, Ultra-Low-permeability filter cake onthe face of the formation, thereby minimizingfluid and solids invasion into the formation.Products are carefully selected for compati-bility with reservoir, drilling conditions, envi-ronmental protocol, and completion methodto maximize productivity while adhering toenvironmental requirements.

The system meets environmental require-ments for synthetic based fluids.

Features

• Formulated with synthetic-base fluid• Exhibits all the drilling advantages of

conventional invert-emulsion fluids• Designed to be compatible with the

completion method

Benefits

• Minimizes formation damage • Reduces fluid loss• Maximizes production• Environmentally acceptable

13·16


13·17

Base synthetic 70 – 90%

Brine internal phase 10 – 30%

VG-PLUS 1.0 – 4.0 lb/bbl

NOVAMUL*, SUREMUL* 6.0 – 8.0 lb/bbl

NOVAWET*, SUREWET* 2.0 – 4.0 lb/bbl



Typical Formulation

Product Function

Base synthetic Provides continuous phase for system

Brine Internal phase inhibition

VG-PLUS Viscosity

NOVAMUL, SUREMUL Primary emulsifier

NOVAWET, SUREWET Wetting agent

Lime Alkalinity

SAFE-CARB 2, 10, 20, 40 Acid-soluble and/or 250 bridging material

Product Functions

Product Function




3 rpm 5 – 15


Electrical stability (volts) >500

HTHP, mL/30 min @ 250° F(121° C) – 5 micron disk <5.0

Typical NOVAPRO Properties


FLOTHRU

The FLOTHRU* system is a premium water-baseReservoir Drill-In Fluid (RDF) designed to be non-damaging with enhanced flow-back capabilitiesavoiding the need for a chemical cleanuptreatment. FLOTHRU utilizes organophilic com-ponents as part of its design. The systemdeposits an impermeable filter cake on the sandface preventing the flow of aqueous fluid andsolids into the formation. When the well is puton production, this organophilic material allowsoil to flow through channels in the filter cakeeliminating the need for any external breakers.

13·18


Base fluid (brine) — halide or Formates 0.96 bbl

FLO-VIS PLUS, FLO-VIS NT 0.75 – 1.0 lb/bbl

THRUTROL* 10 lb/bbl

THRUCARB* 20 to 30% of the total carbonate blend

Greencide 25G 0.5 – 1.0 gal/100 bbl

Caustic Soda, MgO, KOH 0.5 – 1.0 lb/bbl


KLA-GARD, KLA-STOP 4.0 – 8.0 lb/bbl

Typical Formulation


13·19

Pro

du

ctF

un

ctio

ns

De

scri

pti

on

Bas

e fl

uid

(bri

ne)

Den

sity

an

d s

hal

e in

hib

itio

nB

ase

brin

e

FLO

-VIS

PLU

S, F

LO-V

ISN

TV

isco

sity

pro

per

ties

, esp

ecia

lly L

SRV

Prem

ium

-gra

de

xan

than

gu

m

THR

UTR

OL

Flu

id-l

oss

con

trol

an

d

Org

anop

hil

ic s

tarc

hsu

pp

lem

enta

l vis

cosi

fier

THR

UC

AR

BB

rid

gin

g ag

ent/

flu

id-l

oss

con

trol

Org

anop

hil

ic c

alci

um

car

bon

ate

Gre

enci

de

25G

Bac

teri

cid

eG

luta

rald

ehyd

e

Cau

stic

Sod

a, M

gO, K

OH

pH

Alk

alin

ity

SAFE

-CA

RB

2, 1

0, 2

0, 4

0 an

d/o

r 25

0B

rid

gin

g ag

ent,

flu

id-

Op

tim

ally

siz

ed c

alci

um

car

bon

ate

loss

con

trol

, den

sity

KLA

-GA

RD

, KLA

-STO

PSh

ale

inh

ibit

orA

min

e ty

pe

of s

hal

e in

hib

itor

s

Pro

du

ct F

un

ctio

ns

an

d D

esc

rip

tio

ns


FLO-VIS PLUS is a high-yield, premium-grade,clarified xanthan gum. It is both clarified anddispersible. It produces elevated LSRV and fragilegel strengths.

FLOVIS NT is a high-yielding, xanthan gumbiopolymer. It is non-clarified and non dis-persible. It imparts elevated LSRV while not hav-ing an adverse effect on the overall apparentviscosity.

THRUTROL is a hydrophobic-modified starch.It is used to lower fluid-loss control and impartviscosity. It provides some of the channels forhydrocarbons to flow through.

THRUCARB is a very fine organophilic-coatedcalcium carbonate. It is used in conjunction withother sized calcium carbonate and the THRUTROL

starch to form the basis of a filter cake. It alsohelps create the organophilic channels.

KLA-GARD or KLA-STOP reduces the swellingof sensitive shale.

13·20




3 rpm 10 – 15

pH 8.5 – 10.0

LSRV 0.0636 sec–1, cps 40,000 – 60,000HTHP, mL/30 min @ 150° F (66° C) <5.0

Typical FLOTHRU Properties


13·21

Breakers – Chemical cleanupWhy a Breaker?Most of the M-I SWACO Reservoir Drill-In Fluids(RDFs) are designed to deposit an impermeablefilter cake on the formation with the intent ofpreventing the loss of fluid and solids into theproducing or injection zone. While these filtercakes provide a protective barrier on the forma-tion face in the drilling phase of the well, theycan also impair the productivity of a well or theinjection into a well if they are not cleaned upproperly.

In producing wells that are completedin unconsolidated formations, gravel packs,expandable screens, pre-packed liners andstand-alone screens are used to stabilize thewellbore. Although these completion tech-niques might stabilize the wellbore they can,at the same time, serve as potential traps forthe filter cake/filter-cake debris when thewell is put on production. The net result canbe lost production and/or premature declineof the well.

The purpose of using a breaker is to preventthe plugging of a gravel pack or a completionassembly with filter cake/filter-cake debris bycleaning up or changing the characteristics ofthe filter cake itself. Filter-cake cleanup allowshydrocarbons from the reservoir to flow freelyinto the well without being blocked by thefilter-cake residue.

The maintenance of the RDF while drillingthe well plays an important role in the cleanupprocess of the filter cake. If the percent of drillsolids in the RDF is allowed to escalate then


consequently the amount of drill solids in thefilter cake will also accumulate. A large amountof drill solids will not only affect the integrityof the filter cake, it will also limit the amountof the filter cake that can be cleaned up.

One of the most important objectives of acleanup treatment is the uniform degradationof the filter cake. This objective should be one ofthe basis of design when selecting a breakertreatment.

Factors that affect Breaker Selection• Breaker carrier • Well type – Producer or injector• Type of completion – Gravel pack, expandable

screen, etc.• Metallurgy• Formation characteristics — Sensitivities• Environmental issues• Type of RDF used to drill the well• RDF components• % drill solids in the filter cake• MBT concentration• Amount of bridging material • Total amount of solids• Thickness of the filter cake• Type of cleanup desired• Contact area • Contact time• BHT• Delay time required• Completion equipment• Operator concerns

13·22


13·23

What to Use, When to Use It

and How Do You Get It There?What to use and when to use it depends onthe factors affecting the breaker selectionincluding the type of cleanup desired andwhen the cleanup is going to take place. Forexample, in a gravel-pack completion there aretwo options when to do the cleanup, during thegravel-pack operation or post-gravel pack. Thereis also the option of placing a breaker as a com-ponent in the filter cake, or using a system thatdeposits a filter cake that can be cleaned up byformation hydrocarbons.

OptionsPost Treatment

• Aggressive treatmentsStrong acidsOxidizers

• Non-aggressive treatmentsWeak acidsBREAKDOWN*FAZEBREAK*BREAKFREE*

Treatments While Completing the Well

• Aggressive treatmentsChelants

• Non-aggressive treatmentsFAZEBREAK — Delayed

Chemical Options• Acids – Temperature ranges 120° to 250° F

(49° to 121° C). Attack biopolymers and cal-cium carbonate components of a water-basefilter cake. Acids can also be used to cleanup FAZEPRO, a reversible invert-emulsion fluid.


Some of the disadvantages of acid are thatthey can cause corrosion with downhole tubu-lars, form precipitates, cause emulsions andcause incomplete cleanup. • Oxidizers – Temperature ranges 80° to 200° F

(27° to 93° C). They attack the organic polymerportion of the filter cake deposited by water-base fluids. Generally, oxidizers may worktwo times faster for every 10° F (–12° C) risein temperature.

Disadvantages of oxidizers include theattack on steel material, the dissolution of sili-cates or micro-porous chert, and the reactionwith clays which can generate an emulsion.

M-I SWACO Products• SAFE-BREAK* L – Oxidizer• Sodium Hypochlorite – Oxidizer

SAFE-BREAK L and SAFE-BREAK S are strongoxidizers used in water-base drill-in fluids asbreakers for various polymers. They are used to“break” the viscosity of natural polymer-basefluids and to loosen the filter cakes of drill-influids, so that bridging particles can be pro-duced back through sand-control liners or bemore effectively acidized.• Enzymes — Temperature ranges 40° to 200° F

(4° to 94° C). Enzymes primarily starch or poly-mer specific. These enzymes break down thepolymers in the residual filter cake which ineffect breaks down the “cement” which bondsthe filter cake together allowing the bridgingsolids to disperse and either flow back throughthe completion assembly (gravel pack), orbe chemically dissolved by other chemicaltreatments.

13·24


M-I SWACO Products• WELLZYME* A• WELLZYME NS

Both WELLZYME A and WELLZYME NS arestarch-specific enzymes (Amylase) designed todegrade the starch component of the FLOPRO NTfilter cake. They work in monovalent carrierbrines, but do not work in divalent brines.

The optimum concentration of WELLZYME Aor WELLZYME NS is 2 to 5% volume. • Chelants — Dissolve the calcium carbonate

material in both water and reversible oil-basefluids. They are less aggressive than acids oroxidizers allowing for a more even breakdownof the filter cake and a delayed break if that isdesired. Chelants can be used in combinationwith other breakers such as enzymes or acidfor a more enhanced filter-cake cleanup. LowpH chelants are also effective in destroyingthe integrity of the FAZEPRO (reversible oil-base) filter cake.

Chelants are non-corrosive as opposedto acid.

M-I SWACO Products• D-SOLVER* pH 4.5 to 4.8• D-SOLVER PLUS pH 3.5 to 4.0

Both D-SOLVER and D-SOLVER PLUS are not

compatible with seawater or calcium chloride

or other divalent brines.

The concentration of chelants will dependon the amount of calcium carbonate material inthe filter cake, the surface area of the filter cake,and the volume of the breaker system.

13·25


M-I SWACO Breaker Systems• BREAKFREE – Enzyme-base system• BREAKDOWN – Enzyme/chelant-base system• FAZEBREAK – Chelant-base system for FAZEPRO

BREAKFREE – Enzyme-Base SystemBREAKFREE is recommended for the cleanup ofthe starch component of a FLOPRO NT filter cakewhere stand-alone or gravel-pack open-holecompletions are used. The process of the starchdestruction is slow and gentle and it preventsformation of emulsions and precipitates withformation fluids. It also disperses bridging par-ticles to flowback or fall out of the way.• Monovalent-base brines• Dispersant – SAPP*, D-SPERSE* (optional)• WELLZYME A or WELLZYME NS• Viscosifier (optional) — Increases delay

BREAKDOWN — Enzyme/Chelant

CompositionBREAKDOWN is recommended for the cleanup ofboth the starch and calcium carbonate compo-nents of a FLOPRO NT filter cake for stand-aloneand premium screen/gravel-pack open-holecompletions. The process of the starch and cal-cium carbonate destruction is slow and gentleand it prevents formation of emulsions andprecipitates with formation fluids. • Monovalent base brines • Dispersant – SAPP, D-SPERSE (optional)• WELLZYME A or WELLZYME NS• D-SOLVER or D-SOLVER PLUS — Chelant • Viscosifier (optional) — Increases delay

13·26


FAZEBREAK

FAZEBREAK is designed to clean up FAZEPRO.It does not completely dissolve the filter cake;it disperses the filter cake. The low pH of thesystem helps initiate the reversibility of thefilter cake and the chelant attacks the calciumcarbonate material.• Surfactant — Water-wet carbonate (FAZE-MUL*) • Viscosifier — Delays the reversal process

(SAFE-VIS) • Dispersant — Minimizes surface interactions

(EGMBE)• Base brine — Density enables good placement• Chelant — D-SOLVER

13·27

Chapter 14ENGINEERING FORMULAS AND TABLES


14. ENGINEERINGFORM

ULASAND

TABLES

ENGINEERING FORMULAS AND TABLES

14·1

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tin

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

23 ⁄86.

652.

375

1.81

50.

0032

000.

0022

790.

0054

7931

2.49

27 ⁄810

.40

2.87

52.

151

0.00

4495

0.00

3535

0.00

8029

222.

49

3∑9.

50

3.50

0 2.

992

0.00

8696

0.

0032

04

0.01

190

114.

9913

.30

3.50

0 2.

764

0.00

7421

0.00

4479

0.

0119

0 13

4.75

15.5

0 3.

500

2.60

2 0.

0065

77

0.00

5323

0.

0119

015

2.05

4 11

.85

4.00

0 3.

476

0.01

1737

0.

0038

05

0.01

5543

85

.20

14.0

0 4.

000

3.34

0 0.

0108

37

0.00

4706

0.

0155

43

92.2

8

4∑13

.75

4.50

0 3.

958

0.01

5218

0.

0044

53

0.01

9671

65

.71

16.6

0 4.

500

3.82

6 0.

0142

20

0.00

5451

0.

0196

71

70.3

220

.00

4.50

0 3.

640

0.01

2871

0.

0068

00

0.01

9671

77

.69

Ca

pa

city

an

d D

isp

lace

me

nt

AP

I D

rill

Pip

e

Con

tin

ues

on

nex

t p

age

Oilfi

eld Tu

bular

s


14·2

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tin

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

5 16

.25

5.00

0 4.

408

0.01

8875

0.

0054

10

0.02

4286

52

.98

19.5

0 5.

000

4.27

6 0.

0177

62

0.00

6524

0.

0242

86

56.3

025

.60

5.00

0 4.

000

0.01

5543

0.

0087

43

0.02

4286

64

.34

5∑21

.90

5.50

0 4.

778

0.02

2177

0.

0072

09

0.02

9386

45

.09

24.7

0 5.

500

4.67

0 0.

0211

86

0.00

8200

0.

0293

86

47.2

0

Con

tin

ued

from

pre

viou

s p

age

Ca

pa

city

an

d D

isp

lace

me

nt

AP

I D

rill

Pip

e


14·3

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tin

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

3∑23

.20

3.50

0 2.

250

0.00

500.

0084

0.01

34

200.

00

25.3

0 3.

500

2.06

3 0.

0042

0.00

92

0.01

34

238.

10

4 27

.20

4.00

0 2.

563

0.00

640.

0108

0.

0172

15

6.25

4∑41

.00

4.50

0 2.

750

0.00

740.

0149

0.02

23

135.

14

5 49

.30

5.00

0 3.

000

0.00

880.

0180

0.

0268

11

3.64

5∑

57.0

0 5.

500

3.37

5 0.

0112

0.

0210

0.

0322

89

.29

65 ⁄870

.80

6.62

5 4.

500

0.01

97

0.02

600.

0457

50

.76

Ca

pa

city

an

d D

isp

lace

me

nt

He

av

y-W

eig

ht

Dri

ll P

ipe

Pipe

Disp

lacem

ent

(Met

al O

nly

w/C

oup

.)

0.00

2W

tof

pip

ep

erft

wit

hco

up

lin

gs(

)Dep

th,f

t(

)=D

isp

lace

men

tof

pip

ein

ft3

Wto

fp

ipe

per

ftw

ith

cou

pli

ngs

()D

epth

,ft

()

2,73

3=

Dis

pla

cem

ento

fp

ipe

inb

bl


14·4

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tT

yp

ein

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

1 1.

14

N

1.05

0 0.

824

0.00

0660

0 0.

0004

11

0.00

1071

15

16.1

31.

20

E 1.

050

0.82

4 0.

0006

600

0.00

0411

0.00

1071

15

16.1

31.

55

U

1.05

0 0.

724

0.00

0535

0 0.

0005

36

0.00

1071

18

69.7

5

15 ⁄16

1.70

N

1.

315

1.04

9 0.

0001

069

0.00

0611

0.

0016

80

935.

491.

72

N

1.31

5 1.

049

0.00

0106

9 0.

0006

11

0.00

1680

93

5.49

1.80

I

1.31

5 1.

049

0.00

0106

9 0.

0006

11

0.00

1680

93

5.49

2.30

U

1.

315

0.95

7 0.

0089

00

0.00

0790

0.

0016

80

1124

.00

111⁄1

62.

10

I 1.

660

1.41

0 0.

0019

31

0.00

0746

0.

0026

77

517.

792.

30

N

1.66

0 1.

380

0.00

1850

0.

0008

27

0.00

2677

54

0.55

2.40

E

1.66

0 1.

380

0.00

1850

0.

0008

27

0.00

2677

54

0.55

2.33

I

1.66

0 1.

380

0.00

1850

0.

0008

27

0.00

2677

54

0.55

3.29

U

1.

660

1.26

4 0.

0015

52

0.00

1125

0.

0026

77

644.

31

Con

tin

ues

on

nex

t p

age

Ca

pa

city

an

d D

isp

lace

me

nt

AP

I T

ub

ing

an

d W

ork

stri

ng


14·5

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tT

yp

ein

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

17 ⁄82.

40

I 1.

900

1.65

0 0.

0026

45

0.00

0862

0.

0035

07

378.

112.

75

N

1.90

0 1.

610

0.00

2518

0.

0009

89

0.00

3507

39

7.14

2.76

I

1.90

0 1.

610

0.00

2518

0.

0009

89

0.00

3507

39

7.14

2.90

E

1.90

0 1.

610

0.00

2518

0.

0009

89

0.00

3507

39

7.14

4.19

U

1.

900

1.46

2 0.

0020

76

0.00

1430

0.

0035

07

481.

68

21 ⁄16

3.25

I

2.06

3 1.

751

0.00

2978

0.

0011

56

0.00

4134

33

5.75

23 ⁄84.

00

N

2.37

5 2.

041

0.00

4047

0.

0014

33

0.00

5479

24

7.12

4.60

N

2.

375

1.99

5 0.

0038

66

0.00

1613

0.

0054

79

258.

654.

70

E 2.

375

1.99

5 0.

0038

66

0.00

1613

0.

0054

79

258.

655.

80

N

2.37

5 1.

867

0.00

3386

0.

0020

93

0.00

5479

29

5.33

5.95

E

2.37

5 1.

867

0.00

3386

0.

0020

93

0.00

5479

29

5.33

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

Ca

pa

city

an

d D

isp

lace

me

nt

AP

I T

ub

ing

an

d W

ork

stri

ng


14·6

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tT

yp

ein

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

27 ⁄86.

4 N

2.

875

2.44

1 0.

0057

88

0.00

2241

0.

0080

29

172.

766.

5 E

2.87

5 2.

441

0.00

5788

0.

0022

41

0.00

8029

17

2.76

7.8

N

2.87

5 2.

323

0.00

5242

0.

0027

87

0.00

8029

19

0.76

7.9

E 2.

875

2.32

3 0.

0052

42

0.00

2787

0.

0080

29

190.

768.

6 N

2.

875

2.25

9 0.

0049

57

0.00

3072

0.

0080

29

201.

728.

7 E

2.87

5 2.

259

0.00

4957

0.

0030

72

0.00

8029

20

1.72

3∑7.

70

N

3.50

0 3.

068

0.00

9144

0.

0027

56

0.01

19

109.

379.

20

N

3.50

0 2.

992

0.00

8696

0.

0032

04

0.01

19

114.

999.

30

E 3.

500

2.99

2 0.

0086

96

0.00

3204

0.

0119

11

4.99

10.2

0 N

3.

500

2.99

2 0.

0086

96

0.00

3204

0.

0119

11

4.99

12.7

0 N

3.

500

2.75

0 0.

0073

46

0.00

4554

0.

0119

13

6.12

12.9

5 E

3.50

0 2.

750

0.00

7346

0.

0045

54

0.01

19

136.

12

Con

tin

ued

from

pre

viou

s p

age

Con

tin

ues

on

nex

t p

age

Ca

pa

city

an

d D

isp

lace

me

nt

AP

I T

ub

ing

an

d W

ork

stri

ng


14·7

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tT

yp

ein

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

4 9.

50

N

4.00

0 3.

458

0.01

2229

0.

0033

14

0.01

5543

81

.78

11.0

0 E

4.00

0 3.

476

0.01

1737

0.

0038

05

0.01

5543

85

.20

4∑12

.60

N

4.50

0 3.

958

0.01

5218

0.

0044

53

0.01

9671

65

.71

12.7

5 E

4.50

0 3.

958

0.01

5218

0.

0044

53

0.01

9671

65

.71

Type

: N

= N

on U

pset

I = In

tegr

al Jo

int

E =

Exte

rnal

Ups

et

Con

tin

ued

from

pre

viou

s p

age

Ca

pa

city

an

d D

isp

lace

me

nt

AP

I T

ub

ing

an

d W

ork

stri

ng


14·8

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tin

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

3∑

9.91

3.

500

2.99

2 0.

0086

960

0.00

3204

0.

0119

00

114.

99

4 11

.34

4.00

0 3.

428

0.01

1415

0.

0041

27

0.01

5543

87

.60

4∑9.

50

4.50

0 4.

090

0.01

6250

0.

0034

21

0.01

9671

61

.54

10.5

0 4.

500

4.05

2 0.

0159

50

0.00

3722

0.

0196

71

62.7

011

.60

4.50

0 4.

000

0.01

5543

0.

0041

29

0.01

9671

64

.34

13.0

4 4.

500

3.92

0 0.

0149

27

0.00

4744

0.

0196

71

66.9

913

.50

4.50

0 3.

920

0.01

4927

0.

0047

44

0.01

9671

66

.99

5 11

.50

5.00

0 4.

560

0.02

0199

0.

0040

86

0.02

4286

49

.51

13.0

0 5.

000

4.49

4 0.

0196

19

0.00

4667

0.

0242

86

50.9

715

.00

5.00

0 4.

408

0.01

8875

0.

0054

10

0.02

4286

52

.98

17.9

3 5.

000

4.27

6 0.

0177

62

0.00

6524

0.

0242

86

56.3

018

.00

5.00

0 4.

276

0.01

7762

0.

0065

24

0.02

4286

56

.30

Ca

pa

city

an

d D

isp

lace

me

nt

Ca

sin

g a

nd

Pla

in E

nd

Lin

ers

Con

tin

ues

on

nex

t p

age


14·9

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tin

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

521

.40

5.00

0 4.

126

0.01

6537

0.

0077

48

0.02

4286

60

.47

23.2

0 5.

000

4.04

4 0.

0158

87

0.00

8399

0.

0242

86

62.9

524

.10

5.00

0 4.

000

0.01

5543

0.

0087

43

0.02

4286

64

.34

5∑14

.00

5.50

0 5.

012

0.02

4402

0.

0049

83

0.02

9386

40

.98

15.5

0 5.

500

4.95

0 0.

0238

02

0.00

5583

0.

0293

86

42.0

117

.00

5.50

0 4.

892

0.02

3248

0.

0061

38

0.02

9386

43

.01

19.8

1 5.

500

4.77

8 0.

0221

77

0.00

7209

0.

0293

86

45.0

920

.00

5.50

0 4.

778

0.02

2177

0.

0072

09

0.02

9386

45

.09

23.0

0 5.

500

4.67

0 0.

0211

86

0.00

8200

0.

0293

86

47.2

0

65 ⁄820

.00

6.62

5 6.

049

0.03

5545

0.

0070

92

0.04

2636

28

.13

24.0

0 6.

625

5.92

1 0.

0340

56

0.00

8580

0.

0426

36

29.3

627

.65

6.62

5 5.

791

0.03

2577

0.

0100

59

0.04

2636

30

.70

28.0

0 6.

625

5.79

1 0.

0325

77

0.01

0059

0.

0426

36

30.7

032

.00

6.62

5 5.

675

0.03

1285

0.

0113

51

0.04

2636

31

.96

Con

tin

ued

from

pre

viou

s p

age

Con

tin

ues

on

nex

t p

age

Ca

pa

city

an

d D

isp

lace

me

nt

Ca

sin

g a

nd

Pla

in E

nd

Lin

ers


14·10

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tin

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

7 17

.00

7.00

0 6.

538

0.04

1524

0.

0060

760

0.04

7600

24

.08

20.0

0 7.

000

6.45

6 0.

0404

89

0.00

7111

00.

0476

00

24.7

023

.00

7.00

0 6.

366

0.03

9368

0.

0082

320

0.04

7600

25

.40

26.0

0 7.

000

6.27

6 0.

0382

63

0.00

9337

0 0.

0476

00

26.1

429

.00

7.00

0 6.

184

0.03

7149

0.

0104

51

0.04

7600

26

.92

32.0

0 7.

000

6.09

4 0.

0360

76

0.01

1524

0.

0476

00

27.7

235

.00

7.00

0 6.

004

0.03

5018

0.

0125

82

0.04

7600

28

.56

38.0

0 7.

000

5.92

0 0.

0340

45

0.01

3555

0.

0476

00

29.3

7

75 ⁄824

.00

7.62

5 7.

025

0.04

7940

0.

0085

390

0.05

6479

20

.86

26.4

0 7.

625

6.96

9 0.

0471

79

0.00

9300

0 0.

0564

79

21.2

029

.70

7.62

5 6.

875

0.04

5915

0.

0010

.64

0.05

6479

21

.78

33.7

0 7.

625

6.76

5 0.

0444

58

0.01

2022

0.

0564

79

22.4

939

.00

7.62

5 6.

625

0.04

2636

0.

0138

43

0.05

6479

23

.45

Con

tin

ued

from

pre

viou

s p

age

Con

tin

ues

on

nex

t p

age

Ca

pa

city

an

d D

isp

lace

me

nt

Ca

sin

g a

nd

Pla

in E

nd

Lin

ers


14·11

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tin

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

75 ⁄842

.80

7.62

5 6.

501

0.04

1055

0.

0154

24

0.05

6479

24

.36

45.3

0 7.

625

6.43

5 0.

0402

26

0.01

6253

0.

0564

79

24.8

647

.10

7.62

5 6.

375

0.03

9479

0.

0170

00

0.05

6479

25

.33

85 ⁄824

.00

8.62

5 8.

097

0.06

3688

0.

0085

77

0.07

2265

15

.70

28.0

0 8.

625

8.01

7 0.

0624

36

0.00

9829

0.

0722

65

16.0

232

.00

8.62

5 7.

921

0.06

0949

0.

0113

16

0.07

2265

16

.41

36.0

0 8.

625

7.82

5 0.

0594

81

0.01

2784

0.

0722

65

16.8

140

.00

8.62

5 7.

725

0.05

7971

0.

0142

95

0.07

2265

17

.25

49.0

0 8.

625

7.51

1 0.

0548

03

0.01

7462

0.

0722

65

18.2

5

95 ⁄832

.30

9.62

5 9.

001

0.07

8703

0.

0112

91

0.08

9994

12

.71

36.0

0 9.

625

8.92

1 0.

0773

10

0.01

2683

0.

0899

94

12.9

340

.00

9.62

5 8.

835

0.07

5827

0.

0141

67

0.08

9994

13

.19

43.5

0 9.

625

8.75

5 0.

0744

60

0.01

5534

0.

0899

94

13.4

3

Con

tin

ued

from

pre

viou

s p

age

Con

tin

ues

on

nex

t p

age

Ca

pa

city

an

d D

isp

lace

me

nt

Ca

sin

g a

nd

Pla

in E

nd

Lin

ers


14·12

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tin

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

95 ⁄847

.00

9.62

5 8.

681

0.07

3206

0.

0167

87

0.08

9994

13

.66

53.5

0 9.

625

8.53

5 0.

0707

65

0.01

9229

0.

0899

94

14.1

3

10π

32.7

5 10

.750

10

.192

0.

1009

09

0.01

1352

0.

1122

60

9.91

40.5

0 10

.750

10

.050

0.

0981

16

0.01

4144

0.

1122

60

10.1

945

.50

10.7

50

9.95

0 0.

0961

74

0.01

6087

0.

1122

60

10.4

051

.00

10.7

50

9.85

0 0.

0942

50

0.01

8010

0.

1122

60

10.6

155

.50

10.7

50

9.76

0 0.

0925

36

0.01

9725

0.

1122

60

10.8

1

11π

42.0

0 11

.750

11

.084

0.

1193

45

0.01

4773

0.

1341

18

8.38

47.0

0 11

.750

11

.000

0.

1175

43

0.01

6575

0.

1341

18

8.51

54.0

0 11

.750

10

.880

0.

1149

92

0.01

9126

0.

1341

18

8.70

60.0

0 11

.750

10

.772

0.

1127

20

0.02

1397

0.

1341

18

8.87

Con

tin

ued

from

pre

viou

s p

age

Con

tin

ues

on

nex

t p

age

Ca

pa

city

an

d D

isp

lace

me

nt

Ca

sin

g a

nd

Pla

in E

nd

Lin

ers


14·13

We

igh

tw

/Co

up

.O

DID

Ca

pD

isp

l.C

ap

Dis

pl.

Lin

ea

rS

ize

lb/f

tin

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

133 ⁄8

48.0

0 13

.375

12

.715

0.

1570

52

0.01

6727

0.

1737

79

6.37

54.5

0 13

.375

12

.615

0.

1545

91

0.01

9188

0.

1737

79

6.47

61.0

0 13

.375

12

.515

0.

1521

50

0.02

1629

0.

1737

79

6.57

68.0

0 13

.375

12

.415

0.

1497

28

0.02

4051

0.

1737

79

6.68

72.0

0 13

.375

12

.347

0.

1480

92

0.02

5687

0.

1737

79

6.75

16

65.0

0 16

.000

15

.250

0.

2259

17

0.02

2768

0.

2486

85

4.43

75.0

0 16

.000

15

.124

0.

2221

99

0.02

6486

0.

2486

85

4.50

84.0

0 16

.000

15

.010

0.

2188

62

0.02

9823

0.

2486

85

4.57

185 ⁄8

87.5

0 18

.625

17

.755

0.

3062

32

0.03

0746

0.

3369

79

3.27

20

94.0

0 20

.000

19

.124

0.

3552

77

0.03

3293

0.

3885

70

2.81

106.

50

20.0

00

19.0

00

0.35

0685

0.

0378

86

0.38

8570

2.

8513

3.00

20

.000

18

.730

0.

3407

89

0.04

7782

0.

3885

70

2.93

Con

tin

ued

from

pre

viou

s p

age

Ca

pa

city

an

d D

isp

lace

me

nt

Ca

sin

g a

nd

Pla

in E

nd

Lin

ers


14·14

OD

IDC

ap

Dis

pl.

Ca

p D

isp

l.L

ine

ar

Siz

ein

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

3∫

3.12

5 1.

2500

0.

0015

18

0.00

7969

0.

0094

87

658.

83

3∑

3.50

0 1.

5000

0.

0021

86

0.00

9714

0.

0119

00

457.

52

3π

3.75

0 1.

5000

0.

0021

86

0.01

1475

0.

0136

61

457.

52

4 4.

000

2.00

00

0.00

3886

0.

0116

57

0.01

5543

25

7.35

4∫

4.12

5 2.

0000

0.

0038

86

0.01

2644

0.

0165

29

257.

35

4∏4.

250

2.00

00

0.00

3886

0.

0136

61

0.01

7546

25

7.35

4∑

4.50

0 2.

2500

0.

0049

18

0.01

4754

0.

0196

71

203.

34

4π4.

750

2.25

00

0.00

4918

0.

0170

00

0.02

1918

20

3.34

5 5.

000

2.25

00

0.00

4918

0.

0193

68

0.02

4286

20

3.34

5∏5.

250

2.25

00

0.00

4918

0.

0218

57

0.02

6775

20

3.34

Ca

pa

city

an

d D

isp

lace

me

nt

Dri

ll C

oll

ars

Con

tin

ues

on

nex

t p

age


14·15

OD

IDC

ap

Dis

pl.

Ca

p D

isp

l.L

ine

ar

Siz

ein

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

Con

tin

ues

on

nex

t p

age

5∑

5.50

0 2.

2500

0.

0049

18

0.02

4468

0.

0293

86

203.

34

5π5.

750

2.25

00

0.00

4918

0.

0272

00

0.03

2118

20

3.34

6 6.

000

2.25

00

0.00

4918

0.

0300

53

0.03

4971

20

3.34

6∏6.

250

2.25

00

0.00

4918

0.

0330

28

0.03

7946

20

3.34

6.25

0 2.

8125

0.

0076

84

0.03

0262

0.

0379

46

130.

14

6∑6.

500

2.25

00

0.00

4918

0.

0361

25

0.04

1043

20

3.34

6.50

0 2.

8125

0.

0076

84

0.03

3359

0.

0410

43

130.

14

6π6.

750

2.25

00

0.00

4918

0.

0393

43

0.04

4261

20

3.34

6.75

0 2.

8125

0.

0076

84

0.03

6576

0.

0442

61

130.

14

7 7.

000

2.81

25

0.00

7684

0.

0399

16

0.04

7600

13

0.14

7∏

7.25

0 2.

8125

0.

0076

84

0.04

3376

0.

0510

61

130.

14

7∑7.

500

2.81

25

0.00

7684

0.

0469

59

0.05

4643

13

0.14

Con

tin

ued

from

pre

viou

s p

age

Ca

pa

city

an

d D

isp

lace

me

nt

Dri

ll C

oll

ars


14·16

OD

IDC

ap

Dis

pl.

Ca

p D

isp

l.L

ine

ar

Siz

ein

.in

.b

bl/

ftb

bl/

ftb

bl/

ftft

/bb

l

7π7.

750

2.81

25

0.00

7684

0.

0506

62

0.05

8346

13

0.14

8 8.

000

2.81

25

0.00

7684

0.

0544

87

0.06

2171

13

0.14

8.00

0 3.

0000

0.

0087

43

0.05

3428

0.

0621

71

114.

38

8∏8.

250

3.00

00

0.00

8743

0.

0573

75

0.06

6118

11

4.38

8∑8.

500

3.00

00

0.00

8743

0.

0614

43

0.07

0186

11

4.38

8π8.

750

3.00

00

0.00

8743

0.

0656

32

0.07

4375

11

4.38

9 9.

000

3.00

00

0.00

8743

0.

0699

43

0.07

8686

11

4.38

9∏

9.25

0 3.

0000

0.

0087

43

0.07

4375

0.

0831

18

114.

38

9∑9.

500

3.00

00

0.00

8743

0.

0789

28

0.08

7671

11

4.38

9π9.

750

3.00

00

0.00

8743

0.

0836

03

0.09

2346

11

4.38

10

10.0

00

3.00

00

0.00

8743

0.

0884

00

0.09

7143

11

4.38

11

11.0

00

3.00

00

0.00

8743

0.

1088

00

0.11

7543

11

4.38

Con

tin

ued

from

pre

viou

s p

age

Ca

pa

city

an

d D

isp

lace

me

nt

Dri

ll C

oll

ars


14·17

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

π0.

067

0.49

0.61

60.

0003

72,

712.

830.

0020

748

3.19

20.

0154

864

.592

5

10.

067

0.67

0.86

60.

0007

31,

372.

610.

0040

924

4.48

10.

0306

32.6

819

10.

075

0.74

0.85

0.00

071,

424.

780.

0039

425

3.77

20.

0294

833

.923

9

10.

080.

790.

840.

0006

91,

458.

900.

0038

525

9.85

0.02

879

34.7

364

10.

087

0.85

0.82

60.

0006

61,

508.

770.

0037

226

8.73

30.

0278

435

.923

9

10.

095

0.92

0.81

0.00

064

1,56

8.97

0.00

358

279.

454

0.02

677

37.3

571

10.

102

0.98

0.79

60.

0006

21,

624.

640.

0034

628

9.37

10.

0258

538

.682

7

10.

109

1.04

0.78

20.

0005

91,

683.

340.

0033

429

9.82

50.

0249

540

.080

2

10.

125

1.17

0.75

0.00

055

1,83

0.04

0.00

307

325.

956

0.02

295

43.5

733

1∏0.

067

0.85

1.11

60.

0012

182

6.52

0.00

679

147.

215

0.05

081

19.6

795

1∏0.

075

0.94

1.1

0.00

118

850.

740.

0066

151.

529

0.04

937

20.2

562

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing

Con

tin

ues

on

nex

t p

age


14·18

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

1∏0.

081

1.09

0.00

115

866.

430.

0064

815

4.32

20.

0484

720

.629

6

1∏0.

087

1.08

1.07

60.

0011

288

9.12

0.00

631

158.

364

0.04

724

21.1

699

1∏0.

091.

111.

070.

0011

189

9.12

0.00

624

160.

145

0.04

671

21.4

08

1∏0.

095

1.17

1.06

0.00

109

916.

160.

0061

316

3.18

10.

0458

421

.813

8

1∏0.

097

1.19

1.05

60.

0010

892

3.12

0.00

608

164.

419

0.04

5521

.979

4

1∏0.

102

1.25

1.04

60.

0010

694

0.85

0.00

597

167.

578

0.04

464

22.4

016

1∏0.

104

1.27

1.04

20.

0010

594

8.09

0.00

592

168.

867

0.04

4322

.574

1∏0.

109

1.33

1.03

20.

0010

396

6.55

0.00

581

172.

156

0.04

345

23.0

136

1∏0.

116

1.4

1.01

80.

0010

199

3.32

0.00

565

176.

923

0.04

228

23.6

509

1∏0.

118

1.43

1.01

40.

001

1,00

1.17

0.00

561

178.

322

0.04

195

23.8

379

1∏0.

125

1.5

10.

0009

71,

029.

400.

0054

518

3.35

0.04

0824

.51

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing


14·19

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

1∏0.

134

1.6

0.98

20.

0009

41,

067.

480.

0052

619

0.13

30.

0393

425

.416

8

1∏0.

145

1.71

0.96

0.00

091,

116.

970.

0050

319

8.94

70.

0376

26.5

951

1∏0.

156

1.82

0.93

80.

0008

51,

169.

980.

0048

208.

389

0.03

5927

.857

2

1∏0.

175

2.01

0.9

0.00

079

1,27

0.86

0.00

442

226.

358

0.03

305

30.2

593

1∑0.

095

1.43

1.31

0.00

167

599.

850.

0093

610

6.84

10.

0700

214

.282

4

1∑0.

102

1.52

1.29

60.

0016

361

2.88

0.00

916

109.

162

0.06

853

14.5

926

1∑0.

109

1.62

1.28

20.

0016

626.

340.

0089

611

1.55

90.

0670

614

.913

1

1∑0.

116

1.71

1.26

80.

0015

664

0.24

0.00

877

114.

036

0.06

5615

.244

2

1∑0.

118

1.74

1.26

40.

0015

564

4.3

0.00

871

114.

759

0.06

519

15.3

408

1∑0.

125

1.84

1.25

0.00

152

658.

820.

0085

211

7.34

40.

0637

515

.686

4

1∑0.

134

1.95

1.23

20.

0014

767

8.21

0.00

828

120.

798

0.06

193

16.1

481

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing


14·20

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

1∑0.

145

2.1

1.21

0.00

142

703.

090.

0079

912

5.23

10.

0597

416

.740

7

1∑0.

156

2.24

1.18

80.

0013

772

9.38

0.00

7712

9.91

20.

0575

817

.366

4

1∑0.

175

2.48

1.15

0.00

128

778.

370.

0072

113

8.63

90.

0539

618

.533

1

1∑0.

188

2.63

1.12

40.

0012

381

4.8

0.00

689

145.

127

0.05

155

19.4

004

1∑0.

192.

661.

120.

0012

282

0.63

0.00

684

146.

165

0.05

118

19.5

392

1∑0.

203

2.81

1.09

40.

0011

686

0.1

0.00

653

153.

196

0.04

883

20.4

79

1π0.

095

1.68

1.56

0.00

236

422.

990.

0132

775

.341

0.09

929

10.0

715

1π0.

102

1.8

1.54

60.

0023

243

0.69

0.01

304

76.7

120.

0975

210

.254

7

1π0.

109

1.91

1.53

20.

0022

843

8.6

0.01

2878

.12

0.09

576

10.4

43

1π0.

116

2.02

1.51

80.

0022

444

6.73

0.01

257

79.5

680.

0940

210

.636

5

1π0.

118

2.06

1.51

40.

0022

344

9.09

0.01

2579

.989

0.09

352

10.6

928

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing


14·21

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

1π0.

125

2.17

1.5

0.00

219

457.

510.

0122

781

.489

0.09

1810

.893

3

1π0.

134

2.31

1.48

20.

0021

346

8.69

0.01

198

83.4

80.

0896

111

.159

6

1π0.

145

2.49

1.46

0.00

207

482.

920.

0116

386

.015

0.08

697

11.4

984

1π0.

156

2.66

1.43

80.

0020

149

7.81

0.01

128

88.6

670.

0843

711

.852

9

1π0.

175

2.94

1.4

0.00

1952

5.2

0.01

069

93.5

460.

0799

712

.505

1

1π0.

188

3.14

1.37

40.

0018

354

5.27

0.01

0397

.12

0.07

703

12.9

828

1π0.

193.

171.

370.

0018

254

8.46

0.01

024

97.6

880.

0765

813

.058

8

1π0.

203

3.35

1.34

40.

0017

556

9.88

0.00

985

101.

504

0.07

3713

.568

9

1π0.

204

3.37

1.34

20.

0017

557

1.58

0.00

982

101.

807

0.07

348

13.6

094

20.

109

2.2

1.78

20.

0030

832

4.17

0.01

732

57.7

390.

1295

67.

7184

20.

116

2.33

1.76

80.

0030

432

9.32

0.01

705

58.6

570.

1275

37.

8411

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing


14·22

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

20.

118

2.37

1.76

40.

0030

233

0.82

0.01

697

58.9

230.

1269

67.

8767

20.

125

2.5

1.75

0.00

297

336.

130.

0167

59.8

690.

1249

58.

0033

20.

134

2.67

1.73

20.

0029

134

3.15

0.01

636

61.1

20.

1223

98.

1705

20.

145

2.87

1.71

0.00

284

352.

040.

0159

562

.703

0.11

938.

3821

20.

156

3.07

1.68

80.

0027

736

1.28

0.01

554

64.3

480.

1162

58.

602

20.

175

3.41

1.65

0.00

264

378.

110.

0148

567

.346

0.11

108

9.00

28

20.

188

3.64

1.62

40.

0025

639

0.31

0.01

438

69.5

20.

1076

9.29

33

20.

193.

671.

620.

0025

539

2.24

0.01

431

69.8

640.

1070

89.

3393

20.

203

3.9

1.59

40.

0024

740

5.14

0.01

386

72.1

610.

1036

79.

6464

20.

204

3.91

1.59

20.

0024

640

6.16

0.01

382

72.3

430.

1034

19.

6707

23 ⁄80.

109

2.64

2.15

70.

0045

222

1.25

0.02

538

39.4

080.

1898

35.

268

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing


14·23

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

23 ⁄80.

118

2.84

2.13

90.

0044

422

4.99

0.02

495

40.0

740.

1866

75.

357

23 ⁄80.

125

32.

125

0.00

439

227.

960.

0246

340

.603

0.18

424

5.42

78

23 ⁄80.

134

3.21

2.10

70.

0043

123

1.88

0.02

421

41.3

0.18

113

5.52

1

23 ⁄80.

145

3.45

2.08

50.

0042

223

6.79

0.02

371

42.1

760.

1773

75.

6381

23 ⁄80.

156

3.7

2.06

30.

0041

324

1.87

0.02

321

43.0

810.

1736

45.

759

23 ⁄80.

175

4.11

2.02

50.

0039

825

1.03

0.02

236

44.7

130.

1673

15.

9771

23 ⁄80.

188

4.39

1.99

90.

0038

825

7.61

0.02

179

45.8

830.

1630

46.

1336

23 ⁄80.

194.

431.

995

0.00

387

258.

640.

0217

146

.068

0.16

239

6.15

83

23 ⁄80.

203

4.71

1.96

90.

0037

726

5.52

0.02

114

47.2

920.

1581

86.

322

23 ⁄80.

204

4.73

1.96

70.

0037

626

6.06

0.02

1147

.388

0.15

786

6.33

48

23 ⁄80.

224

5.15

1.92

70.

0036

127

7.22

0.02

025

49.3

760.

1515

6.60

05

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing


14·24

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

25 ⁄80.

134

3.56

2.35

70.

0054

185.

30.

0303

33.0

040.

2266

64.

4119

25 ⁄80.

145

3.84

2.33

50.

0053

188.

80.

0297

433

.628

0.22

245

4.49

54

25 ⁄80.

156

4.11

2.31

30.

0052

192.

410.

0291

834

.271

0.21

828

4.58

13

25 ⁄80.

175

4.58

2.27

50.

0050

319

8.89

0.02

823

35.4

260.

2111

74.

7357

25 ⁄80.

194.

942.

245

0.00

4920

4.25

0.02

749

36.3

790.

2056

34.

8631

25 ⁄80.

204

5.27

2.21

70.

0047

720

9.44

0.02

681

37.3

030.

2005

44.

9867

25 ⁄80.

224

5.74

2.17

70.

0046

217.

20.

0258

538

.687

0.19

336

5.17

16

25 ⁄80.

256.

342.

125

0.00

439

227.

960.

0246

340

.603

0.18

424

5.42

78

25 ⁄80.

287.

012.

065

0.00

414

241.

40.

0232

642

.997

0.17

398

5.74

78

25 ⁄80.

37.

452.

025

0.00

398

251.

030.

0223

644

.713

0.16

731

5.97

71

27 ⁄80.

125

3.67

2.62

50.

0066

914

9.39

0.03

758

26.6

090.

2811

43.

557

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing


14·25

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

27 ⁄80.

134

3.92

2.60

70.

0066

151.

460.

0370

726

.977

0.27

733.

6063

27 ⁄80.

145

4.23

2.58

50.

0064

915

4.05

0.03

644

27.4

380.

2726

33.

6679

27 ⁄80.

156

4.53

2.56

30.

0063

815

6.71

0.03

583

27.9

120.

2680

13.

7312

27 ⁄80.

175

5.05

2.52

50.

0061

916

1.46

0.03

477

28.7

580.

2601

33.

8443

27 ⁄80.

188

5.4

2.49

90.

0060

716

4.84

0.03

406

29.3

590.

2548

3.92

47

27 ⁄80.

195.

452.

495

0.00

605

165.

360.

0339

529

.454

0.25

398

3.93

73

27 ⁄80.

203

5.79

2.46

90.

0059

216

8.87

0.03

325

30.0

770.

2487

24.

0207

27 ⁄80.

204

5.82

2.46

70.

0059

116

9.14

0.03

319

30.1

260.

2483

14.

0272

27 ⁄80.

224

6.34

2.42

70.

0057

217

4.76

0.03

213

31.1

270.

2403

34.

1611

27 ⁄80.

257.

012.

375

0.00

548

182.

50.

0307

632

.505

0.23

014

4.34

53

27 ⁄80.

287.

762.

315

0.00

521

192.

080.

0292

334

.212

0.21

866

4.57

34

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing


14·26

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

27 ⁄80.

38.

252.

275

0.00

503

198.

890.

0282

335

.426

0.21

117

4.73

57

3∑0.

134

4.82

3.23

20.

0101

598

.55

0.05

697

17.5

520.

4261

92.

3464

3∑0.

145

5.2

3.21

0.01

001

99.9

0.05

6217

.794

0.42

041

2.37

87

3∑0.

156

5.57

3.18

80.

0098

710

1.29

0.05

543

18.0

40.

4146

62.

4116

3∑0.

175

6.21

3.15

0.00

964

103.

740.

0541

218

.478

0.40

484

2.47

01

3∑0.

188

6.65

3.12

40.

0094

810

5.48

0.05

323

18.7

870.

3981

82.

5114

3∑0.

196.

723.

120.

0094

610

5.75

0.05

309

18.8

350.

3971

62.

5179

3∑0.

203

7.15

3.09

40.

0093

107.

530.

0522

119

.153

0.39

057

2.56

04

3∑0.

204

7.18

3.09

20.

0092

910

7.67

0.05

214

19.1

780.

3900

72.

5637

3∑0.

224

7.84

3.05

20.

0090

511

0.51

0.05

0819

.684

0.38

004

2.63

13

3∑0.

258.

683

0.00

874

114.

380.

0490

920

.372

0.36

722.

7233

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing


14·27

Siz

eW

all

Ca

lc.

bb

l/L

ine

ar

ft3/

Lin

ea

rg

al/

Lin

ea

rO

DT

hic

kn

ess

wt/

ftID

Lin

ea

r ft

ft/b

bl

Lin

ea

r ft

ft/f

t3L

ine

ar

ftft

/ga

l

3∑0.

289.

632.

940.

0084

119.

090.

0471

421

.212

0.35

266

2.83

56

3∑0.

310

.25

2.9

0.00

817

122.

40.

0458

721

.801

0.34

313

2.91

44

4∑0.

204

9.36

4.09

20.

0162

761

.48

0.09

132

10.9

50.

6831

71.

4638

4∑0.

224

10.2

34.

052

0.01

595

62.7

0.08

955

11.1

670.

6698

81.

4928

4∑0.

2511

.35

40.

0155

464

.34

0.08

726

11.4

590.

6528

1.53

19

4∑0.

2812

.62

3.94

0.01

508

66.3

10.

0846

711

.811

0.63

336

1.57

89

4∑0.

313

.46

3.9

0.01

477

67.6

80.

0829

612

.055

0.62

057

1.61

14

65 ⁄80.

2818

.97

6.06

50.

0357

327

.98

0.20

062

4.98

41.

5008

0.66

63

65 ⁄80.

320

.27

6.02

50.

0352

628

.36

0.19

798

5.05

11.

4810

70.

6752

Con

tin

ued

from

pre

viou

s p

age

Tu

bu

lar/

Op

en

Ho

le:

Co

il T

ub

ing


14·28

Flui

d Eng

inee

ring C

alcul

atio

nsE

stim

ati

on

of

the

Nu

mb

er

of

Pe

rfo

rati

on

s

Plu

gg

ed

wit

h S

oli

ds

Du

e t

o F

luid

Lo

ss:

Wh

ere

:

# PP

= #

of p

lugg

ed p

erfo

rati

ons

S =

Vol

um

e fr

acti

on o

f sol

ids

(vol

% s

olid

s/10

0)V

L =

Vol

um

e of

flu

id lo

st t

o p

erfo

rati

ons,

bbl

Vp

= V

olu

me

of a

per

fora

tion

(see

not

e), i

n.3

% P

P =

Perc

ent

of p

erfo

rati

ons

that

are

plu

gged

No

te:

The

volu

me

of o

ne

per

fora

tion

tu

nn

el c

anbe

app

roxi

mat

ed b

y co

nsi

der

ing

it t

o be

a 1

0-in

.cy

lin

der

wit

h a

dia

met

er o

f 0.5

in.:

Vol

um

e,V

p1.

96in

.3 %

PP=

#PP

shot

s ft(

)len

gth

ofp

erfs

()

#PP

=(S

)(V

L)(9

702)

Vp


14·29

De

term

ine

Str

etc

h o

r F

ree

po

int

Str

etc

h:

Fre

ep

oin

t:

Wh

ere

:

∆L

= St

ren

gth

in in

ches

(in

.)L

= Le

ngt

h o

f pip

e fr

om s

urf

ace

to p

oin

t of

an

chor

dow

nh

ole

(stu

ckp

oin

t) in

feet

(ft)

F =

Forc

e re

quir

ed t

o st

retc

h p

ipe

L d

ista

nce

, in

1,0

00 lb

∆ (4

54 k

g)A

= C

ross

sec

tion

al a

rea

of p

ipe

or t

ubi

ng,

in

squ

are

inch

es (i

n.2 )

Are

aof

pip

e=

OD

2–

ID2

()0

.785

4

L=

2500

()∆

L ()A (

)F

∆L

=L ()

F ()25

00(

)A ()


14·30

Ex

am

ple

:H

ook

load

is 1

20,0

00 lb

. Pu

ll 14

3,00

0 lb

. Mar

k on

pip

e m

oves

up

16

in. P

ipe

is 4

∑-i

n. d

rill

pip

e w

ith

an ID

of 3

.826

in.

Pip

e is

stu

ck a

t ap

pro

xim

atel

y 7,

652

ft.

Weig

ht-U

p For

mul

as(W

ith

ou

t H

2O

an

d s

alt

fra

ctio

n)

To

we

igh

t u

p 1

bb

l o

f fl

uid

wit

h d

ry s

alt

:

lb o

f wt

mat

eria

l per

bbl

of f

luid

=

Vol

um

e in

crea

se p

er b

bl o

f flu

id=

dF

−d1

dW

M−

dF

Wd

F−

d1(

)d

WM

−d

F

L=

2500

()1

6 ()4

.4 ()

23=

7,65

2

Are

aof

pip

e=

OD

2−

ID2

()0

.785

4=

4.4

in2


14·31

To

we

igh

t u

p 1

fin

al

bb

l o

f fl

uid

wit

h

dry

sa

lt m

ate

ria

l:

lb o

f wei

ght

mat

eria

l p

er fi

nal

bbl

of f

luid

=

Vol

um

e of

in

itia

l flu

id in

bbl

=

Wh

ere

:

dF

= Fi

nal

den

sity

d1

= In

itia

l den

sity

dW

M =

Den

sity

of w

eigh

t m

ater

ial,

lb/g

al(S

ee t

able

on

pag

e 15

·32)

VF

= Fi

nal

vol

um

eW

= W

eigh

t fa

ctor

, lb/

bbl (

See

tabl

e on

pag

e 15

·32)

1−

dF

−d1

dW

M−

dF

⎡ ⎣ ⎢ ⎤ ⎦ ⎥

VF

Wd

F−

d1(

)d

WM

−d

F


14·32

Sp

eci

fic

lb/g

al

lb/b

bl

Sa

ckW

eig

hti

ng

Ag

en

tsG

rav

ity

(SG

*8

.33

4)

(lb

/ga

l *

42

)S

ack

s/b

bl

wt/

lb

Bar

ite

4.2

351,

470

14.7

100

Cal

ciu

m C

arbo

nat

e2.

823

.35

981

19.6

50

Cal

ciu

m B

rom

ide

3.35

327

.96

1,17

421

.355

Cal

ciu

m C

hlo

rid

e1.

6814

588

7.4

80

Pota

ssiu

m C

hlo

rid

e1.

988

16.6

696

13.9

507.

010

0

Pota

ssiu

m F

orm

ate

1.91

15.9

669

12.2

55

Sod

ium

Ch

lori

de

2.16

318

.075

87.

610

0

Sod

ium

Bro

mid

e3.

205

26.7

1,12

320

.455

Sod

ium

For

mat

e1.

919

1667

212

.255

Zin

c B

rom

ide

4.21

935

.21,

478

14.8

100

Am

mon

ium

Ch

lori

de

1.54

12.8

453

910

.850

Ces

ium

For

mat

e2.

420

841

8.4

100

De

nsi

tie

s o

f W

eig

hti

ng

Ag

en

ts


14·33

Am

mon

ium

Ch

lori

de

NH

4Cl

8.90

1.06

7

Sod

ium

Ch

lori

de

NaC

l10

.01.

2

Cal

ciu

m C

hlo

rid

eC

aCl 2

11.8

1.41

Cal

ciu

m C

hlo

rid

e/C

aCl 2

/CaB

r 215

.11.

81C

alci

um

Bro

mid

e

Pota

ssiu

m C

hlo

rid

eK

Cl

9.8

1.17

5

Sod

ium

Bro

mid

eN

aBr

12.7

1.52

Cal

ciu

m B

rom

ide

CaB

r 215

.31.

83

Zin

c B

rom

ide

ZnB

r 2/C

aBr

19.2

2.30

ZnB

r 220

.52.

46

Sod

ium

For

mat

eN

aCO

OH

11.0

1.32

Pota

ssiu

m F

orm

ate

KC

OO

OH

13.1

1.57

Ces

ium

For

mat

eC

sCO

OH

19.9

2.38

6

Not

e: D

o n

ot u

se th

ese

den

siti

es w

ith

out r

efer

rin

g to

the

brin

e ta

bles

for

crys

talli

zati

on p

oin

ts.

Bri

ne

s a

nd

Ma

xim

um

De

nsi

tie

s


14·34

Flu

id V

elo

city

(V

):

Pip

e:

An

nu

lus:

Wh

ere

:

Q =

flow

rat

e (g

al/m

in)

Vp

= fl

uid

vel

ocit

y in

pip

e, ft

/sec

Va

= fl

uid

vel

ocit

y in

an

nu

lus,

ft/s

ecD

2=

ID c

asin

g or

ou

ter

ann

ulu

s w

all (

in.)

D1

= O

D o

f tu

bin

g or

inn

er a

nn

ulu

s (i

n.)

Hydr

aulic

Calc

ulat

ions

for

Non-

New

toni

an Fl

uids

Fri

ctio

n L

oss

in

Pip

e:

Wh

ere

:

P p=

pre

ssu

re lo

ss in

pip

e (p

si)

L m=

mea

sure

d d

epth

or

len

gth

of p

ipe

(ft)

P p/L

m=

psi

/ft

pre

ssu

re lo

ssf p

= fr

icti

on fa

ctor

for

pip

eV

p=

flow

vel

ocit

y in

pip

e (f

t/se

c)d

= d

ensi

ty (l

b/ga

l)ID

= ID

of p

ipe

(in

.)

Vp

=0.

408

Q ()

ID2

Va

=0.

408

Q ()

D2()2

−D

1()2

P p

L m

=f p

Vp()2

d

25.8

1ID (

)


14·35

Fri

ctio

n L

oss

in

Bit

No

zzle

:

Wh

ere

:

Pn =

pre

ssu

re lo

ss in

noz

zles

(psi

)d

= fl

uid

den

sity

(lb/

gal)

Q =

flow

rat

e (g

al/m

in)

Dn

= d

iam

eter

of b

it n

ozzl

es (1 ⁄3

2in

.)

Theo

reti

cally

th

e su

rfac

e (s

tan

dpip

e) p

ress

ure

shou

ld e

qual

th

e su

m o

f th

e fr

icti

on p

ress

ure

loss

es.

P s=

P p+

P n+

P at

Wh

ere

:

P s=

surf

ace

pre

ssu

reP p

= p

ress

ure

loss

in p

ipe

Dep

end

ing

on w

ell c

onfi

gura

tion

th

e ac

cura

cy o

fP a

tm

ay b

e gr

eate

r by

usi

ng

the

follo

win

g eq

uat

ion

:

P at=

P s–

(Pp

+ P n

)

Wh

ere

:

P at=

tota

l an

nu

lus

pre

ssu

re lo

ss

No

te:

Thes

e p

ress

ure

s ex

ist

only

wh

en c

ircu

lati

ng

P n=

156

d ()Q

2

D2

n1

+D

2n

2+

D2

n3

()2


14·36

Hy

dro

sta

tic

Pre

ssu

re G

rad

ien

t:

Hyd

rost

atic

pre

ssu

re P

h=

0.05

2(d

)(L v

)

Hyd

rost

atic

pre

ssu

re g

rad

ien

t P h

/Lv

= 0.

052(

d)

Wh

ere

:

P h=

hyd

rost

atic

pre

ssu

re (p

si)

L v=

Tru

e V

erti

cal D

epth

(TV

D) (

ft)

d =

den

sity

(lb/

gal)

P h/L

v=

hyd

rost

atic

pre

ssu

re g

rad

ien

t (p

si/f

t)

Cir

cula

tin

g P

ress

ure

Gra

die

nt

(Bo

tto

mh

ole

):

Cir

cula

tin

g p

ress

ure

Pc

= P h

+ P a

t

Cir

cula

tin

g p

ress

ure

gra

die

nt

Wh

ere

:

P c=

circ

ula

tin

g p

ress

ure

(psi

)P c

/L =

cir

cula

tin

g p

ress

ure

gra

die

nt

(psi

/ft)

L m=

len

gth

(ft)

or

mea

sure

d d

epth

(ft)

(to

dep

th o

f in

tere

st)

P c L=

P h Lv

+P at L m


14·37

Av

era

ge

Pre

ssu

re L

oss

or

To

tal

An

nu

lar

Pre

ssu

re G

rad

ien

t:

The

pre

ssu

re lo

ss is

cal

cula

ted

for

each

sec

tion

ofan

nu

lus

and

th

e av

erag

e p

ress

ure

loss

can

be

calc

ula

ted

as

follo

ws:

P a/L

= p

ress

ure

gra

die

nt,

psi

/ft

L =

mea

sure

d d

epth

or

dep

th o

f in

tere

st, f

t

P at/

L m=

(Pa1

/L1)

L1

+ (P

a2/L

2) L

2+

(Pa3

/L3)

L3

...

L m

This

can

als

o be

cal

led

th

e to

tal a

nn

ula

rp

ress

ure

grad

ien

t:

P at=

tota

l an

nu

lus

pre

ssu

re lo

ssP a

t=

P a1

+ P a

2+

P a3

+. .

.+

P an

L m=

mea

sure

d d

epth

or

len

gth

of p

ipe


14·38

Po

we

r L

aw

Mo

de

l:τ

= Kγn

wh

ere

K a

nd

n a

re t

he

valu

es o

f in

tere

st

n =

flow

beh

avio

r in

dex

K =

con

sist

ency

ind

exτ

= sh

ear

stre

ssγ

= sh

ear

rate

For

600

and

300

rp

m r

ead

ings

:

Wh

ere

:n

p=

n fo

r p

ipe

Wh

ere

: K

p=

K fo

r p

ipe

Wh

ere

: n

a=

n fo

r an

nu

lus

Wh

ere

: R

3=

3 rp

m r

ead

ing

Wh

ere

: K

a=

K fo

r an

nu

lus

np

=3

.32

log

R60

0

R30

0

⎡ ⎣ ⎢ ⎤ ⎦ ⎥

Kp

=5.

1R

300

()

511

np

na

=0.

5lo

gR

300

R3

⎡ ⎣ ⎢ ⎤ ⎦ ⎥

Ka

=5.

1R

300

()

511

na


14·39

Rheo

logi

cal C

alcul

atio

ns fo

r No

n-Ne

wto

nian

Flui

dsB

ing

ha

m P

last

ic, E

ffe

ctiv

e V

isco

sity

in

Pip

e, a

nd

Eff

ect

ive

Vis

cosi

ty i

n A

nn

ulu

s:

Bin

gh

am

Pla

stic

PV =

R60

0–

R30

0(p

last

ic v

isco

sity

)Y

P =

R30

0–

PV (y

ield

poi

nt)

R60

0=

rheo

met

er r

ead

ing

at 6

00 r

pm

R30

0=

rheo

met

er r

ead

ing

at 3

00 r

pm

Eff

ect

ive

Vis

cosi

ty i

n P

ipe

:

Vp

= fl

uid

vel

ocit

y in

pip

e, ft

/sec

Eff

ect

ive

Vis

cosi

ty i

n A

nn

ulu

s:

Va

= fl

uid

vel

ocit

y in

th

e an

nu

lus,

ft/s

ecD

2=

ID o

f cas

ing

or o

ute

r an

nu

lus

wal

l (in

.)D

1=

OD

of t

ubi

ng

or in

ner

an

nu

lus

wal

l (in

.)

The

abov

e eq

uat

ion

s as

sum

e fl

ow in

pip

e to

be

at

a h

igh

er s

hea

r ra

te t

han

an

nu

lar

flow

.

µe

p=

100

Kp

96V

p()

ID

⎡ ⎣ ⎢ ⎢

⎤ ⎦ ⎥ ⎥ np

−1

µe

a=

100

Ka

144

Va()

D2

−D

1

⎡ ⎣ ⎢ ⎢

⎤ ⎦ ⎥ ⎥ na

−1


14·40

Capa

city a

nd D

isplac

emen

t Calc

ulat

ions

Thes

e fo

rmu

las

can

be

use

d t

o ca

lcu

late

th

eca

pac

ity

and

dis

pla

cem

ent

of a

ny

size

pip

e,an

nu

lus

or h

ole.

Ca

pa

city

of

Pip

e:

Ca

pa

city

of

An

nu

lus:

Cp

inb

bl/

100

ft=

ID2

10.2

94

Cp

inb

bl/

ft=

ID2

1029

.41

Cp

incu

ft/

ft=

ID2

183.

35

Ca

inb

bl/

100

ft=

D2()2

−D

1()2

10.2

94

Ca

inb

bl/

ft=

D2()2

−D

1()2

1029

.41

Ca

incu

ft/

ft=

D2()2

−D

1()2

183.

35


14·41

Ca

pa

city

of

Ho

le:

Ca

pa

city

of

Lin

ea

r ft

/bb

l:

Ch

inb

bl/

100

ft=

D ()2

10.2

94

Ch

inb

bl/

ft=

D ()2

1029

.41

Ch

incu

ft/

ft=

D ()2

183.

35

Cp

l=

1029

.41

ID2

=li

nea

rft

/b

bli

np

ipe

=18

3.35

ID2

=li

nea

rft

/cu

ftin

pip

e

Cal

=10

29.4

1

OD

2−

ID2

=li

nea

rft

/b

bli

nan

nu

lus

=18

3.3

5

OD

2−

ID2

=li

nea

rft

/cu

ftin

ann

ulu

s

Ch

l=

1029

.41

D2

=li

nea

rft

/b

bli

nh

ole

=18

3.35

D2

=li

nea

rft

/cu

ftin

hol

e


14·42

Op

gal/

stk

()=

cyli

nd

erca

pac

ity

×#

ofcy

lin

der

s×

%ef

fici

ency

100

Pum

p Out

put

Use

th

ese

form

ula

s in

con

jun

ctio

n w

ith

th

e p

um

p o

utp

ut

tabl

e to

det

erm

ine

pu

mp

ou

tpu

t.

No

te:

1. 1

str

oke

(stk

) = 1

com

ple

te c

ycle

2. D

oubl

e ac

tion

pu

mp

s lo

se t

he

rod

cap

acit

y du

rin

g ∑

of t

he

stro

ke.

3. C

ylin

der

an

d r

od c

apac

ity

is t

aken

from

th

e p

um

p o

utp

ut

tabl

e or

cal

cula

ted

by

usi

ng

the

form

ula

bel

ow.

Sin

gle

Act

ion

Pu

mp

s:


14·43

Do

ub

le A

ctio

n P

um

ps:

For

thes

e eq

uat

ion

s, #

of c

ylin

der

s is

: Du

ple

x =

2Tr

iple

x =

3Q

uin

tup

lex

=

Op

gal/

stk

()=

cyli

nd

erca

p.×

#of

cyld

rs×

2(

)−ro

dd

isp

l.×

#of

cyld

rs(

)[

]×%

effi

cien

cy10

0

Cy

lin

der

cap

acit

yor

rod

dis

pla

cem

ent

gal

()=

D2

l ()29

4.1

26


14·44

Pu

mp

Ou

tpu

t in

bb

l/m

in:

(bbl

/ft

take

n fr

om p

ipe

tabl

es)

Op

= p

um

p o

utp

ut,

gal

/stk

Q =

flow

rat

e, ft

/min

D =

dia

met

er, i

n.

l = c

ylin

der

or

rod

len

gth

, in

.

Op

bb

l/m

in(

)=O

p

gal

stk

⎛ ⎝ ⎜ ⎞ ⎠ ⎟ ×

stk

min

⎛ ⎝ ⎜ ⎞ ⎠ ⎟ ×

1b

bl

42ga

l

⎛ ⎝ ⎜ ⎞ ⎠ ⎟

Flow

rate

Q ()f

t/m

in(

)pip

eor

ann

ulu

s(

)=Q

=b

bl

min

⎛ ⎝ ⎜ ⎞ ⎠ ⎟ ×

ft bb

l

⎛ ⎝ ⎜ ⎞ ⎠ ⎟


14·45

H=

∆PK

A

1279

µQ

H=

∆PK

A2

1279

µQ

A+

4.6

3ρQ

2K

0.4

5

Darc

y’s Sa

nd H

eight

Calc

ulat

ion

for N

on-T

urbu

lent F

low

Wh

ere

:

H =

hei

ght

of fi

ll, ft

∆P

= fl

owin

g d

iffe

ren

tial

pre

ssu

reK

= g

rave

l per

mea

bili

ty, d

arci

esA

= c

ross

-sec

tion

al fl

ow a

rea,

ft2

µ =

flu

id v

isco

sity

, cp

Q =

flow

rat

e, b

bl/m

in

Forc

heim

er’s

Sand

Heig

ht C

alcul

atio

n fo

r Tur

bulen

t Flo

w

Wh

ere

:

H =

hei

ght

of fi

ll, ft

∆P

= fl

owin

g d

iffe

ren

tial

pre

ssu

reρ

= fl

uid

den

sity

, lb/

gal

K =

gra

vel p

erm

eabi

lity

, dar

cies

A =

cro

ss-s

ecti

onal

flow

are

a, ft

2

µ =

flu

id v

isco

sity

, cp

Q =

flow

rat

e, b

bl/m

in


14·46

Mu

ltip

lyB

yT

o O

bta

in

acre

s43

,560

squ

are

feet

(ft2 )

atm

osp

her

es14

.7p

oun

ds/

squ

are

inch

es (l

b/in

.2 )

barr

els

(U.S

. liq

uid

)31

.5ga

llon

s —

U.S

. liq

uid

(gal

)

barr

els

(oil

)42

gallo

ns

— o

il (g

al)

cen

tim

eter

s10

mil

lim

eter

s (m

m)

cen

tim

eter

s10

,000

mic

ron

s

cen

tim

eter

s1.

x 1

0–8an

gstr

om u

nit

s

cen

tim

eter

s of

mer

cury

0.44

61fe

et o

f wat

er (f

t)

cen

tim

eter

s of

mer

cury

0.19

34p

oun

ds/

squ

are

inch

(psi

)

cen

tip

oise

0.01

gr./

cen

tim

eter

s-se

con

d

cen

tip

oise

6.72

x 1

0–4p

oun

ds/

foot

-sec

ond

(lb/

ft-s

ec)

cubi

c ce

nti

met

ers

3.53

1 x

10–5

cubi

c fe

et (f

t3 )

cubi

c ce

nti

met

ers

0.06

102

cubi

c in

ches

(in

.3 )

Conv

ersio

ns an

d Tab

les

Con

tin

ues

on

nex

t p

age


14·47

Mu

ltip

lyB

yT

o O

bta

in

cubi

c ce

nti

met

ers

2.64

2 x

10–4

gallo

ns

— U

.S. l

iqu

id (g

al)

cubi

c ce

nti

met

ers

1.0

x 10

–3li

ters

(L)

cubi

c fe

et17

28cu

bic

inch

es (i

n.3 )

cubi

c fe

et0.

0283

2cu

bic

met

ers

(m3 )

cubi

c fe

et0.

0370

4cu

bic

yard

s

cubi

c fe

et7.

4805

2ga

llon

s —

U.S

. liq

uid

(gal

)

cubi

c fe

et28

.32

lite

rs (L

)

cubi

c fe

et/m

inu

te0.

1247

gallo

ns/

seco

nd

(gal

/sec

)

cubi

c fe

et/m

inu

te0.

472

lite

rs/s

econ

d (L

/sec

)

cubi

c m

eter

s35

.31

cubi

c fe

et (f

t3 )

cubi

c m

eter

s61

,023

cubi

c in

ches

(in

.3 )

cubi

c m

eter

s1.

308

cubi

c ya

rds

cubi

c m

eter

s26

4.2

gallo

ns

— U

.S. l

iqu

id (g

al)

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age


14·48

Mu

ltip

lyB

yT

o O

bta

in

cubi

c ya

rds

27cu

bic

feet

(ft3 )

cubi

c ya

rds

202

gallo

ns

— U

.S. l

iqu

id (g

al)

fath

oms

6.0

feet

(ft)

feet

30.4

8ce

nti

met

ers

(cm

)

feet

0.30

48m

eter

s (m

)

feet

/min

ute

0.01

667

feet

/sec

ond

(ft/

sec)

gallo

ns

3785

cubi

c ce

nti

met

ers

(cm

3 )

gallo

ns

0.13

37cu

bic

feet

(ft3 )

gallo

ns

231

cubi

c in

ches

(in

.3 )

gallo

ns

3.78

5 x

10–3

cubi

c m

eter

s (m

3 )

gallo

ns

3.78

5li

ters

(L)

gallo

ns

of w

ater

8.33

pou

nd

s of

wat

er (l

b)

gallo

ns/

min

ute

2.22

8 x

10–3

cubi

c fe

et/s

econ

d (f

t3 /se

c)

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age


14·49

Mu

ltip

lyB

yT

o O

bta

in

gallo

ns/

min

ute

8.02

08cu

bic

feet

/hou

r (f

t3 /h

r)

gram

s0.

0352

7ou

nce

s (o

z)

gram

s2.

205

x 10

–3p

oun

ds

(lb)

gram

s/cu

bic

cen

tim

eter

s62

.43

pou

nd

s/cu

bic

foot

(lb/

ft3 )

gram

s/cu

bic

cen

tim

eter

s0.

0361

3p

oun

ds/

cubi

c in

ches

(lb/

in.3 )

gram

s/li

ter

0.06

227

pou

nd

s/cu

bic

foot

(lb/

ft3 )

gram

s/sq

uar

e ce

nti

met

ers

2.04

81p

oun

ds/

squ

are

foot

(lb/

ft2 )

inch

es2.

54ce

nti

met

ers

(cm

)

inch

es o

f mer

cury

1.13

3fe

et o

f wat

er (f

t)

inch

es o

f mer

cury

0.49

12p

oun

ds/

squ

are

inch

(lb/

in.2 )

kilo

gram

s10

00gr

ams

(g)

kilo

gram

s2.

2046

pou

nd

s (l

b)

kilo

gram

s1.

102

x 10

–3to

ns

— s

hor

t (t

ons)

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age


14·50

Mu

ltip

lyB

yT

o O

bta

in

kilo

gram

s/cu

bic

met

er0.

0624

3p

oun

ds/

cubi

c ft

(lb/

ft3 )

kilo

gram

s/cu

bic

met

er3.

613

x 10

–5p

oun

ds/

cubi

c in

ch (l

b/in

.3 )

kilo

gram

s/sq

uar

e ce

nti

met

ers

2048

pou

nd

s/sq

uar

e fo

ot (l

b/ft

2 )

kilo

gram

s/sq

uar

e ce

nti

met

ers

14.2

2p

oun

ds/

squ

are

inch

(lb/

in.2 )

kilo

gram

s/sq

uar

e m

eter

0.20

48p

oun

ds/

squ

are

foot

(lb/

ft2 )

kilo

gram

s/sq

uar

e m

eter

1.42

2 x

10–3

pou

nd

s/sq

uar

e in

ch (l

b/in

.2 )

knot

s60

76fe

et/h

our

(ft/

hr)

knot

s1.

0n

auti

cal m

iles

/hou

r (m

ph

)

knot

s1.

151

stat

ute

mil

es/h

our

(mp

h)

lite

rs0.

2642

gallo

ns

— U

.S. l

iqu

id (g

al)

lite

rs1.

057

quar

ts —

U.S

. liq

uid

(qt)

lite

rs/m

inu

te5.

886

x 10

–4cu

bic

feet

/sec

ond

(ft3 /

sec)

lite

rs/m

inu

te4.

403

x 10

–3ga

llon

s/se

con

d (g

al/s

ec)

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age


14·51

Mu

ltip

lyB

yT

o O

bta

in

met

ers

3.28

1fe

et (f

t)

met

ers

1.0

x 10

–3ki

lom

eter

s (k

m)

met

ers

39.3

7in

ches

(in

.)

met

ers/

min

ute

3.28

1fe

et/m

inu

te (f

t/m

in)

met

ers/

min

ute

0.05

468

feet

/sec

ond

(ft/

sec)

met

ers/

min

ute

0.03

728

mil

es/h

our

(mp

h)

met

ers/

seco

nd

196.

8fe

et/m

inu

te (f

t/m

in)

met

ers/

seco

nd

3.28

1fe

et/s

econ

d (f

t/se

c)

mic

rom

icro

ns

1.0

x 10

–12

met

ers

(m)

mic

ron

s1.

0 x

10–6

met

ers

(m)

mil

es (n

auti

cal)

1.15

16m

iles

, sta

tute

mil

es (s

tatu

te)

5280

feet

(ft)

mil

es (s

tatu

te)

1609

met

ers

(m)

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age


14·52

Mu

ltip

lyB

yT

o O

bta

in

mil

lim

eter

s3.

281

x 10

–3fe

et (f

t)

mil

lim

eter

s0.

0393

7in

ches

(in

.)

oun

ces

28.3

49gr

ams

(g)

pp

mSG

mg/

L

pin

ts (l

iqu

id)

0.12

5ga

llon

s (g

al)

pin

ts (l

iqu

id)

0.47

32li

ters

(L)

pou

nd

s45

3.59

gram

s (g

)

pou

nd

s0.

4535

9ki

logr

ams

(kg)

pou

nd

s16

oun

ces

(oz)

pou

nd

s of

wat

er0.

0160

2cu

bic

feet

(ft3 )

pou

nd

s of

wat

er27

.68

cubi

c in

ches

(in

.3 )

pou

nd

s of

wat

er0.

1198

gallo

ns

(gal

)

pou

nd

s/cu

bic

feet

16.0

2ki

logr

ams/

cubi

c m

eter

(kg/

m3 )

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age


14·53

Mu

ltip

lyB

yT

o O

bta

in

pou

nd

s/cu

bic

inch

es17

28p

oun

ds/

cubi

c fe

et (l

b/ft

3 )

pou

nd

s/fo

ot1.

488

kilo

gram

s/m

eter

(kg/

m)

pou

nd

s/sq

uar

e fo

ot4.

882

kilo

gram

s/sq

uar

e m

eter

(kg/

m2 )

pou

nd

s/sq

uar

e fo

ot6.

944

x 10

–3p

oun

ds/

squ

are

inch

(lb/

in.2 )

pou

nd

s/sq

uar

e in

ches

2.30

7fe

et o

f wat

er (f

t)

pou

nd

s/sq

uar

e in

ches

2.03

6in

ches

of m

ercu

ry (i

n.)

pou

nd

s/sq

uar

e in

ches

703.

1ki

logr

ams/

squ

are

met

er (k

g/m

2 )

pou

nd

s/sq

uar

e in

ches

144

pou

nd

s/sq

uar

e fo

ot (l

b/ft

2 )

pou

nd

s/sq

uar

e in

ches

0.07

03ki

logr

ams/

squ

are

cen

tim

eter

s (k

g/cm

2 )

quar

ts (l

iqu

id)

0.25

gallo

ns

(gal

)

quar

ts (l

iqu

id)

0.94

63li

ters

(L)

rod

s16

.5fe

et (f

t)

squ

are

cen

tim

eter

s1.

076

x 10

–3sq

uar

e fe

et (f

t2 )

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age


14·54

Mu

ltip

lyB

yT

o O

bta

in

squ

are

cen

tim

eter

s0.

155

squ

are

inch

es (i

n.2 )

squ

are

cen

tim

eter

s1.

0 x

10–4

squ

are

met

ers

(m2 )

squ

are

feet

144

squ

are

inch

es (i

n.2 )

squ

are

feet

0.09

29sq

uar

e m

eter

s (m

2 )

squ

are

feet

0.11

11sq

uar

e ya

rds

squ

are

inch

es6.

944

x 10

–3sq

uar

e fe

et (f

t2 )

squ

are

met

ers

10.7

6sq

uar

e fe

et (f

t2 )

squ

are

met

ers

1550

squ

are

inch

es (i

n.2 )

squ

are

met

ers

1.19

6sq

uar

e ya

rds

squ

are

mil

es64

0ac

res

squ

are

mil

es2.

788

x 10

+7sq

uar

e fe

et (f

t2 )

squ

are

mil

lim

eter

s1.

076

x 10

–5sq

uar

e fe

et (f

t2 )

squ

are

mil

lim

eter

s1.

55 x

10–3

squ

are

inch

es (i

n.2 )

Con

tin

ues

on

nex

t p

age

Con

tin

ued

from

pre

viou

s p

age


14·55

Mu

ltip

lyB

yT

o O

bta

in

squ

are

yard

s2.

066

x 10

–4ac

res

squ

are

yard

s9.

0sq

uar

e fe

et (f

t2 )

squ

are

yard

s12

96sq

uar

e in

ches

(in

.2 )

squ

are

yard

s0.

8361

squ

are

met

ers

(m2 )

squ

are

yard

s3.

228

x 10

–7sq

uar

e m

iles

ton

s (lo

ng)

2240

pou

nd

s (l

b)

ton

s (m

etri

c)10

00ki

logr

ams

(kg)

ton

s (s

hor

t)90

7.18

kilo

gram

s (k

g)

ton

s (s

hor

t)20

00p

oun

ds

(lb)

ton

s (s

hor

t)24

30Po

un

ds

— t

roy

Con

tin

ued

from

pre

viou

s p

age

Chapter 15LIST OF PRODUCTS


15. L IST

OFPRODUCTS

LIST OF PRODUCTS

15·1

Clear Brine Systems

Ammonium Chloride (dry)Calcium Bromide/Calcium Chloride Brine SystemCalcium Bromide Brine SystemCalcium Bromide (dry)Calcium Bromide (liquid)Calcium Chloride Brine SystemCalcium Chloride (dry)Calcium Chloride (liquid)Cesium Formate (liquid)Cesium Formate/Potassium Formate Brine SystemCesium Formate/Potassium Formate/

Sodium Formate Brine SystemPotassium Chloride Brine SystemPotassium Chloride (dry)Potassium Formate Brine SystemPotassium Formate (dry)Sodium Bromide Brine SystemSodium Bromide (dry)Sodium Bromide (liquid)Sodium Bromide/Sodium Chloride Brine SystemSodium Chloride Brine SystemSodium Chloride (dry)Sodium Formate Brine SystemSodium Formate (dry)Zinc Bromide/Calcium Bromide (liquid)Zinc Bromide/Calcium Bromide/Calcium Chloride

Brine SystemCesium Formate Brine System

Reservoir Drill-In Fluids Systems

FLOPRO NT Minimal solids, non-damaging WB RDF system

FLOPRO SF Solids-free, non-damagingWB RDF system

FLOTHRU Organophilic filter-cake system

LIST OF PRODUCTS

15·2

DIPRO High-density, biopolymer-free, divalent brine RDFsystem

VERSAPRO Oil-base RDF systemVERSAPRO LS Low-solids oil-base RDF

systemNOVAPRO Synthetic olefin-base RDF

systemFAZEPRO Reversible invert-emulsion

RDF system

Reservoir Drill-In Fluids Products

DI-ANTIFOAM Antifoaming agent for theDIPRO system

DI-BALANCE Viscosifier for the DIPROsystem

DI-BOOST Secondary viscosifier for theDIPRO system

DI-INHIB Shale inhibitor for theDIPRO system

DI-TROL Filtration-control agent forthe DIPRO system

DUAL-FLO Fluid-loss additive for theFLOPRO NT system

DUAL-FLO HT Fluid-loss reducer for high-temperature applications

FAZE-MUL Emulsifier for FAZEPRO systemFAZE-WET Wetting agent for FAZEPRO

systemFLO-TROL Starch derivative filtration

control agent for FLOPRO NTsystem

FLO-VIS L Pre-dispersed, clarifiedxanthan gum solution

FLO-VIS NT Non-dispersable, non-clarified xanthan gum

FLO-VIS PLUS Premium clarified xanthanfor FLOPRO NT system

FLO-WATE Sized-salt weighting agentfor FLOPRO NT system

LIST OF PRODUCTS

15·3

K-52 Non-chloride potassiumsupplement for FLOPRO NTsystem

KLA-STOP Shale stabilizerKLA-GARD Shale stabilizerKLA-GARD B Salt-free shale stabilizerSAFE-CARB Ground marble weighting

agent

Breaker Systems

BREAKFREE Disperses FLOPRO NTfilter cake

BREAKDOWN Dissolves FLOPRO NTfilter cake

FAZEBREAK Disperses FAZEPRO filter cake

Breaker Products

D-SOLVER ChelantD-SOLVER PLUS ChelantD-SPERSE Surfactant-base dispersantWELLZYME A Enzyme breaker with biocide

for WB RDF fluidsWELLZYME NS Enzyme breaker meets North

Sea Environmental standardWELLZYME ME Enzyme breaker, Middle East

Displacement Chemicals

SAFE-SOLV OM Solvent for OBM andpipe-dope removal

SAFE-SOLV 148 Solvent for OBMSAFE-SOLV E Solvent for OBM and

pipe-dope removalSAFE-SURF E General-purpose

displacement surfactantSAFE-SURF NS General-purpose

displacement solvent/surfactant blend for North Sea

SAFE-SURF O Surfactant for OBMSAFE-SURF W Surfactant for WBM

LIST OF PRODUCTS

SAFE-SURF WN Water-base mud displacementsurfactant, North Sea

SAFE-T-PICKLE Pipe-dope solvent

Viscosifiers

DUO-VIS Xanthan gumDUO-VIS L Liquified xanthan gum,

non-clarifiedDUO-VIS PLUS NS Xanthan gum, non-

dispersible, non-clarifiedfor North Sea use

SAFE-LINK 110 Cross-linked cellulose polymerused to control brine losses

SAFE-LINK 140 Cross-linked cellulose polymerused to control high-densitybrine losses

SAFE-VIS Dry HECSAFE-VIS E Liquid HECSAFE-VIS LE Liquid HEC, North Sea versionSAFE-VIS HDE Liquid HEC for high-density

brinesSAFE-VIS OGS Specially formulated

liquid HEC

Corrosion Inhibitors

SAFE-COR Organic amine corrosioninhibitor

SAFE-COR C Organic amine corrosioninhibitor

SAFE-COR E Organic amine corrosioninhibitor

SAFE-COR HT High-temperature, thiocynatecorrosion inhibitor

SAFE-COR 220X Brine-soluble amide corrosioninhibitor

SAFE-SCAV CA Sulphur-free oxygenscavenger

SAFE-SCAV HS Zinc-free brine solubleH2S scavenger

SAFE-SCAV NA Oxygen scavenger

15·4

LIST OF PRODUCTS

Specialty Chemicals

FILTER FLOC FlocculantSAFE-BREAK CBF Emulsion preventer for

calcium-base brineSAFE-BREAK ZINC Emulsion preventer for zinc-

bromide brinesSAFE-BREAK 611 Emulsion preventer for

monovalent brinesSAFE-DFOAM Defoamer for brine systemsSAFE-FLOC II FlocculantSAFE-LUBE Water-soluble brine lubricantSAFE-SCAVITE Scale inhibitorGreencide 25G BiocideSTARGLIDE Lubricant for brine and

water-base RDFsSAFE-CIDE Triazine biocide, Eastern

Hemisphere onlyEMI-530 Temperature stabilizerPTS-200 Temperature stabilizer

Specialty Systems

SEAL-N-PEEL Removable fluid-losscontrol pill

SAFETHERM Insulating packer fluidSAFE-VIS HT LD High-temperature, HEC-base

fluid-loss pillFLO-DENSE AP Annular kill fluidFLOPRO CT Coiled-tubing

intervention fluid

15·5

THE PERIODIC TABLE OF ELEMENTS

79.9 Br e n i

m or B35

200.

6

Hg r u cr e

My

80

1.0 H

n e g or d y H 1

4.0 He m u i l e H

2

6.9 L

i m u i h t i L3

9.0 Be m u i l l yr e B 4

45.0 Sc m u i d n a c S 21

47.9 Ti

Tm u i n a t i

22

50.9 V

Vm u i d a n a

23

52.0 Cr m u i

m or h C 24

54.9 Mn e s e n a g n a

M 25

55.8 Fe n or I

26

58.9 Co t l a b o C

27

58.7 Ni l e k c i N

28

63.5 Cu r e p p o C

29

65.4 Zn c n i Z

30

10.8 B n or o B

5 27.0 Al m u i n i

m u l A 13 69.7 Ga m u i l l a G

31 114.

8 Inm u i d n I

49 204.

4 Tl m u i l l a h T

81

72.6 Ge m u i n a

mr e G 32 118.

7

Sn

Tn i

50 207.

2

Pb d a e L

82

74.9 As c i n e s r A

33 121.

8

Sb y n o

m i t n A 51 209.

0 Bi h t u

m s i B83

79.0 Se m u i n e l e S 34 12

7.6 Te T

m u i r u l l e52 (2

10)

Po m u i n o l o P 84

126.

9 I e n i d o I53 (2

10) At e n i t a t s A

85

28.1 Si n o c i l i S

14

31.0 P

s ur o h p s o h P 15

32.1 S

r u h p l u S16

12.0 C

n o b r a C6

14.0 N

n e g or t i N7

16.0 O

n e g y x O8

19.0 F e n i r o u l F

9 35.5 Cl e n i r o l h C

17

39.9 Ar n o gr A

18 83.8 Kr n o t p yr K

36 131.

3

Xe n o n e X

54 (222

)

Rn n o d a R

8620.2 Ne n o e N

10

88.9 Y m u i r t t Y

39

91.2 Zr m u i n o cr i Z 40

92.9 Nb m u i b o i N

41

95.9

o M

m u n e d b y l o M 42

(99) Tc T

m u i t e n h c e 43

101.

1

Ru m u i n e h t u R 44

102.

9

Rh m u i d o h R

45

106.

4

Pd m u i d a l l a P 46

107.

9

Ag r e v l i S

47

112.

4

Cd m u i

m d a C 4813

8.9

La m u n a h t n a L 57

178.

5 Hf m u i n f a H

72

181.

0 Ta Tm u l a t n a

73

183.

9 W Tn e t s g n u

74

186.

2

Re m u i n e h R

75

190.

2

Os m u i

m s O76

192.

2 Ir m u i d i r I77

(227

)

Ac m u i n i t c A 89

(261

) Rf

r e h t u Rr o f

m u i d10

4

(262

)

Db m u i n b u D 10

5

(263

) g S

r o b a e Sm u i g

106

(262

)

Bh m u i r h o B

107

(265

)

Hs m u i s s a H

108

(266

)

Mt m u i r e n t i e

M 109

195.

1 Pt m u n i t a l P

78

197.

0

Au d l o G

79

23.0 Na m u i d o S

11

24.3 Mg m u i s e n g a

M 1239

.1 Km u i s s a t o P 19

40.1 Ca m u i c l a C

2085

.5 Rb m u i d i b u R 37

87.6 Sr m u i t n or t S 38

132.

9

Cs m u i s e a C

55

137.

3

Ba m u i r a B

56(2

23) Fr m u i c n a r F 87

(226

)

Ra m u i d a R

88

* †

2

34

56

78

910

1112

1314

1516

17

181

Rel

ativ

e at

omic

mas

s

Key

Tho

se n

umbe

rs a

ppea

ring

with

in b

rack

ets

are

the

mas

s nu

mbe

rs o

f com

mon

isot

opes

Tho

se e

lem

ents

und

erlin

ed a

re r

adio

activ

e

Nel

emen

t is

a ga

s

Hg

elem

ent i

s a

liqui

d

at r

oom

tem

pera

ture

and

pre

ssur

e

Li

elem

ent i

s a

solid

Sym

bol

Ato

mic

num

ber

}

1 2 3 4 5 6 7

Con

tin

ues

on

nex

t p

age

THE PERIODIC TABLE OF ELEMENTS

H

140.

1

Ce m u i r e C

58

140.

9 Pr m u i m y d o e s a r P 59

232.

0

Th m u i r o h T

90

(231

)

Pa

r Pm u i n i t c a t o

91

144.

2

Nd m u i m y d o e N 60 23

8.1 U m u i n a r U

92

(147

) m P r Pm u i h t e

m o61 (2

37)

Np m u i n u t p e N 93

150.

4 m Sm u i r a

m a S 62 (244

) u P

m u i n o t u l P 94

152.

0 u E

m u i p or u E 63 (243

) m A

m u i c i r e m A 95

157.

3 d G

m u i n i l o d a G 64 (247

) m C

m u i r u C96

158.

9 b T Tm u i b r e

65 (247

) k B

m u i l e k r e B 97

162.

5

Dy m u i s or p s y D 66 (2

51) f

C r o f i l a Cm u i n

98

164.

9 o H

m u i m l o H 67 (2

52) s E

m u i n i e t s n i E 99

167.

3 r E

m u i b r E68 (2

57) m F r e F

m u i m

100

168.

9 m Tm u i l u h T

69 (258

) d M

m u i v e l e d n e M 10

1

173.

0 b Y

m u i b r e t t Y 70 (259

) o N

m u i l e b o N 102

175.

0 u Lm u i t e t u L

71 (260

) r L r w a L

m u i c n e10

3He

NO

F Cl

Ar

Kr

Xe

Rn

Ne

N

*58

-71

Lan

than

ide

seri

es

†90

-103

Act

inid

e se

ries

Con

tin

ued

from

pre

viou

s p

age

NOTICE

The information and data contained herein andall interpretations and/or recommendationsmade in connection therewith, whether writ-ten herein or elsewhere, or presented orally,have been carefully prepared and considered. Itmust be understood, however, that in additionto the necessity for relying on facts and sup-porting services furnished by others, there aremany variable well conditions of and overwhich M-I SWACO can have no knowledge orcontrol. Therefore, the information and dataand all interpretations and/or recommen-dations made in connection therewith are pre-sented solely as a guide, for the user’sconsideration, investigation and verification,and no warranties of any kind, express orimplied, are made in connection therewith. Inthese premises and in consideration thereof,any user of such information, data, interpreta-tions and/or recommendations agrees toindemnify and save harmless M-I SWACO fromall claims and actions for loss, damages, deathor injury, to persons or property, including,without limitation, subsurface damage, subsur-face trespass, or injury to the well or reservoir,allegedly, based on or arising out of use of same,whether or not such claims or actions are basedupon the purported negligence of M-I SWACO inthe preparation of furnishing the same.

The user’s agreement to indemnify and saveharmless M-I SWACO hereunder shall apply infavor of all its affiliates, subsidiaries, branchesand divisions, as well as to any contributionhereto to whom it or they may be liable in theabsence of this notice.

©2005 M-I L.L.C. All rights reserved. CMC.0306.0605.R1 (E) 1M Litho in U.S.A.

P.O. Box 42842Houston, Texas 77242-2842

Tel: 281·561·1300Fax: 281·561·1441

www.miswaco.comE-mail: [email protected]

Technology Centers:

HOUSTON, TEXASTel: 281·561·1300 · Fax: 281·561·1441

ABERDEEN, SCOTLANDTel: 44·1224·334634 · Fax: 44·1224·334650

STAVANGER, NORWAYTel: 47·51·577300 · Fax: 47·51·570605

This information is supplied solely for informational purposes and M-I SWACO makes noguarantees or warranties, either expressed or implied, with respect to the accuracy and useof this data. All product warranties and guarantees shall be governed by the Standard Termsof Sale. Nothing in this document is legal advice or is a substitute for competent legal advice.

completion fluids manual

Documents

true crystallization

calcium bromide

dry calcium

mixing dry

mixing cabr2

calcium bromide

mixing dry

calcium chloride