PNG 451 Lab Manual 2012

LABORATORY MANUAL FOR DRILLING FLUIDS

AND CEMENTS AND RIG FLOOR SIMULATION

PNG 451 – OIL WELL DRILLING LABORATORY

Petroleum and Natural Gas Engineering

The Pennsylvania State University

9th Edition, 2010

Copyrighted @ 2010 PSU

FIELD TESTING OF DRILLING FLUIDS

INTRODUCTION

Every drill operation depends directly upon the properties of the drilling fluid. The properties

of the drilling fluid should be such as to promote safe and speedy drilling and completion of the

well with the maximum productive capacity. The use of drilling muds of controlled properties

frequently requires considerable sums of money. These expenditures must be justified and it is

well to examine the role of the drilling fluid to determine its necessary properties. The general

functions of a drilling fluid are:

1. Cooling and lubricates the bit and drill pipe.

2. Removing cuttings from the hole.

3. Preventing settling of cuttings in the hole when circulation stops and allowing dropping

of cuttings in the surface circulating system.

4. Depositing an impermeable wall cake.

5. Overcoming formation pressures to prevent influx of oil, gas, or water.

6. Preventing caving of the formation.

7. Preventing contamination of the producing formation.

8. Allowing good electric logs to be taken.

9. Reducing casting and cementing costs.

10. Preventing drill pipe corrosion.

Of all the mud systems in use today, the fresh water type is the basic, most universally used

mud system. The remaining mud systems have been developed to overcome drilling conditions

which fresh water muds have difficulty in handling or for which they are totally unfitted.

However, as we shall see, it is probably impossible for any one mud system to satisfy all the

necessary functions of a drilling fluid. Consequently, the choice of mud type for a specific

instance is governed by those functions which are the most critical to the well in question, and

some sacrifice of other desirable properties must be made.

Prepared as a guide, this section first discusses field tests that evaluate drilling fluids,

especially muds, by measuring certain properties of the drilling fluid and its filtrate. To associate

these tests more closely with drilling conditions, the significance of each test as a factor of

proper mud control, and, in turn, the importance of mud control to successful drilling, are

pointed out briefly. Second, this section details a series of experiments to help the student better

understand drilling muds.

2

TEST PROCEDURES

DENSITY (Mud Weight)

It is extremely important that the density of the drilling mud be known throughout the

drilling operation. This is true whether drilling through gas, oil, or saltwater sands; shale, where

relatively high density may be required; or into low pressure production zones, where low

density colloidal mud is advantageous. Frequent density tests aid in preserving a safety factor by

disclosing any changes taking place in the unit weight of the mud. The most practical instrument

for measuring mud density is the Mud Balance.

Mud Balance

The Mud Balance provides a simple method for the accurate determination of mud density.

Durably constructed, it consists principally of a base and graduated arm with cup, lid, knife edge,

rider, level, and counterweight.

Procedure:

1. Remove lid and fill cup to the top with sample to be tested. (When testing mud, first

remove air and other gases from sample using the Baroid Mud Dearator.)

2. Replace lid and rotate until firmly seated, making sure some sample squeezes out the vent

hole.

3. Wipe sample from exterior of balance.

4. Place balance on base with knife edges on fulcrum rest.

5. Move rider until instrument is in balance, as determined by level.

6. Read sample density at end of rider nearest fulcrum.

Results:

The instrument must first be calibrated by using distilled water as the sample. After

measuring the density of the water, dry the cup and then measure the density of the mud.

Calculate the true mud density (corrected for balance error) using the following formula:

densitymudTrue

densitymud

waterdistilledofdensityTrue

waterdistilledof MeasureddensityMeasured =

The density of distilled water is 8.33 pounds/gallon or 62.4 pounds/cubic foot.

(Alternately, balance error of the Mud Balance can be eliminated by adding or removing lead

shot from the counterweight.)

In most parts of the world mud weight is expressed in pounds per gallon (ppg). In California,

3

many companies use pounds per cubic foot.

VISCOSITY

Viscosity is a measure of the internal resistance of a fluid to flow: the greater the resistance,

the higher the viscosity. For drilling operations, viscosity of mud must be controlled and a

standard means of measuring viscosity provided. Hole size, hole condition, pumping rate,

drilling rate, cutting size, cavings, presence or absence of shale separators, mud weight, design of

the pit systems, and gel characteristics of the mud are factors influencing the specification of the

viscosity of any given mud.

The development of satisfactory instruments for measuring the viscosity of drilling muds has

been the subject of much effort. This is due largely to the fact that drilling fluids are

fundamentally thixotropic and the viscosity characteristics of such materials cannot be described

by means of a single measurement. The indicated viscosity as obtained on any instrument is valid

only for that rate of shear and will differ when measured at a different rate of shear. Two

instruments for determining will be described: the Marsh Funnel Viscosimeter and the Baroid

Rheometer (which is similar in operation to a Fann V-G Meter.)

Marsh Funnel Viscosimeter

The Marsh Funnel Viscosimeter is used for routine viscosity determinations on nearly every

drilling rig. The measurement obtained is influenced considerably by rate of gelation and by

density which varies the hydrostatic head of the column of mud in the funnel. Because of these

4

variations, the viscosities obtained with the Marsh Funnel cannot be correlated directly with

those found using rotational viscosimeters. Marsh Funnel viscosities are of little quantitative use

but have general comparative value.

Procedure:

1. Hold funnel in upright position with index finger over outlet. (Instead of holding funnel,

it may be placed in a ring stand.)

2. Pour the test sample freshly taken from the mud system, through the screen in top of

funnel until mud level just reaches the underside of the screen. (The funnel now contains

1500 cc of mud.)

3. Immediately remove finger from outlet tube and measure number of seconds for one

quart (946 cc) of the sample to run out. This time in seconds is recorded as the Marsh

Funnel Viscosity of the mud. Also report the temperature of the sample.

Baroid Rheometer

The Baroid Rheometer is a rotational viscosimeter with which one, two, or multiple point

viscosities. Its fixed speeds of 3 (GEL), 100, 200, 300, and 600 RPM are switch selectable with

the RPM knob. In addition, the same switch, when set to the VAR position, enables the operator

to select any speed between 3 and 625 RPM by annually adjusting the VARIABLE knob.

Procedure:

1. Place a recently agitated sample in the mud cup, and tilt the instrument head into the

field. Adjust the head with the knurled knob until the rotor sleeve is immersed to the

scribed line.

2. Stir the sample for about 15 seconds at 600 RPM.

5

3. Read the meter deflection at the following RPM’s: 3 (GEL), 10, 25, 50, 75, 100, 200,

300, and 600. (NOTE: The meter whose deflection is to be read is labeled VISCOSITY.

This label is incorrect. The meter deflection indicates shear stress; to calculate viscosity,

see below.)

Results:

1. The plastic viscosity (PV), in cp, is calculated by:

Plastic Viscosity Pµ=!"!= 300600

2. The apparent viscosity at each RPM, in cp, is calculated by:

Apparent Viscosity A

RPMµ=!# 300300=

3. The Bingham yield point (YP), in pounds/100 square feet, is calculated by:

Bingham Yield Point Pµ"!300=

4. Plot vs. RPM, as shown in Gatlin.

SHEAR OR GEL STRENGTH

The gel strength of drilling muds is a measure of the minimum shearing stress necessary to

produce slip wise movement. Two readings are generally taken: the first, immediately after

agitation of the mud in the cup; the second, after the mud in the cup has been quiescent for a

period of ten minutes. The readings are referred to as the initial gel strength and the ten - minute

gel strength, respectively. Both gel strength readings so determined will be zero for non-

thixotropic fluids, such as water and brines, no matter how viscous but the difference in the

readings may be appreciable for suspensions such as drilling muds. The difference is considered

to be a measurement of the thixotropic of the mud system. Hole size, type of formations, depth,

temperature and pressure of formation fluids or gases, and amount of weight material in the mud

are factors that must be considered in prescribing desirable gel-strength properties of the mud.

The Marsh Funnel has been used to some degree to obtain a measure of the gel strength of

muds. In making the gel strength test the viscosity time in seconds is first determined with

minimum delay between filling the funnel and making the measurement as described previously.

The funnel is then refilled and allowed to stand quiet for ten minutes, after which the

viscosity is again measured. The time difference in seconds between the first and second

measurements gives the gel strength in seconds. This method is not recommended and is given

largely for historical reference. The Baroid Rheometer is commonly used to measure gel

strength.

6

Baroid Rheometer

Procedure:

1. Stir a sample at 600 RPM for about 15 seconds.

2. Turn the RPM knob to STOP; allow the desired rest time (10 seconds for ten second Gel

strength; 10 minutes for ten minutes Gel strength) and then turn.

3. Switch the RPM knob to the GEL position; the maximum deflection of the dial before the

gel breaks is the Gel strength in pounds/100 square feet.

FILTRATION PROPERTIES

The filtration properties of drilling muds are a measure of the ability of the solid components

of the muds to form a thin, low-permeability filter cake. The lower the permeability, the thinner

the filter cake and the lower the volume of filtrate from muds of comparable solids

concentration. This property is dependent upon the amount and physical state of the colloidal

material in the mud. It has been shown repeatedly in the field that when mud of sufficient

colloidal content is used, drilling difficulties are minimized. In contrast, a mud low in colloids

and high in inert solids deposits a thick filter cake on the walls of the hole. A thick filter cake

restricts the passage of tools and allows an excessive amount of filtrate to pass into the

formation, thus providing a potential cause of caving and differential pressure wall sticking.

Lack of proper walling properties may result in further trouble such as difficulty in running

casing, creating a swabbing effect which may cause the formation to cave or swab reservoir

contents into the hole, and difficulty in securing a water shutoff because of channeling of

7

cement. The filtration properties will be studied with two pieces of equipment: The Filter press

and the Mud Sticking Tester.

Filter Press

The filtration, water loss, or wall building test is conduced with a Filter press. The test

consists of measuring the rate at which filtrate (the continuous liquid phase of the mud) is forced

from the sample under a specified pressure of 100 psig. Both the filtrate volume (ml) and the

mud cake thickness (32nd

of an inch) are reported. The Filter Press consists of a mud reservoir

mounted on a frame, a filtering medium, a means of catching and measuring the filtrate, and

provisions for a pressure source. The filtering medium is a sheet of especially hardened filter

paper which fits on a screen in the base cap.

Procedure:

1. Assemble the following dry pans in this order: base cap, screen, a sheet of filter paper,

rubber gasket, and cell. Secure the cell to the base cap.

2. Fill the cell with the sample to be tested to within ¼ “ of the top. Set the unit in place in

the filter press frame. Check the top cap to make sure the gasket is in place. Place the top

cap on the cell and secure the unit in place with the T-screw.

3. Place a dry graduated cylinder under the filtrate tube.

4. With the regulator T-screw in its maximum outward position (closed position), open the

valve to the cell. Apply a pressure of 100-psig to the filter cell by rapidly screwing the

regulator T-screw into the regulator. Timing of the test should begin now.

5. Record the initial filtrate loss; then record the filtrate loss every minute for the first 7.5

minutes (also record the loss at 7.5 minutes); then record the loss at 10, 15, 20, 25, and 30

minutes (end of test).

6. Close the valve to the cell rapidly and open the safety-bleeder valve. Return the regulator

T-screw to its maximum outward position.

Results:

1. Plot filtrate volume vs. square root of time (as shown in Gatlin, p.74). Determine the

collected 30 minutes filter loss.

2. The filter cake thickness is determined after the cell has been disassembled. The filter

paper with the cake deposited on it is removed from the base cap, and excess mud is

gently washed from the cake with a gentle stream of water. The filter cake thickness is

measured and reported in thirty-seconds of an inch.

3. Properties of the filter cake such as texture, hardness, flexibility, etc., may be reported.

8

Mud Sticking Tester

The sticking tendency of a mud filter cake is measured with the Baroid Mud Sticking Tester.

The torque required to free a steel disk in contact with a mud filter cake is measured and used in

the calculation of the “sticking coefficient.” The sticking coefficient is an indication of the force

required to rotate (or free) a section of drill pipe in contact with the wall cake in the borehole.

The sticking coefficient can be used to evaluate the cake lubricity of various muds.

Procedure:

1. Start with a clean apparatus. Be especially sure that the torque plate is clean, Scour the

face of the plate with abrasive cleanser until the plate shines and rinse thoroughly with

water. Then dry carefully.

2. Place filter paper, rubber gasket, the slip ring on screen inside chamber. Screw hold-down

ring over gaskets, using ring wrench.

3. Insert threaded end of one of the valve stems into bottom center hole of cell and turn

hand tight.

4. Fill cell with mud sample to the scribed line.

5. Set cell on stand mating the four tips into stand holes.

6. Slip torque plate stem through lid with polished surface facing up looking at inside of lid.

7. Put lid onto cell with stem of torque plate standing up through “O” ringed center hole of

9

lid. Tighten cell lid with Spanner Wrench, using torque plate level for a backup.

8. Insert the other valve stem in cell lid and tighten hand tight (closing valve).

9. Set CO2 assembly over top end of valve stem and insert locking pin.

10. Turn relief valve on CO2 assembly to closed position. Back out regulator handle.

11. Insert CO2 cartridge into knurled CO2 holder, and tighten holder onto head puncturing

cartridge.

12. Place graduate under cell and turn lower valve stem a quarter turn back from hand tight,

thus opening the valve.

13. Turn regulator handle in until 500 psi is read gage.

14. Pull plate stem up and hold there while opening top valve stem by turning stem a quarter

turn back from hand tight.

15. Record the time for the start of test.

16. Allow the mud to filter to desired cake thickness or filtrate volume, then push torque

plate down using the torque plate lever. To do this, catch the groove in the bar in the

column top cross support and hold plate down until pressures equalize allowing plate to

stick.

17. Record filtrate volume and time.

18. Allow plate to stick for 5 minutes or more. Put socket on torque wrench. Zero dial on

torque wrench. Place the torque wrench and socket on the hex top of the torque plate

stem, and measure the torque wrench while watching dial. With free hand, for a backup,

use the torque plate level wedged between columns above cell platform.

19. Record set time (i.e. plate sticking time), filtrate volume, and maximum torque.

20. Repeat steps 18 and 19 for additional readings.

21. Back off regulator handle and then open bleed-off valve.

22. Pull pin, remove CO2 assembly and remove top valve stem. Loosen cell lid with Spanner

Wrench, unscrew lid, and pour mud out of cell.

23. Disassemble apparatus and wash thoroughly, being careful not to scratch the torque plate.

Results:

1. The sticking coefficient is the ratio of the force necessary to initiate sliding of the plate to

the normal force on the plate, and is given by:

10

Sticking Coefficient PA

T

##5.1=

where: T = maximum torque, in inch-pounds.

A = plate area, in square inches.

P = differential pressure, in psi

For this instrument, A = 3.14 in2and P = 500 psi (as specified in step 13).

2.Plot sticking coefficient versus set time.

HYDROGEN ION CONCENTRATION

The degree of acidity or alkalinity of drilling mud is indicated by the hydrogen ion

concentration that is commonly expressed in terms of pH. The hydrogen ion concentration of a

drilling mud exerts considerable influence on its properties and hence is of interest to the

petroleum engineer. pH control is also important in corrosion control, usually pH is kept above

10 for this reason.

Water dissociates slightly into hydrogen ions and hydroxyl ions. It can be shown that at a

given temperature the product of the concentrations of these ions is a constant. That is:

(H+) (OH

-) = K = l x 10

-14(at 25 C)

In pure water the concentrations of these two ions are equal and each is 10-7

moles per liter.

The addition of an acid will increase the concentration of hydrogen ions with a corresponding

decrease in hydroxyl ion concentration. Thus, if a water solution contains one mole per liter of

hydrogen ions, then the hydroxyl ion concentration must be 10-14

moles per liter by the above

expression for the dissociation of water. Conversely if the solution is made basic there will be a

corresponding decrease in hydrogen ion concentration. The product of the two ion

concentrations will, however, remain constant. The pH of a solution is a measure of its hydrogen

ion concentration. pH is defined as:

pH ( )++ "=©

℘= HH

log1

log

Thus in pure water ( H+) = (OH

-) = 10

-7 and the pH is 7. A solution containing one mole of

hydrogen ion per liter would have (H+) = l and the pH is 0.

The pH measurement is used as an aid in determining the need for chemical control of the

mud as well as indicating the presence of contaminants such as cement, gypsum, etc. The

opening pH for any drilling muds is commonly measured with an electronic pH Meter.

11

pH Meter

The electromatic hydrogen ion determination offers a fast, accurate determination of pH. The

operation of these meters involves the generation of an electric potential in a glass and calomel

electrode system by the solution under test. The electrical potential is amplified by means of a

vacuum-tube system and the reading is indicated directly on a meter.

Procedure:

1. Check battery by turning selector to BAT CK.

2. Turn selector to STANDBY position. Selector must be kept in this position while rinsing,

removing, or inserting electrodes to prevent damage to delicate electronic components.

3. Remove plastic end cap and soak electrode in distilled water a few minutes, then wipe

with soft tissue.

4. Add sufficient buffer solution to a test tube to cover the electrode when inserted (use

buffer of pH in range expected of mud pH). Insert electrode.

5. Set temperature knob to the solution temperature.

6. Turn selector to READ, IMPORTANT, Do not electrode in your hand while taking

reading. Remove hand at least 12 inches away. Local radio transmission and electric

fields often conduct through the human body and cause shifts in readings.

7. Set meter to pH of buffer with STANDARIZE knob.

8. Turn selector to STANDBY. Note: By noting reading in this position, electronics drift

can be compensated by bringing the meter back to this reading with STANDARDIZE

knob, thus avoiding frequent buffering.

9. Remove electrode and rinse with distilled water.

10. Insert electrode into solution to be tested.

11. Turn selector to READ.

12. Stir carefully to assure fresh solution. Wait adequate time for a steady reading. Make sure

temperature knob is set correctly. Remove hand from electrode before reading.

13. Turn selector to STANDBY = = before removing electrode from solution.

14. To run next sample, repeat steps 9 through 11.

15. When finished, turn selector to OFF. Rinse electrode in distilled water and wipe clean

with soft tissue.

16. Before storing, wet electrode with a few drops of pH 7 buffer and replace plastic

protector.

12

RESISTIVITY

Control of the resistivity of a mud and mud filtrate while drilling may be desirable to permit

better evaluation of formation characteristics from electric logs. A salt mud (low resistivity) will

prevent the obtaining of a good, definitive SP curve. The determination of resistivity is

essentially the measurement of resistance to flow of electrical current through a known

configuration of a sample. Measured resistance is converted to resistivity by use of a cell

constant. The cell constant is fixed by the configuration of the sample in the cell and is

determined by calibration with standard solutions of known resistivity. The resistivity is

expressed in ohm-meters.

Any type of cell and instrument which is sufficiently accurate to permit determination of

resistivity within five percent of the correct value may be used. If the instrument indicates the

sample resistance in ohms, the cell constant must be known. The resistivity in ohm-meters is

obtained by multiplying the resistance in ohms by the cell constant in square meters per meter. If

the instrument is a type of direct-reading resistivity meter, the cell constant has been adjusted to

a particular value or accounted for in the circuitry of the meter. Such an instrument measures the

sample resistance and converts it to the resistivity so that the reading is taken directly in ohm-

meters.

Baroid Resistivity Meter

The Baroid Resistivity Meter is a transistorized electrical meter for measuring the resistivity

of fluids, slurries, or semi-solids having resistivities of 0.01 to 10 ohmmeters. (The instrument

reads directly in ohm-meters.) Conductivity of the medium being measured is obtained by taking

the reciprocal of the resistivity measurement.

13

Procedure: Filtrate and Mud

1. Fill cell with fluid, being careful to remove all air bubbles (fill and exhaust fluid two or

three times to thoroughly wet the surface).

2. Connect cell to the meter.

3. Press the black button and adjust for full scale reading on the meter.

4. While keeping the black button depressed, press the red button.

5. The reading on the meter is the resistivity of the fluid. (When testing mud, it may be

necessary to allow 3 to 5 minutes after putting mud in the cell before taking a reading to

allot the cell and mud to reach temperature equilibrium.)

6. Record the resistivity reading and the cell temperature.

7. Remove the cell and clean with distilled water. (Pipe cleaners can be used to remove mud

that cannot be flushed out with water.)

Procedure: Mud Cake

1. Remove excess water from filter cake.

2. Fill the slot on top of the cell with mud cake.

3. Press black button and adjust for full scale.

4. While keeping the black button depressed, press red button.

5. The reading on the meter is the resistivity of the mud cake.

6. Record the resistivity of the mud cake and the cell temperature.

7. Remove the cell and clean thoroughly with distilled water.

14

Note:

1. Use only fresh or distilled water (mild soaps only when necessary) to clean the cell. Do

not use any type of solvent. Do not scratch the inner surface of the cell when using a pipe

cleaner.

2. When full-scale reading cannot be obtained when the black button is depressed, the

battery needs to be replaced. Use a 22.5 V Burgess U-15 or equivalent. Be sure to

observe polarity when replacing the battery in order to prevent damage to the transistor.

15

FIELD TESTING OF OIL WELL CEMENTS

INTRODUCTION

The discovery of Portland cement dates back to 1824 when Joseph Aspdin, an English

mason, was issued a patent covering gray, rock-like material called “cement”. This cement was

produced by feeding a finely ground mixture of limestone, clay, into a rotating kiln at 2600 F. As

this mixture traveled through the kiln it was convened into cement clinker. The clinker was then

stored in bins and later ground with gypsum (retarded setting time and added strength) to form

the final cement.

It was not until the early 1900’s, through, that the use of cement in oil well operations was

introduced. In 1903, Frank F. Hill used a cement slurry to shut off down-hole water just above an

oil sand in the Lompoc field in California. Since that time no other production operation has

played as important a role in the producing life of an oil well.

Basically, oil-well cementing is a process of mixing a cement-water slurry and pumping

down steel casing to critical points located in the annulus around the casing, in the open hole

below or in fractured formations. This operation is referred to as primary cementing. Its main

functions are to (1) support the casing, (2) seal off non-productive formations, and (3) retard

corrosion by minimizing casing contact with saline formation waters.

Secondary cementing deals with completion and remedial repairs on a well after the

producing zone is reached. Squeeze-cementing, the most common form of secondary cementing,

involves applying hydraulic pressure to force or “squeeze” a cement slurry in contact with a

formation, either in open hole or through perforations in the casing. By squeezing cement at

given depths (1) hydrocarbon producing zones can be segregated from those formations

producing other fluids, (2) casing leaks can be repaired or, (3) thief zones sealed.

In oil-field practices cement is exposed to an infinite variety of environments; therefore,

cements with various qualities are needed. To provide for these growing needs the American

Petroleum Institute annually produces a list of cements, API Standards 10A, Specifications for

Oil-Cements and Cement Additives for manufactures and users. They are listed in the API

Standards 10A dated April 1977 as follows:

Class A: Intended for use from surface to 6,000 ft (1830 m) depth when special properties

are not required. Available only in ordinary type.

Class B: Intended for use from surface to 6,000 ft (1830 m) depth when conditions require

moderate to high sulfate-resistance. Available in both moderate and high sulfate-resistant types.

Class C: Intended for use from surface to 6,000 ft (1830 m) depth when conditions require

high early strength. Available in ordinary and moderate and high sulfate-resistant types.

Class D: Intended for use from 6,000 ft to 10,000 ft (1830 m to 3050 m) depth under

16

conditions of moderately high temperatures and pressures. Available in both moderate and high

sulfate-resistance types.

Class E: Intended for use from 10,000 ft to 14,000 ft (3050 m to 4270 m) depth under

conditions of high temperatures and pressures. Available in both moderate and high sulfate-

resistant types.

Class F: Intended for use from 10,000 ft to 16,000 ft (3050 m to 4880 m) depth under

conditions of extremely high temperatures and pressures. Available in both moderate and high

sulfate-resistant types.

Class G: Intended for use as a basic cement from surface to 8,000 ft (2440 m) depth as

manufactured, or can be used with accelerators and retarders to cover a wide range of well

depths and temperatures. No additions other than calcium sulfate or water, or both, shall be

interground or blended with the clinker during manufacture of Class G cement. Available in

moderate and high sulfate-resistance types.

Class H: Intended for use as a basic cement from surface to 8,000 ft (2440 m) depth as

manufactured, and can be used with accelerators and retarders to cover a wide range of well

depths and temperatures. No addition other than calcium sulfate or water, or both, shall be

interground or blended with the clinker during manufacture of Class H cement. Available in

moderate and high (Tentative) sulfate-resistant types.

Class J: Intended for use as manufactured from 12,000 ft to 16,000 ft (3650 m to 4880 m)

depth under conditions of extremely high temperatures and pressures or can be used with

accelerators and retarders to cover a range of well depths and temperatures. No additions of

retarder other than calcium sulfate, or water, or both, shall be interground or blended with the

clinker during manufacture of Class J cement.

Although the API lists nine different classes of cement, only five (A, B, C, G, H) are

available from manufacturers in the United States. These five cements with the addition of

chemicals called additives (see Appendix B) can change cement properties to meet most well

conditions. Class G and H cements are very similar and are the most commonly used. G is used

in California and H in the Gulf Coast Areas.

As in our discussion of drilling fluids, we will first examine field test that evaluates critical

properties of oil field cements. These tests are outlined for standardization in API RP 10B. Then,

several experiments are presented to expose the student to the measurement of such properties as

compressive strength, thickening time, etc. and their role in providing adequate cement control.

17

TEST PROCEDURES

WATER CONTENT OF SLURRY

Water is added to cement to make the slurry pumpable and provide for hydration (the

chemical reaction), although only 25.0 % water by weight of cement may be needed for

hydration, normal water content is higher to provide for pumpability.

Minimum and maximum water content values are determined for given cement in the

following manner.

Minimum Water Content

The minimum amount of water for any class of cement is defined as that amount of which

can be used without producing a slurry of consistency greater than 3O Uc2 as measured by a

consistometer (the consistometer operation is described in the section labeled Thickening Time).

If less than the minimum amount of water is used, the friction in the annulus plus the hydrostatic

pressure may be high enough to break down weak formations. In addition, since the water-

cement ratio is low, the loss of a small amount of water to thief zones or tubing leaks may cause

the cement to set prematurely. On the other hand, it may be necessary to use the minimum water

content where maximum slurry weight or strength is required or to control lost circulation.

*All cement additives are given as a percent of the dry cement weight.

Procedure:

1. The required quantity of water shall be placed in the Waring blender at slow speed and

the cement sample added.

2. After all the cement has been added to the water, cover the container and stir at high

speed for 35 seconds.

3. Pour the slurry immediately into the atmospheric consistometer and stir at 80F for a

period of 20 minutes, at which time the consistency shall be recorded.

4. Several runs with various water contents should be made and plotted to determine the

amount of water at which a consistency of 30 Uc is obtained and, therefore, the minimum

water content.

Maximum Water Content

The maximum water content is defined as that quantity of water that can be mixed with a

given cement without causing the separation of more than 2.5 ml of free-floating water when the

slurry is allowed to stand for 2 hours at room temperature in a 250 ml graduate. If more than the

maximum amount of water is used, cement particles will settle out of the slurry to the extent that

free-water pockets and low-strength cement will exist within the cement column. The maximum

2Universal consistency units (Uc) are dimensionless units formerly referred to as “poises”.

18

water content should never be exceeded unless bentonite gel or a similar material is blended with

the cement to tie up excess water.

Procedure:

1. Prepare cement slurry as previously described.

2. Pour the slurry immediately into an atmospheric consistometer and stir at 80 ºF for 20

minutes.

3. Then remix the slurry an additional 35 seconds at high speed.

4. Fill a 250 ml graduate cylinder with slurry, seal with a rubber stopper, and let stand for 2

hours.

5. Remove the supernatant water developed by standing with a pipette and measure in a

graduated cylinder.

6. Several runs with various water contents should be made and plotted to determine which

water content yields 2.5 ml of free water on standing 2 hours. This is the maximum water

content for the tested cement.

DENSITY

The density of cement slurry is, except for squeeze jobs, slightly heavier than the mud in the

hole. This minimizes chances of either a blowout or lost circulation occurring during cementing

and aids in removing drilling mud from the hole.

The density can be controlled by the amount of water (between minimum and maximum

stated above) added to the slurry. In addition, for lower densities -10.8 to 16.5 lb/gal, materials

that “hold” large volumes of water such as bentonite, diatomaceous earth or expanded perlite are

often used. For greater densities 15.6 to 22 lb/gal, weighting materials such as hematite and

barite are commonly used.

In field operations, slurry density is customarily monitored with a standard mud balance.

Automated weighting devices, however, fitted into the discharge line between the mixing unit

and the wellhead, give a more uniform weight record and are becoming an accepted practice.

Mud Balance

The Mud Balance provides a simple method for the accurate determination of mud density.

Durably constructed, it consists principally of a base and graduated arm with cup, lid, knife edge,

rider, level, and counterweight.

19

Procedure:

1. Remove lid and fill cup to the top with sample to be tested. Puddle the sample 25 times

with a glass rod to remove entrapped air.

2. Replace lid and rotate until firmly seated, making sure some sample squeezes out the vent

hole.

3. Wipe sample from exterior of balance.

4. Place balance on base with knife edges on fulcrum rest.

5. Move rider until instrument is in balance, as determined by level.

6. Read sample density at end of rider nearest fulcrum.

Results:

The instrument must first be calibrated by using distilled water as the sample. After

measuring the density of the water, dry the cup and then measure the density of the mud.

Calculate the true mud density (corrected for balance error) using the following formula:

densitymudTrue

densitymud

waterdistilledofdensityTrue

waterdistilledof MeasureddensityMeasured =

The density of distilled water is 8.33 pounds/gallon or 62.4 pounds/cubic foot. (Alternately,

balance error of the Mud Balance can be eliminated by adding or removing lead shot from the

counterweight.)

STRENGTH TESTS

One major performance criterion of oil-well cement is in its strength. Cement must (1) secure

and support easing in the hole, (2) set quickly to reduce rig waiting on cement (WOC) time, and

(3) withstand the shock of continued drilling and perforating.

There is no universal agreement on strength requirements for oil-well cements; however, it is

generally accepted in the industry that a compressive strength of 500 psi is adequate for most

operations. Three variables - cement type, temperature, and pressure - affect the setting time and

ultimate compressive strength. Since temperature and pressure of the well are predetermined we

must alter the cement’s composition to minimize WOC time yet provide adequate strength.

Early strength is increased with the addition of accelerators such as calcium chloride,

ammonium chloride and ‘minimum water’. In hot or high pressure formations it may be useful to

retard the cement’s setting time with lignosulfonate, CMHEC, and “maximum” water. But also

in high temperature formations, cement compositions may retrogress (lose strength) after

reaching a high value.

20

Cements containing retarders for high temperature applications seem particularly subject to

strength retrogression. Although remaining compressive strength may be adequate for many

applications, the addition of 35% silica flour to the slurry provides a way to maintain

compressive strength.

Versa Tester

The Versa Tester is a hydraulic loading apparatus which compresses cement specimens until

they fail (fracture). Unlike the machines used in sophisticated testing which load specimens

mechanically at a constant rate (1000-4000 psi/min) you must hand load specimens in the Versa

Tester. When adding pressure to your specimens take care to load the samples slowly. Also note

that reliable strength tests depend upon careful observance of all specified requirements and

procedures. Improper centering of specimens in the Versa Tester can result in oblique fractures

yielding low-strength results.

Procedure: 3

1. Prepare the cement slurry to be tested as previously described.

2. Place the slurry in the lightly greased molds and puddle each mold.25 times.

3. After pudding, remove the excess slurry from the top of each mold using a straightedge.

4. Specimens can be cured at atmospheric temperature or in an oven for periods of 8, 24, 48

and 72 hours.

5. When samples are to be tested at ages of less than 24 hours, remove the samples from the

oven approximately 30 minutes before testing.

6. Set the sample to be tested on the Versa Tester platform centered under the hydraulic

piston.

7. Close the valve on the hydraulic pump and lower the piston onto the sample.

8. Add pressure slowly onto the sample by pumping and record the maximum pressure.

Have another person watch the gauge as you load the sample. (It will return to 0 pounds

when the sample fails). Note: the gauge reads pounds and you must convert to psi by

dividing by the average cement cross-sectional area.

( ) topofAreabottomofArea2

1area +=Average

Results:

The compressive strength (psi) of the sample tested is measured as the maximum pressure

prior to failure on the Versa Tester. Strengths of 500 psi are normally necessary prior to

returning to drilling operations. By measuring strengths at various times the WOC can be

estimated.

3Always wear eye protection when testing cement’s compressive strength.

21

THICKENNING TIME

Cement slurry must remain pumpable until it is in place, within some margin of error. This

limit of pumpability i.e. thickening time is defined as when the slurry reaches a viscosity of 100

poises.

Thickening time is a function of both temperature and pressure as shown below.

It must be established to ensure adequate pumping time for slurry placement. Avoid cements

with excessive thickening times to prevent; delays in resuming drilling operations, settling and

separation of cement slurry components, formation of free-water, pockets, loss of hydrostatic

head and gas cutting.

Consistometer

Thickening time is measured using a pressurized or atmospheric (our model) consistometer.

As the apparatus applies heat and pressure to the slurry, simulating cement flow in a well, a

continuous consistency measurement is recorded as a strip chart. The limit of pumpability is

reached when the torque on the paddle in the slurry cup reaches 100 Uc. Please note that these

measurements are made in metal vessels which prevent any fluid loss. Your time valves will be

higher than they might be opposite a permeable zone, after partial dehydration.

Procedure:

Care shall be taken to see that the apparatus is clean. After each test the inside of the cell and

the paddles, particularly the outside edges should be cleaned and brushed. Surfaces that come in

contact with the slurry shall be given a thin coating of waterproof grease or light oil before each

test.

1. Fill the bath with water. Place the empty cells in the water bath and bring the bath to the

testing temperature. After the bath has reached this temperature set the heat control and

turn the switch to low.

2. Test the paddle for excessive friction by running the cylinder assembled, but without

cement inside, for a few minutes. If the paddle is bent to such an extent that it rubs on the

side, an appreciable movement will be shown by the indicator. The two bearings in the

slurry indicating lid should be checked periodically for excessive friction. These defects,

if found, should be corrected before starting additional tests.

3. With the paddle out, fill each cylinder of the consistometer with 500 cc (the line scribed

the cylinder). Some space has been left between the scribed line the lid for increased

volume when the paddle is inserted in the cylinder and when the slurry is heated. The

slurry is poured into the cylinder, the paddle inserted, and the lid put on, being careful

that the slotted shaft engages the pin in the lid, The cylinder is then placed in the

consistometer, and the viscosity (Uc) is read on the scale. The scale is divided into 10

units, with each division representing 10 Units of Consistency. A reading of 3 would be

30 Units of Slurry Consistency, etc.

22

4. Start the motor and a stop watch and take readings every 10 minutes for the first hour and

at every 30 minutes thereafter until the cement starts to stiffen.

5. When either sample has reached a consistency of 70 Uc, turn off the motor and remove

the cylinder for cleaning, if the other cement slurry has not started to set, the test may be

continued with only one cell in place.

6. BE CERTAIN THAT EACH CELL IS CLEANED IMMEDIATELY AFTER IT IS

REMOVED.

Observe the following precautions:

1. Watch the indicators during a test run. Do not allow the cement to remain in the

containers after a consistency of 10 has been reached.

2. Check and clean the bearings before each test.

3. Watch the temperature control.

4. Never turn the heater on unless the bath is fitted with water.

5. Cover the water surface with a film of oil to prevent rusting.

6. Do not mix parts. Each container is a separate unit.

7. Remove the cement immediately after removing the cylinder.

8. Never use force or pry the gears when placing a cylinder.

9. Do not clean the cylinders or paddles with acid.

10. Slide the cylinder bracket out, place the cylinder, and push forward to engage the gears.

11. Be sure that the end of the thermometer is submerged.

12. Be sure that the pointers read zero before starting the test.

13. Be sure that the indicator cord lies on the outside circumference of the cylinder top.

Results:

The results of tests are read directly from the indicator and no calculations are necessary so

long as the machine is in calibration. However, the consistency readings may be plotted on

common graph paper with the consistency as the ordinate and time as the abscissa.

The general shape of the consistency-time curve plotted as described above presents an

excellent picture of a particular cement as far as its setting characteristics are concerned. A visual

comparison of the curves of several cements will usually disclose characteristic differences with

regard to a particular cementing application.

There are certain features common to all consistency-time curves. The cement slurry

generally has a fairly low initial consistency. As stirring is continued, this value usually drops a

little more. It then begins to increase at very gradual rate. However, as time goes on, the rate of

23

increase of consistency is accelerated to such an extent that the latter part of the curve is quite

steep. This acceleration varies with different cements and with different testing temperatures.

From the standpoint of the majority of oil-well cementing requirements, a proper cement

slurry should reveal the following characteristics on a consistency curve produced with a

Halliburton Consistometer at temperatures corresponding to well conditions.

1. Initial consistency between 10 and 30 Uc (Units of Consistency)

2. Consistency to remain below 40 Uc for 3 hours from time of introductions into

consistometer.

3. Sharp break toward higher consistency after 3 hours.

4. Tangent to curve should be practically vertical when curve reaches consistency of 100

Uc. This feature is indicative of the rapidity with which the cement will develop strength

after initial set.

Note:

It is understood that units of measurement of viscosity should properly apply only to true

fluids, and that a cement slurry is not a true fluid; however, the effective resistance to flow

offered by a cement slurry can be conveniently measured by a Halliburton Consistometer and,

hence, the advantage of expressing the consistency of a cement slurry in terms of Units of

Consistency (Uc)

FLUID LOSS

The water loss of neat cement is extremely high. Consequently, when a slurry contacts a

porous formation from which the mud cake has been removed, it may quickly become

dehydrated and undergo a flash set. This problem is common in cementing deep liners and in

squeeze cementing.

In the 1960’s, significant progress was made in developing cement additives that lower fluid

loss with a high molecular weight, synthetic polymer but these additives are usually affected by

temperature. Generally, thickening time is retarded and, at low temperature, this retardation may

have to be offset by accelerators. Bentonite and CMHEC are also used to reduce filtrate loss.

Cement Filter Press

To measure filtrate characteristics of cement slurries, the API specifies a standardized 30-

minute test at 100 psi.

The API procedure employs a filter assembly consisting of a frame, a cylinder, and a 325-

mesh screen supported by a 60-mesh screen as the filtration medium. The heating jacket makes it

possible to simulate formation temperatures.

24

Procedure:

1. The filter press cylinder shall be filled with the cement to be tested, capped, and secured

in the frame.

2. Place a dry graduated cylinder under the drain tube to receive the filtrate.

3. Close the relief valve and pressure the system to 100 psi with the gas supplied.

4. Timed from the initial pressure application, filtrate readings shall be taken at ¼, ½, 1, 2,

and 5 minutes and thereafter at 5-minutes intervals until 30 minutes have elapsed.

5. If dehydration occurs before the end of the 30-minutes test period, the time required to

dehydrate the sample shall be observed.

6. Release the pressure on the filter pressure and clean with water making sure the screen is

properly washed.

Results:

The API filter loss of all cement slurries without additives is high-in excess of 1,000 ml.

When all the filtrate is received in the test cell in less than 30 minutes, the following equation is

used to calculate the hypothetical 30-minute fluid-loss valve.

t477.5

30 tFF =

where F30 = quantity of filtrate in 30 minutes

Ft = quantity of filtrate at time t.

t = time in minutes

Cement slurries having laboratory fluid-loss values of 50 to 150 ml in 30 minutes are

commonly used in squeeze cementing. In cementing deep liners, the API filter loss may be as

high as 300 ml.

PERMEABILITY

Although in designing cement slurries only slight emphasis is given to the permeability of set

cement, there are means of measuring it for both water and gas. The API has specified a standard

system that involves the use of a permeameter, which we will not use in this course.

Set cements have very low permeabilities - much lower, in fact, than those of most producing

formations. Data have shown that at temperatures less than 200 F the permeability of cement

decreases with age and temperature. After 7 days of curing, the permeability is usually too low to

measure.

The permeability of set cement to gas is normally higher than to water, but measurements of

25

the former are less reliable because it is difficult to obtain good representative samples for

measuring gas flow. Cements that have set for 3 to 7 days have a gas permeability of less than

0.1 md. Dolomite and limestone have an average of 2 to 3 md and oolitic limestones usually

have a very low permeability. Sandstone has gas permeability ranging from 0.1 to 2,000 md.

Silica flour, besides inhibiting strength retrogression, also reduces the permeability of set

cements. For example, cements cured at 350 F displayed a permeability of 1 md but with the

addition of 35% silica flour was reduced to less than 0.001 md.

RHEOLOGICAL PROPERTIES

A common cause of failure in primary cementing is incomplete displacement of drilling

muds, which can leave vertical, mud filled channels of cement. This mud may be displaced later

under producing conditions to create open channels that permit formation fluids to migrate

upward behind the casing.

Two basic forces are associated with drilling and displacement during primary cementing.

They are differential pressure and cement-on-mud (fluid-on-fluid) drag forces. To effectively

displace muds, oil well cements must exert a combination of differential pressure and drag forces

of sufficient magnitude to overcome forces resisting displacement.

Mud and oil well cement slurries being non-Newtonian in nature (viscosity changes with

shear rate) has led to several mathematical models beings used in predicting flow properties and

interrelationships of such muds and cements. The Bingham Plastic Model and the Power Law

Model are most commonly used. The former has been utilized since the mid-1940’s, power Law

Model Equations - presented in the late 1950’s - are more generally used than those of the

Bingham Model and will be presented here. Such models attempt to describe the relationship of

shear rate and shear stress for muds and slurries. Extremely useful in analyzing the displacement

process, they are not precise techniques and should be used only as an indicator to acceptable

displacement conditions.

Baroid Rheometer

The Baroid Rheometer is used to measure the consistency index (K) and flow behavior index

(n) of cements. Field models have two speeds to develop shear rate to 300 and 600 rpm, while

our lab model has constant variation from 0 to 600 rpm.

Procedure:

1. Prepare the prescribed slurry in the Waring Blender in accordance with the previous

procedure described in the section titled Minimum Water Content.

2. The cement shall then be stirred at slow speed for a period of 10 minutes.

3. Transfer slurry to sample cup with minimum time lag. With rotor turning at 600 rpm,

26

place rotor into the cup containing the slurry up to the level at the designated line on the

sleeve.

4. The initial reading at 600 rpm shall be taken 60 seconds after continuous rotation. Then

lower the rotor speed to 300 rpm, rotate for 60 seconds and read.

Remove the sample and clean rheometer with water.

Results:

The pressure at any point in the well bore is the sum of the hydrostatic pressure and the

frictional pressure. The hydrostatic pressure is the pressure exerted on the formations, casings,

and down-hole equipment by the weight of the fluid or fluids above them, Friction pressure is

generated by the resistance of the fluids to the movement.

P = Ph + Pf

where: P = Total pressure at any point in the well bore

Ph = hydrostatic pressure

Pf = friction pressure

The hydrostatic pressure is: Ph = 0.052 L

Where: Ph = hydrostatic pressure, psi

= fluid density, lb/gal

L = length of the fluid column, ft (vertical depth)

The friction pressure is not easy to calculate since it depends on the rheological behavior of

the fluid as it is exposed to shear caused by pumping. For general purposes, the following

calculation approach to friction pressure is perhaps appropriate. It assumes that the cement slurry

behaves as a power-law fluid.

Calculate the flow-characteristic parameters by using the equations:

N = (3.32) log10 (600-rpm reading/300-rpm reading)

K = (1.0660 (300-rpm reading)/[(100) (511)n]

To determine friction pressure, calculate the Reynolds number, NRe, from the following

equations:

For annulus:

NRe = (547) (dw – do)n (Q)

2-n ( )/[(1,647)

n (dw

2– do

2)

2-n (K)]

For casing:

NRe = (547) (Q)2-n

( )/[(1 ,647)n (di)

4-3n (K)]

where Q = Pumping rate, bbl/min

= Fluid density, lb/gal

di = Casing ID, in.

27

dw = Hole diameter, in.

do = Casing OD, in.

Nre = Reynolds number, dimensionless.

Using the n-valve and Reynolds number, estimate a friction factor from the figure above.

Friction pressure is then determined by:

For casing:

Pfc = (11.5) (L) ( ) (Q2) (f)/di

5

For annulus:

Pfa = (11.5) (L) ( ) (Q2) (f)/[dw-do) (dw

2– do

2)

2]

where: f = Friction factor, dimensionless

Pfc = Friction pressure in casing, psi

Pfa = Friction pressure in annulus, psi

Notice that the above calculations must be performed for every fluid using the corresponding

n, K, and . Also, the L’s will be different for each both inside and outside the casing.

Pressure: Once all the individual hydrostatic and friction pressures are calculated for each

fluid in the casing and annulus, the total hydrostatic and frictional pressures for the casing and

annulus can be calculated by simple addition. Next, the surface and bottom-hole pressures can be

calculated:

Ps = Pf + Pa - Pc

PB = Pfa + Pa

where: Ps = Surface pumping pressure, psi.

PB = Bottom hole, circulating pressure, psi

Pa = Total hydrostatic pressure in annulus, psi

Pc = Total hydrostatic pressure in casing, psi

Pf = Total friction pressure (casing and annulus), psi

Hydraulic horsepower: The following equation can be used to calculate the hydraulic

horsepower needed to circulate the well at the given rate:

Hhp = 0.0245 (Ps) (Q)

where: Hhp = Hydraulic horsepower

Ps = Surface pumping pressure, psi

Q = Pump rate, bbl/min

Turbulent flow rate: Cement placement under turbulent flow conditions is an effective

technique for achieving a good cement job. The pumping rate for turbulent flow may be

determined from the following procedure.

28

First, determine n and k for the cement slurry as outlined above. Then determine the upper

critical Reynolds number for turbulent flow, from the friction-factor chart (notice that the upper

critical Reynolds number changes with n, and varies from about 2,900 to 3,500. A good average

number is 3,000).

Calculate the turbulent flow rate from the equation:

Q2-n

= (NRe) (1,647)n (dw

2– do

2)

2-n(k)/[(547) (dw – do)

n ( )]

Where: Q = Flow rate, bbl/min

NRe = Reynolds number, dimensionless

n = Fluid-flow behavior index, dimensionless

K = Fluid consistency index, lb-sec/sq ft

dw = Diameter of well bore, in.

do = 0D of casing, in

The value obtained for Q is the minimum rate at which the cement must be pumped to

achieve turbulent flow.

29


Laboratory Experiment No. 1

Properties of Fresh Water Muds

Object:

Become familiar with the mud testing apparatus and procedures by investigating the

properties of fresh water muds.

Theory:

Certain clay mineral, when ground to colloidal size and contacted with water, readily hydrate

(adsorb water) to form stable colloids. Different clay minerals have different abilities to adsorb

water. The more water adsorbed by the clay, the higher the viscosity of the resulting mud will be.

In general, simple water-clay systems are suitable for shallow or upper hole drilling in areas

where contaminating beds are not a problem. Unfortunately, fresh water muds are easily subject

to contamination and the muds develop objectionable properties (as we shall see in later

experiments).

Procedure:

Each group of the lab section will test different drilling mud clays. Description of clay types

is included in Appendix A. The lab instructor will prepare the muds for you in the following

manner:

1. Add the required amount of clay to the required amount of fresh (distilled) water.

2. Stir 10 minutes with the mixer

3. Age the mud overnight.

GROUP MUD NAMEMUD 1

(gr. clay/cc water)

MUD 2

(gr. clay/cc water)

1 Aquagel* 50/1000 100/1000

2 Zeogel* 50/1000 100/1000

3 Quick-Gel* 25/1000 50/1000

*These materials are Baroid trade names. Their functions are described in Appendix A.

Each group will test their two muds for the following properties using the equipment and

procedures described in the previous section:

1. Density (Mud Balance).

2. Marsh Funnel viscosity (Marsh Funnel).

3. Apparent viscosity, plastic viscosity, yield point, 10-sec gel strength, 10-min gel strength

(Baroid Rheometer).

30

4. Fluid loss, mud cake thickness (Filter Press).

5. pH (Litmus Paper).

6. Mud, mud filtrate, and mud cake resistivity (Resistivity Meter).

Note the following:

1. Blend mud for 5 minutes before making first test.

2. Return the sample to the sample container after measuring each property EXCEPT fluid

loss and re-stir it by hand.

3. Perform the fluid loss test LAST.

4. For Mud 1, do complete 30-min filtration test. For Mud 2, do a 7.5-min filtration test and

report the corrected 30-min loss.

Results:

1) Tabulate the following mud properties:

a) Mud density (ppg).

b) Apparent viscosity (cp) @ 10, 50, 100, 200, 300, and 600 RPM.

c) Plastic viscosity (cp).

d) Yield point (lbs/100 sq. ft.).

e) 10-sec gel strength (lbs/100 sq. ft.).

f) 10-min gel strength (lbs/100 sq. ft.).

g) pH.

h) Corrected 30-min fluid loss (ml).

i) Filter cake thickness (in.).

j) Mud resistivity (ohm-m).

k) Mud filtrate resistivity (ohm-m).

l) Mud cake resistivity (ohm-m).

2) Plot the following mud properties vs. % of clay in the mud:


b) Hastic viscosity (cp).

c) Yield point (lbs/l00 sq.ft.).

d) 10-min gel strength (lbs/100 sq.ft.).

e) Corrected 30-min fluid loss (ml).

3) Summarize the results of doing the following experiments:

a) Increasing the concentration of general purpose bentonite clay in a fresh water-based mud

(Group 1).

b) Increasing the concentration of high-yield bentonite clay in a fresh water-based mud

(Group 2).

c) Increasing the concentration of attapulgite clay in a fresh water-based mud (Group 3).

4) Compare the results of using general purpose bentonite clay, high-yield bentonite clay, and

attapulgite clay to build a fresh water-based mud.

31



Effects of Sodium Salts on Fresh Water Muds

Object:

To investigate the effects of salt on fresh water muds and to evaluate aids in overcoming the

adverse effects caused by salt contamination.

Theory:

Clay particles dispersed in water are in the form of sheets which possess electrical charges

(unsatisfied valences). The presence of these charges gives fresh water muds their excellent

viscous, thixotropic, and filtration properties. Salt concentrations, however, neutralize the

electric charges and cause flocculation (formation of particle aggregates which are larger than

colloidal size) of the clay particles. As a result, the mud may be valueless for its usual functions.

Salt contamination can be due to two different factors, each having different effects on the

mud. First, formations containing salt water are frequently encountered in the drilling of wells. If

the mud weight is too low, salt water intrusion may occur with adverse effects on the mud

viscosity. In some wells salt formations are encountered either as beds or salt plugs. Second, salt

contamination may be due to the presence of salt in the water used to mix the mud (especially

true when sea water is used). Whatever the reason, contamination of mud by salt is a frequent

phenomenon and the full effect of this compound is of considerable importance.

Procedure:

Your lab instructor has prepared the muds for you in the following manner:

Group 1

Mud 1: Add 50.0 gr. of Aquagel to 1000.0 cc of water, stir with mixer for 10 minutes, age mud

overnight.

Mud 2: Dissolve 10.0 gr. of sodium chloride (NaCl) in 990.0 cc of water to make a 1.0 % salt

solution, add 50.0 gr. of Aquagel and stir with mixer for 10 minutes. Age mud

overnight.

Mud 3: Dissolve 50.0 gr. of NaCl in 950.0 cc of water to make a 5.0 % salt solution, add 50.0 gr.

of Aquagel. Proceed as in Mud 2/Group 1.

Mud 4: Dissolve 150 gr. of NaCl in 850 cc of water to make a 15.0 % salt solution. Add 50.0 gr.

of Aquagel. Proceed as in Mud 2/Group 1.

32

Group 2

Mud 1: Same as Mud 1/Group 1.

Mud 2: Add 50.0 gr. Aquagel to 990.0 cc of water, stir with mixer for 10 minutes. Add 10.0 gr.

of sodium chloride (NaC1) and stir with mixer for 10 minutes. Age mud overnight.

Mud 3: Proceed as in Mud 2/Group 2 but use 50.0 gr. of Aquagel, 950.0 cc of water and 50.0 gr.

of NaC1.

Mud 4: Proceed as in Mud 2/Group 2 but use 50.0 gr. of Aquagel, 850.0 cc of water and 150 gr.

of NaCl.

Group 3


Mud 2: Dissolve 50.0 gr. of sodium chloride (NaC1) in 950.0 cc of water to make a 5.0 % salt

solution. Add 50.0 gr. of Aquagel, 6.0 gr. of Q-Broxin* and stir with mixer for 10

minutes. Age mud overnight.

Mud 3: Proceed as in Mud 2/Group 3 but use 50.0 gr. of NaCl, 950.0 cc of water, 50.0 gr. of

Aquagel and 6.0 gr. of Impermex*.

Mud 4: Proceed as in Mud 2/Group 3 but use 50.0 gr. of NaCl, 950.0 cc of water, 50.0 gr. of

Aquagel and 6.0 gr. of Loloss*.

*Description included in Appendix A.

Each group will test their 4 muds for the following properties:


2. Apparent viscosity, plastic viscosity, yield point, 10-sec gel strength, 10-min gel strength

(Baroid Rheometer).

3. Fluid loss, mud cake thickness (Filter Press).


5. Mud, mud filtrate, and mud cake resistivity (Resistivity Meter).

Note the following:


2. Return the sample to the sample container after each test and re-stir it by hand.


4. Do a 7.5-min filtration test and report the corrected 30-min loss.

33

Results:



b) Plastic viscosity (cp).

c) Yield point (lbs/100 sq. ft.).

d) 10-sec gel strength (lbs/100 sq. ft.).

e) 10-min gel strength (lbs/100 sq. ft.).

f) pH.

g) Corrected 30-min fluid loss (ml).

h) Filter cake thickness (in.).

i) Mud resistivity (ohm-m).

j) Mud filtrate resistivity (ohm-m).

2) Plot the following mud properties vs. % of NaCl (Group 1), % of NaCl (Group 2), and % of

Additive (Group 3):

a) Plastic viscosity (cp)

b) Yield point (lbs/l00 sq. ft.).

c) 10-sec gel strength (lbs/l00 sq. ft.).

d) 10-min gel strength (lbs/100 sq.ft.).


f) Mud resistivity (ohm-m)

g) Mud filtrate resistivity (ohm-m)


a) Increasing the salt contamination of fresh water muds due to salt in the mixing water

(Group 1).

b) Increasing the salt contamination of fresh water muds due to salt encountered in the

borehole (Group 2).

c) Adding viscosity and filtration control agents to salt contaminated mud (Group 3).

4) Compare the results of salt contamination in fresh water muds due to salt in the mixing water

due to salt encountered in the borehole.

34



Viscosity Reducing Agents

Object:

Evaluate the performance of several mud thinners.

Theory:

Viscosity reducing agents are necessary to the handling of water-based muds. Fresh water-

based muds normally contain bentonite clay for the purpose of developing desirable viscous and

low fluid loss properties. High concentrations of clay compounds, other low-specific-gravity

solids such as drill cuttings, or soluble salts may be responsible for undesirable mud viscosity,

gel strength, and fluid loss in fresh water-based mud systems.

The problem of calcium contamination can frequently be handled successfully through the

use of chemical agents who precipitate the contaminant and restore satisfactory properties to the

mud. High viscosity, gel strength, and fluid loss caused by non-precipitable salts such as NaCl or

by excess concentrations of solids may be treated by diluting the mud with water (reduces both

salt and solids concentrations) or by mechanical methods (reduces solids concentration only).

These actions, however, also result in a decrease in both the Bentonite concentration and mud

weight. Therefore, Bentonite usually has to be added back to the mud to restore desired

rheological and fluid loss properties and weighting material usually has to be added back to the

mud to restore required density. Such treatment is often unsatisfactory or uneconomical and

other means are frequently used to obtain a reduction in viscosity, gel strength, and fluid loss

without requiring the supplementary use of Bentonite and weighting material.

An alternative to water dilution and mechanical separation is treatment with viscosity

reducing agents. A viscosity reducing agent, usually very expensive, may be defined as any

additive to water-based muds capable of reducing viscosity and gel strength by means other than

dilution or precipitation of the agent responsible for the abnormal viscosity. This definition

eliminates water as a viscosity reducer although it is frequently the most advantageous and the

least expensive agent to use and is sometimes the only additive which will give the required

effect. This definition also eliminates such compounds as sodium bicarbonate, soda ash, barium

carbonate, etc., which all reduce mud viscosity by precipitating calcium or by regulating the mud

pH.

The chemicals which have been found effective as viscosity reducers consist of a relatively

narrow set of compounds. Practically, they are the molecularly dehydrated phosphates and

polyphosphates, the plant tannins, the lignosulfonate wood by-products, and the mineral lignins.

The ability of viscosity reducers is strictly limited and their addition to the mud above the

low concentrations required for particle saturation will not result in further viscosity reduction. In

35

fact, often the reserve is true and viscosity increases.

Procedure:

Your lab instructor has prepared the muds for you in the following manner:

Group 1

Mud 1: Add 50.0 gr. of Aquagel to 600.0 cc of water and stir with mixer for 10 minutes. Age

mud overnight.

Mud 2: Add 50.0 gr. of Aquagel to 600.0 cc of water, stir with mixer for 10 minutes. Add 0.4 gr.

of CC-16* and stir with mixer for 10 minutes. Age mud overnight.

Mud 3: Proceed as in Mud 2/Group 1 but use 1.0 gr. of CC-16.

Mud 4: Proceed as in Mud 2/Group 1 but use 4.0 gr. of CC-16.

Group 2


Mud 2: Proceed as in Mud 2/Group 1 but use 0.4 gr. of Barafos* instead of CC-16.

Mud 3: Proceed as in Mud 3/Group 1 but use 1.0 gr. of Barafos instead of CC-16.

Mud 4: Proceed as in Mud 4/Group 1 but use 4.0 gr. of Barafos instead of CC-16.

Group 3


Mud 2: Proceed as in Mud 2/Group 1 but use 0.15 gr. of SAPP* instead of CC-16.

Mud 3: Proceed as in Mud 3/Group 1 but use 0.25 gr. of SAPP instead of CC-16.

Mud 4: Proceed as in Mud 4/Group 1 but use 0.30 gr. of SAPP instead of CC-16.

*Description included in Appendix A.

Each group will test their 4 muds for the following properties:


2. Plastic viscosity, yield point, 10-sec gel strength, 10-min gel strength (Baroid

Rheometer).

3. Fluid loss (Filter Press).


Note the following:


2. Return the sample to the sample container after each test and re-stir it by hand.


4. Do a 7.5-min filtration test and report the corrected 30-min loss.

36

Results:



b) Plastic viscosity (cp).


d) 10-sec gel strength (lbs/100 sq. ft.).

e) 10-min gel strength (lbs/100 sq. ft.).

f) pH.

g) Corrected 30-min fluid loss (ml).

2) Plot the following mud properties vs. % of thinner in the mud:

a) Plastic viscosity (cp)

b) Yield point (lbs/l00 sq. ft.).

c) 10-sec gel strength (lbs/l00 sq. ft.).

d) 10-min gel strength (lbs/100 sq. ft.).



a) Increasing the concentration of the thinner CC-16 in a fresh water-based mud (Group 1).

b) Increasing the concentration of the thinner Barafos in a fresh water-based mud (Group 2).

c) Increasing the concentration of the thinner SAPP in a fresh water-based mud (Group 3).

4) Compare the results of adding the thinners CC-16, Barafos, and SAPP to a fresh water-based

mud.

37



High Temperature Effects

Object:

Evaluate the effects of high temperature on drilling muds.

Theory:

The filtration properties of drilling mud are a measure of the ability of the solid components

of the mud to form a thin, low-permeability filter-cake. The lower the permeability, the thinner

the filter cake and the lower the volume of filtrates from mud of comparable solids

concentration. This property is dependent upon the amount and physical state of the colloidal

material in the mud. It has been shown repeatedly in the filed that when mud of sufficient

colloidal content is used, drilling difficulties are minimized. In contrast a mud low in colloids

and high in inert solids deposits a thick filter cake on the walls of the hole. A thick filter cake

restricts the passage of tools and allows an excessive amount of filtrate to pass into the

formation, thus providing a potential result in further trouble such as difficulty in running casing,

creating a swabbing effect which may cause the formation to cave or swab reservoir contents

into the hole, and difficulty in securing a water shutoff because of channeling of cement.

In previous laboratories the filtration properties of drilling mud were tested at a specified

pressure of 100 psig, and room temperature. In this laboratory the filtration properties of a

drilling mud will be tested at high temperatures as may be encountered at the bottom of the hole.

Procedure:

Each group of the lab section will test different mud clays. Description of each of the clays is

included in Appendix A. The lab instructor will prepare the muds for you in the following

manner:

1. Add the required amount of clay to the required amount of fresh (distilled) water.

2. Stir 10 minutes with the mixer

3. Age the mud overnight.

GROUP MUD NAMEMUD 1

(gr. clay/cc water)

MUD 2

(gr. clay/cc water)

1 Aguagel* 50/1000 100/1000

2 Zeogel* 50/1000 100/1000

3 Quick-Gel* 25/1000 50/1000

*These materials are Baroid trade names. Their functions are described in Appendix A.

38

Each group will test their muds at two temperatures according to the following manner:

A. Preheating the Heating Jacket

1. Connect the power cord to the proper line voltage as indicated on the nameplate.

2. Turn the thermostat to near mid-scale.

3. Place the metal stem dial thermometer in the thermometer well of the heating jacket.

4. The pilot light will turn on when the heating jacket temperature has reached the

thermostat setting.

5. Readjust the thermostat as necessary to obtain the desired test temperature. (Just below 3

is 200 ºF.)

B. Loading the Filtration Cell

***SAFETY NOTE***. The filtration Cell Assembly constitutes a Pressure Vessel. The

SAFETY PRECAUTIONS listed should be followed to assure safe operation.

• Cell material should be compatible with the test sample.

• Cell bodies that show signs of stress cracking, severe pitting, or have damaged set

screw holes must not be used.

• Cell caps showing evidence of the set screw seat being pulled or deformed must not

be used.

• Damaged or “Hardware Store” set screws must not be used.

1. Loosen the six socket head set screws and remove the cell end cap by pulling it straight

out of the cell, using the valve stem as a handle.

2. Check “O” rings on the valve stems, cell body and cap. Replace any damaged or brittle

‘O” rings. Replacement of “O” rings is normally required after test run above a

temperature of 350 ºF.

3. Repeat 1 and 2 above for the other end cap.

4. Reassemble the end cap and valve stem which is going to be the non-filter end. (The filter

end is the end with two little holes in the jacket.) Make sure the six socket set screws are

securely tightened and the valve stem is tight.

5. Carefully fill the cell with sample to be tested. Allow ½” to ¾” from the top for

expansion when the sample is to be heated.

6. Position the filter on the “O” ring in the cell body. Place the screen on the filter paper,

course side up.

7. Install the end cap making sure the set screw seats in the cap are aligned with the set

screws in the body. Tighten set screws firmly, then install and tighten the valve stem.

8. Invert and lower the filtration cell assembly into the heating jacket (filter end down) and

rotate so that the pin is in the bottom of the cell. This prevents the cell rotating when the

39

valve stems are opened or closed.

C. Pressurizing the Filtration Cell

1. Attach the high pressure hose connected to the 1500 psi gauge side of the manifold, to the

top, or inlet, valve stem and insert the locking pin.

2. Close the bleeder valve on the valve stem adapter manifold.

3. Check the “T” screws on the pressure regulators to be sure that they are unscrewed

(counterclockwise) and no pressure will be applied.

4. Open the valve on the Nitrogen bottle slowly and carefully. The bottle pressure will be

registered on the middle manifold gauge.

5. Turn the “T” screw on the left hand regulator clockwise until the desired cell pressure is

registered on the gauge.

D. Conducting the Filtration Test

1. Place a graduated cylinder under the cell lower valve stem.

2. Check the temperature of the cell by placing the metal stem dial thermometer in the

thermometer well of the cell. As soon as the desired temperature is reached, the test may

be started.

3. With an adjustable wrench, open the inlet valve stem ½ turn. If the pressure on the cell

pressure gauge of nitrogen manifold has changed from the desired setting, readjust the

regulator. If the adjustment is to lower the pressure, momentarily open the bleed valve to

reduce the pressure.

4. Set a timer for 30 minutes or other desired filtration test time.

5. With an adjustable wrench, open the lower valve stem on the bottom of the filtration cell

½ turn. This is the start of the test.

E. Test Conclusion and Disassembly

1. Disconnect the filter press-heating jacket from the power source.

2. Close the filtration cell (upper) valve stem.

3. Release the “T” screws (turn counterclockwise) of the test filtration.

4. Open the bleed valve on the test cell manifold to de-pressurize the system.

5. Remove the upper valve stem locking pin and remove the adapter manifold from the top

valve stem.

6. The pressurized cell assembly may be left in the heating jacket or it may be removed to

another location for air cooling, or it can be removed from the heating jacket and rapidly

40

cooled with running water.

7. After the cell and the sample in the cell are cool, the cell may be opened. Make sure the

open end of the valve stem is pointed away. Then, using the adjustable wrench, open the

top valve stem (the one on the opposite end of the cell from the filter) about ½ turn and

allow the pressure to bleed off. Make sure all pressure has bled off.

**WARNING**

• Do not attempt to remove the cell cap if any pressure remains in the cell.

• Removing the cell cap while the cell is pressurized could result in serious injury.

8. Once sure that all the pressure has been release, loosen the six socket set screws in the

end

cap and using the valve stem as a handle, pull the end cap out of the cell.

9. The sample may now be emptied and examined as desired.

Results:

1) Tabulate the following properties:

a) Corrected 30-min. fluid loss (ml)

b) Filter cake thickness.

2) Graph the following properties vs. temperature:

a) Corrected 30-min. fluid loss (ml)

3) Summarize the effects of increasing temperature on the mud and compare the results of each

mud system.

41

FIELD TESTING OF CEMENTS


Regular Cement, Cement Extenders and Cement Weighting Materials

Object:

Investigate the effects of cement extenders and weighting materials on regular neat cement.

Theory:

Lightweight cement slurries are used to reduce hydrostatic pressure on weak formations and

to lower slurry cost. Basically, lightweight slurries are made by adding more water to lighten the

mixture and then adding cement extenders, such as bentonite clay, which keep the solids from

separating. Bentonite is compatible with all additives and may be used to formulate specific

cement systems.

High-density slurries are used to cement high-pressure wells where increased hydrostatic

head is required to prevent formation gas, oil, or water from entering the borehole during

cementing operations. Barite (s.g. = 4.23) is a commonly used weighting material and can be

used to increase cement slurry density up to 18.0 ppg.

Procedure:

Each group will prepare two 500 ml samples of their three cements at the beginning of lab.

Prepare each 500 ml sample in the following manner:

Group 1

Cement 1: Regular cement (32.0 % water). Add 640.0 gr. of cement to 296.0 cc of water already

in blender and mix at high speed for 35 seconds.

Cement 2: Regular (35.0 % water). Add 583.2 gr. of cement to 315.0 cc of water already in

blender and mix at high speed for 35 seconds.

Cement 3: Regular cement (40.0 % water). Add 507.4 gr. of cement to 339.0 cc of water already

in blender and mix at high speed for 35 seconds.

Group 2

Cement 1: Regular cement with 4.0 % bentonite (40.0 % water). Dry mix 19.5 gr. of bentonite

with 487.1 gr. of cement and mix with 338.0 cc of water already in blender at high



with 393.2 gr. of cement and mix with 363.0 cc of water already in blender at high

42



with 329.7 gr. of cement and mix with 380 cc of water already in blender at high


Group 3

Cement 1: Regular cement with 5.0 % barite (31.0 % water). Dry mix 31.1 gr. of barite with

621.7 gr. of cement and mix with 295.0 cc of water already in blender at high speed

for 35 seconds.



for 35 seconds.



for 35 seconds.

Each group will test their 3 cements for the following properties:


2. Plastic viscosity, yield point (Baroid Rheometer).


4. Compressive strength (Versa Tester).

Note the following:


2. Do a 10-min filtration test and report the corrected 30-min loss.

3. Do the compressive strength determination on 3 molds after waiting 24 hours.

4. Include Cement 1/Group 1 as the 0.0 % additive point in all the tabulations and graphs.

Results:


a) Cement density (ppg).

b) Plastic viscosity (cp)


d) Dehydration time (min).


f) Compressive strength (psi).

2) Plot the following cement properties vs. (1) % of water (Group 1), (2) % of bentonite (Group

2), and (3) % barite (Group 3) in the slurry:

a) Cement density (ppg)


43

c) Yield point (lbs/l00 sq. ft.).

d) Corrected 30-min fluid loss (ml).

e) Compressive strength (psi).


a) Increasing the water concentration of regular cement (Group 1).

b) Increasing the bentonite concentration of regular cement (Group 2). [Note: Water content

increases according to API minimum requirements.]

c) Increasing the barite concentration of regular cement (Group 3). [Note: Water content

increases according to API minimum requirements.]

4) Compare the results of using water without bentonite and water with bentonite to extend the

cement.

44



Cement Accelerators and Retarders

Object:

Investigate the effects of cement accelerators and retarders on neat cement.

Theory:

Most operations wait for cement to reach a minimum strength of 500-psi before resuming

operations. At temperatures below 100 ºF, common cement may require a day or two to develop

500-psi compressive strength.

Low concentrations of cement accelerators (2-4 % by weight of cement) are used to shorten

the setting time of cement and promote rapid strength development, thus reducing waiting-on-

cement (WOC) time. Calcium chloride and sodium chloride are the most common accelerators.

With its accelerated thickening time and compressive strength development, calcium chloride

is used in whipstock plugs, lost-circulation plugs, and squeeze slurries.

Increased well depths and formation temperatures require the use of cement retarders to

extend the pumpability of cements. Besides retardation, most retarders affect cement viscosity to

some extent. Lignosulfonates and celluloses (which we will discuss in our next experiment) are

mild dispersant.

Calcium lignosulfonates, derived from wood-pulping processes, are the most common

retarders. They are available as either a brown powder or liquid. Their effectiveness is limited to

temperatures less than 100 ºF.

Procedure:

Each group will prepare two samples of their three cements at the beginning of lab. Each

sample will be slightly greater than 500 ml. Prepare each 500 ml sample in the following

manner.

Group 1

Cement 1: Regular cement with 1.0 % calcium chloride (CaCl) (28.0 % water). Dissolve 7.0 gr.

of calcium chloride in 280.0 cc of water already in blender. Add 700.0 gr. of cement

and mix at high speed for 35 seconds.

Cement 2: Regular cement with 2.5 % calcium chloride (28.0 % water). Similar to Cement 1 but

using 17.5 gr. of calcium chloride.

45

Cement 3: Regular cement with 4.0 % calcium chloride (28.0 % water). Same as Cement 1

except use 28.0 gr. of calcium chloride.

Group 2

Cement 1: Regular cement with 1.0 % sodium chloride (NaCl) (28.0 % water). Dissolve 7.0 gr.

of sodium chloride in 280.0 cc of water already in blender. Add 700.0 gr. of cement

and mix at high speed for 35 seconds.

Cement 2: Regular cement with 2.5 % sodium chloride (28.0 % water). Same as Cement 1

except use 17.5 gr. of sodium chloride.

Cement 3: Regular cement with 4.0 % sodium chloride (28.0 % water). Same as Cement 1

except use 28.0 gr. of sodium chloride.

Group 3

Cement 1: Regular cement with 0.1 % Lignin HR4 retarder (28.0 % water). Dissolve 1.4 gr. of

retarder in 280.0 cc of water already in blender. Add 700.0 gr. of cement and mix at

high speed for 35 seconds.

Cement 2: Regular cement with 0.25 % Lignin HR4 retarder (28.0 % water). Same as Cement 1

except use 1.75 gr. retarder.

Cement 3: Regular cement with 0.5 % Lignin HR4 retarder (28.0 % water). Same as Cement 1

except use 3.5 gr. retarder.

Each group will test their 3 cements for the following properties:




Note the following:




4. Include Cement 1/Group 1 from Laboratory Experiment No. 4 as the 0.0 % additive point

in all the tabulations and graphs.

Results:





46




2) Plot the following cement properties vs. (1) % of calcium chloride (Group 1), (2) % of

sodium chloride (Group 2), and (3) % Lignin HR4 retarder (Group 3) in the slurry:







a) Increasing the calcium chloride content of regular cement (Group 1).

b) Increasing the sodium chloride content of regular cement (Group 2).

c) Increasing the Lignin HR4 Retarder content of regular cement (Group 3).

4) Compare the results of using calcium chloride as cement accelerators.

47



Water Loss Additives and Dispersants

Object:

Investigate the effects of water loss additives and dispersants on neat cement.

Theory:

Fluid-loss additives improve primary cement jobs because they have the ability to:

1. Prevent cement degradation in the annulus. This helps prevent stuck pipe, helps prevent

loss of returns, and helps to bring cement to the desired height.

2. Prevent gas migration. The viscosity and gelation properties of slurries containing fluid-

loss additives help solve this problem.

3. Improve bonding. The bonding qualities of cements containing fluid-loss additives are

also very good.

4. Minimize formation damage. By reducing the amount of filtration lost into sensitive

formations, fluid-loss additives help insure better formation productivity.

Fluid-loss additives are polymers. The most common are cellulose derivatives and they are

also used to control the rate of dehydration when squeezing. This is especially true when

squeezing perforations.

Dispersants reduce slurry viscosity, allow slurry turbulence at lower pump rates, allow

heavier slurries with less water and less weighting materials, and help provide fluid-loss control

for densified slurries. The most common dispersants are aryl sulfonates used in concentrations of

0.3 % to 2.0 % by weight of cement.

Neat cement slurries with densities above 17 ppg are difficult to mix. By using a high

molecular weight polymer, however, slurries may be densified to 18 ppg without using a

weighting material. For slurries heavier than 18 ppg a combination of dispersant and weighting

agent is used.

Procedure:

Each group will prepare two of their three cements at the beginning of lab. Prepare each 500

ml sample in the following manner:

Group 1

Cement 1: Regular cement with 0.5 % aryl alkyl sulfonate (CFR-2) (28.0 % water). Dry mix 3.5

gr. of CFR-2 with 700.0 gr. of cement and mix with 280.0 cc of water already in

48

blender at high speed for 35 seconds.

Cement 2: Regular cement with 1.0 % aryl alkyl sulfonate (CFR-2) (28.0 % water). Same as

Cement 1 except use 7.0 gr. of CFR-2.

Cement 3: Regular cement with 2.0 % aryl alkyl sulfonate (CFR-2) (28.0 % water). Same as

Cement 1 except use 14.0 gr. of CFR-2.

Group 2

Cement 1: Regular cement with 2.0 % organic polymer (28.0 % water). Mix 14.0 cc of organic

polymer with 280.0 cc of water already in blender. Add 700.0 gr. of cement and mix

at high speed for 35 seconds.

Cement 2: Regular cement with 6 % organic polymer (28.0 % water). Same as Cement 1 except

use 42.0 cc of organic polymer.

Cement 3: Regular cement with 10% organic polymer (28% water). Same as Cement 1 except

use 70.0 cc of organic polymer.

Group 3

Cement 1: Regular cement with 0.1 % cellulose (Flocelle) (28.0 % water). Dry mix 0.1 gr. of

Flocelle with 700.0 gr. of cement and mix with 280.0 cc of water already in blender

at high speed for 35 seconds.

Cement 2: Regular cement with 1.0 % cellulose (28.0 % water). Same as Cement 1 except use

7.0 gr. of Flocelle.

Cement 3: Regular cement with 2.0% cellulose (28.0 % water).Same as Cement 1 except use

14.0gr. of Flocelle.

Each group will test their cements for the following properties:


2. Plastic viscosity, yield point (Baroid Rheometer)



Note the following:




4. Include Cement 1/Group 1 from Laboratory Experiment No. 4 as the 0.0 % additive point

in all the tabulations and graphs.

49

Results:








2) Plot the following cement properties vs. (1) % of CFR-2, (2) % of organic polymer, and (3)

% of Flocelle in the slurry:







a) Increasing the aryl alkyl sulfonate content of regular cement (Group 1).

b) Increasing the organic polymer content of regular cement (Group 2).

c) Increasing the cellulose content of regular cement (Group 3).

4) Compare the results of using organic polymer and Flocelle as water loss control additives.

50

SURFACE BOPSTACK WELL CONTROL

Laboratory Exercise No. 8

Simulator Orientation

Object:

Become acquainted with the components of the CS Inc. DS-20FS/W/P rig floor simulator.

Theory:

The results of a hydrocarbon well blowout can be disastrous. Natural gas or crude flowing

uncontrollably at the surface can take human life, destroy millions of dollars worth of equipment,

and cause irreparable damage to the environment.

Drilling rig personnel must be properly trained to prevent the occurrence of blowouts. Rig

floor simulators allow rig personnel to practice well control procedures, to test the principles and

theory underlying these procedures, and to become familiar with the equipment used during well

control operations. Before the simulator can be effectively utilized, however, the student must

have an understanding of its components and operation.

Procedure:

The lab instructor will conduct a tour of Penn State’s rig floor simulator, a DS-20FS/W/P.

The following topics will be covered.

1. Rig components used during normal drilling operations.

2. Rig components used during well control operations.

3. Simulator representations of actual rig components.

4. Simulator components used to program and control simulator operations.

IMPORTANT:

1. The DS-20FS/W/P is a sensitive piece of machinery.

2. Special care must be taken not to damage simulator components.

3. DO NOT touch any control on the instructor’s program panel.

4. DO NOT lean against or stand on any simulator component.

5. DO NOT set textbook, notebooks, or coats on any simulator component.

6. DO NOT force open any valves if they appear to be stuck.

51

7. DO NOT excessively tighten any valves to close them.

8. DO NOT raise the Kelly bushing more than halfway to the ceiling.

9. The general rule to use is WHEN IN DOUBT ASK THE LAB INSTRUCTOR BEFORE

PROCEEDING.

Results:

1) Reproduce the list of “DO’s” and ‘DON’T’s” for proper simulator operation that the lab

instructor covers at the beginning of lab. The list will be posted and reviewed by the lab

instructor at the beginning of each lab meeting and WILL BE STRICTLY ENFORCED!

2) Make a line drawing of each of the simulator components listed below showing the position

of each gauge or control found on the component. Use a different piece of paper for each

component and make the drawings large enough so that space is available to label each gauge

and control. Include a sentence or two for each label that describes the function of that

particular part.

i) Drawworks console.

ii) Driller’s console.

iii) Brake handle and foot throttle.

iv) Surface BOP stack control panel.

v) Remote choke panel.

vi) Remote mud box.

vii) Drill pipe visual display.

viii) Choke manifold.

ix) Standpipe manifold.

3) Draw a schematic of the drilling mud circulation system on the simulator. Show the path

followed by the mud during normal drilling operations. Show the path followed by the mud

during well control operations.

52

SURFACE BOP STAC WELL CONTROL


Simulator Operation

Object:

Practice working the controls of the CS Inc. DS-20FS/W/P rig floor simulator to observe the

effects of different mud densities on the rate of penetration (ROP).

Theory:

The rate at which the drill bit can penetrate the formation rock is an important economic

consideration during drilling operations. An optimal penetration rate reduces the amount of time

the rig spends on location and thus minimizes the cost of leasing the rig.

The ROP is a function of many factors including bit type, weight-on-bit (WOB), bit RPM,

rock strength, differential pressure, etc. Differential pressure refers to the difference between the

pressure exerted by the drilling mud at total depth and the formation pressure at that depth.

Differential pressure is a function of mud density because muds having different densities

will exert different pressures at the same depth. A correlation between mud density and ROP can

be obtained by changing mud weights and measuring the ROP while through the same

formation.

Procedure:

The lab instructor will first review the rules that must be followed whenever operating the

simulator.

At the start of the exercise the bit should be hanging slightly above bottom and rotating

slowly. In addition, the mud pump should be turned on so that the drilling mud is slowly

circulating. All well parameters such as total depth, hoe size, drill pip capacity, etc., and all

drilling parameters such as WOB, rotary speed, pump speed, etc., will be given to you by the lab

instructor at this time. Initial mud weight will be 19.0 ppg.

One student will be designated the driller and it will be the driller’s responsibility to run the

bit to bottom and to drill ahead while making sure the that the specified drilling parameters are

held as constant as possible. The driller should follow the procedure given below:

1. With the bit still hanging off bottom, bring the mud pump up to the proper strokes per

minute (SPM).

2. Remove tie-down chain from the brake handle and lift up on the brake handle until the

drill pipe begins to slowly fall into the hole.

53

3. Make sure the bit is still rotating slowly and watch the WOB indicator. When the bit

touches bottom the WOB indicator will show the bit taking on weight. Slowly increase

the WOB to the proper value while steadily increasing bit RPM.

4. Stop the drill pipe from falling when the proper WOB is reached by pushing down on the

brake handle. Double check mud pump SPM and bit RPM to make sure they are at the

proper values.

5. Wait for the geolograph to make a tick mark. Another tick mark will be made when 1

foot of hole has been drilled. The time between tick marks should be measured and the

ROP (ft/hr) calculated. Also, record the drill pipe pressure.

6. After 1 foot of hole has been drilled in this manner the bit should be returned to its

original position. Decrease the bit RPM to zero. Lift up on the brake handle and step on

the foot throttle. Raise the bit until the WOB falls to zero. Adjust the bit RPM and the

mud pump SPM to their standby levels.

Another student will now be designated the driller and follow the same procedure for a mud

weight of 17.0 ppg. Continue in this manner, decreasing the mud weight in increments of 2.0

ppg, until all of the students have had a turn at the controls.

Results:

1) Plot ROP (ft/hr) vs. mud density (ppg).

2) Plot ROP (ft/hr) vs. differential pressure (psi).

3) Summarize the effects of decreasing mud density on ROP.

54



The Soft Shut-In Procedure

Object:

Practice detecting gas kicks and shutting in the well using the soft shut - in procedure.

Theory:

When the bit passes through an impermeable cap rock into a porous and permeable formation

a drilling break can occur. A drilling break is simply a sudden, sharp increase in the penetration

rate. It indicates that you are in a situation in which a blowout could occur because a porous and

permeable formation could contain abnormally pressured gas. It does not indicate that a kick is

occurring. It is merely a warning signal that tells you to proceed with caution.

Two other indicators, however, will tell you that a kick is definitely occurring. The primary

indicator is a flow rate increase in the mud return line. A flow rate increase will always occur

before the secondary indicator, an increase in the mud pit volume is noticeable. The flow rate

meter and mud pit gain/loss indicator monitor the values of these two positive kick indicators,

respectively.

A flow check should be performed as follows if there is ever a doubt about whether or not the

well is kicking:

1. Stop rotating and pull the bit off bottom.

2. Shut off the mud pumps.

3. Check for flow. A kick is definitely occurring if the well continues to flow after the mud

pump has been shut off and the well should be immediately shut in.

Shutting the well in stops the influx of abnormally pressured gas into the wellbore because

the abnormal formation pressure is balanced by the increase in shut-in drill pipe and shut-in

casing pressure. The well should be shut in using the soft shut-in procedure. This procedure

allows the pressure in the wellbore to build up slowly and minimizes the possibility of pressure

surges that could damage the casing and surface equipment or fracture the formation.

Procedure:


simulator.

At the start of the exercise the bit should be hanging slightly above bottom and rotating

55

slowly. In addition, the mud pump should be turned on so that the drilling mud is slowly

circulating. All well parameters and drilling parameters will be given to you by the lab instructor

at this time.

One student will be designated the driller, one will be designated the choke operator, and one

will be designated the BOP operator. After the flow rate and mud pit volume increase, alarms are

set in a manner described by the lab instructor, the driller will begin to drill ahead and should

watch closely for the occurrence of any kick indicators.

Once the driller decides that a kick is occurring the well should be shut in following the soft

shut-in procedure:

1. The driller stops rotation, picks up the drill pipe until the WOB falls to zero, and

continues to pick up the drill pipe until the Kelly bushing is 3’ - 4’ above the rotary table.

2. The driller shuts off the mud pumps.

3. The BOP operator (1) opens the choke line valve on the BOP stack, and (2) closes the

annular preventer. Both pieces of equipment are operated by first depressing the master

air valve shut-off switch and then moving the equipment control switch to the open or

closed position. Both switches should be engaged until the red light goes off or comes on

to signal that equipment is open or closed, respectively.

4. The choke operator closes the remote choke.

5. Let the pressures stabilize and read the shut-in drill pipe and shut-in casing pressures.

This procedure should be repeated until everyone has had a chance to be the driller, choke

operator, and BOP operator.

Results:

1) Describe the 3 kick indicators used in this exercise.

2) Describe the flow check procedure.

3) Describe the soft shut-in procedure.

56



The Wait and Weight Method

Object:

Practice killing a well using the wait and weight method of well control.

Theory:

Most methods of well control have at least three characteristics in common: (1) the gas kick

is circulated out to the hole, (2) additional formation gas is prevented from entering the wellbore,

and (3) the drilling mud density is increased so that the hydrostatic pressure exerted by the mud

column will counterbalance the abnormal formation pressure.

Once the proper kill weight mud has been completely circulated through the system the well

is said to be killed or dead and normal drilling operations can be resumed (with caution!).

One of the most important aspects of well control is to prevent the influx of additional gas

into the wellbore. This is accomplished by keeping the pressure exerted by the mud column in

the drill pipe at the bottom of the hole constant while the gas kick is being circulated to the

surface.

Shutting in the well temporarily stops more gas from flowing into the wellbore because the

abnormal formation pressure is balanced by the mud hydrostatic pressure plus the shut-in drill

pipe pressure. In fact, the value of the shut-in drill pipe pressure is exactly equal to the pressure

differential between the abnormal formation pressure and the mud hydrostatic pressure.

During the wait and weight, while the kick is being circulated to the surface the choke is

adjusted so that the circulating bottom hole pressure balances the abnormal formation pressure.

The circulating bottom hole pressure can be calculated by adding the hydrostatic pressure of the

mud in the drill string to the circulating drill pipe pressure.

Several terms should be defined at this point:

1. Kill rate pressure or slow circulating rate pressure - This is the drill pipe pressure

required to circulate original weight mud through the wellbore at a reduced pump speed

called the kill rate. The kill rate pressure must be measured before the well kicks.

2. Shut-in drill pipe pressure - This is the extra pressure required to control the kicking

formation.

3. Initial circulation pressure - This is the value that the circulating drill pipe pressure

should have at the start of the wait and weight procedure. It is equal to the kill rate

pressure plus the shut-in drill pipe pressure.

57

The object of the wait and weight method is to circulate kill weight mud into the well

through the drill pipe, to circulate the gas kick out of the hole through the annulus, and to keep

the abnormal formation pressure balanced by the mud column pressure in the drill pipe all at the

same time.

As soon as the mud pits are filled with kill weight mud the choke is opened and the mud

pump is brought up to the kill rate. The choke is quickly adjusted so that the drill pipe pressure

gauge reads a value equal to the initial circulating pressure.

As more kill weight mud is circulated down through the drill pipe the pressure exerted by the

column of mud in the drill pipe is increased because the lighter original mud is displaced by the

high density kill mud. The circulating drill pipe pressure must be reduced accordingly or else the

increased bottom hole pressure could become great enough to fracture the formation when the

kill weight mud finally reaches the bottom of the hole and begins to displace original mud out of

the annulus.

When the kill mud reaches the bit the drill pipe pressure is reduced to a value called the final

circulating pressure. Drill pipe pressure is held constant at the final circulating pressure during

the remainder of the kill procedure because there is now only one type of mud in the drill string

and the hydrostatic pressure there is constant. The well should be dead when kill weight mud

reaches the surface through the annulus.

Procedure:


simulator.

At the start of the exercise the bit should be hanging slightly off bottom and slowly rotating.

In addition, the mud pump should be turned on so that the mud is slowly circulating. All well

parameters and all drilling parameters will be given to you by the lab instructor at this time.

Everyone should fill in the prerecorded information portion of the wait and weight kill sheet.

One student will then be designated the driller, one the choke operator, and one the BOP

operator.

First, the kill rate pressure should be measured. Bring the mud pump SPM up to the first kill

rate record that kill rate pressure. Then, adjust the pump SPM to the second kill rate pressure and

record that kill rate pressure. Follow the same procedure to measure and record the two kill rate

pressures for the second mud pump.

The driller should then start to drill ahead and watch for kick indicators. As soon as the kick

is detected, the well should be shut in following the soft shut-in procedure. Read and record the

shut-in drill pipe pressure and shut-in casing pressure after they have stabilized. Record the pit

volume increase. Follow the directions on the kill sheet increase, final circulating pressure,

surface-to-bit strokes, and bit-to-surface strokes.

58

Fill in the circulating drill pipe pressure schedule at the bottom of the kill sheet. Dial up the

the proper kill weight mud on the remote mud box. You are now ready to kill the well by the

wait and weight method.

The Wait and Weight method is outlined below:

1. Starting with the well completely shut-in, the choke operator will first crack open the

choke and then the driller will slowly but steadily bring the mud pump up to the kill rate.

The choke operator should keep the casing pressure constant by opening or closing the

choke as the pump is brought up to speed.

2. As soon as the mud pump is at the kill rate the choke operator should adjust the choke so

that the drill pipe pressure equals the initial circulating pressure.

3. The driller will continue to pump kill mud into the hole at the kill rate. At the same time

the choke operator will reduce the drill pipe pressure from the initial circulating pressure

to the final circulating pressure according to the pressure reduction scheduled at the

bottom of the well control worksheet.

4. The choke operator will maintain the final circulating pressure after the kill weight mud

reaches the bit until the kill weight mud appears at the surface.

5. When the kill mud reaches the surface the crew should do a soft shut-in and check the

shut-in drill pipe and casing pressures. The well is assumed to be dead only if both

pressures are zero.

As many people as possible should have a chance to operate the choke during this exercise.

The entire exercise should be repeated with different people at the various stations if time allows.

Results:

1) Describe the wait and weight method of well control.

2) Complete the wait and weight worksheet for your well control problem.

3) List the advantages and disadvantages of the wait and weight method.

59

CEMENT HEAD LABORATORY


Cement a Casing String

Object:

Evaluate the techniques of cementing casing in a well.

Theory:

Different cementing equipment and placement techniques are used for cementing casing

strings, cementing liner strings, setting cement plugs, and squeeze cementing. A casing string is

different from a liner string in the fact that the casing extends to the surface, while the liner is

attached to the subsurface casing previously cemented in the hole. Cement plugs are placed in

open hole or in casing before abandoning a lower portion of the well. Cement is squeezed into

lost-circulation zones, abandoned casing perforation, or a leaking cemented zone to stop

undesired fluid movement.

Cementing Casing

When the casing string is ready to be cemented the cement slurry is prepared in a special

cementing unit for the type of the job (truck mounted for land jobs, skid mounted for offshore).

The cement slurry is pumped from the unit to a special cementing head screwed into the top

joint of casing. When cementing begins, the bottom rubber wiper plug is released from the plug

container ahead of the cement slurry. The plug wipes the mud from the casing ahead of the slurry

to minimize contamination of the cement with the mud. The plug reaches the float collar and

stops. Continuing to pump cement causes a diaphragm in the plug to rupture (a spike will occur

in the pump pressure). This allows the cement slurry to be displaced through the plug and into

the annulus. After the desired volume of cement slurry is pumped into the casing, the top wiper

plug is released from the plug container. The top plug displaces the cement plug by pumping

drilling mud into the casing behind the top plug. When the top plug reaches the bottom plug a

pressure increase will be encountered which signifies the end of the displacement operation.

Procedure:

1. The lab instructor will provide everyone with the depth, hole diameter, and casing size.

2. The volume of the annulus must be calculated using this data (use a safety factor of 1.2).

3. This will be the volume of cement slurry that is needed to be pumped.

4. The number of strokes required to pump this volume must then be calculated.

60

At the start of the exercise the mud pumps will be on so that the mud is slowly circulating.

Stop circulation and pick up off the bottom. Assume that the casing string is now at the correct

depth to be cemented. Unhook the Kelly and hook up to the cement head. Load the bottom plug

into the cement head and then load the top plug.

Open the cement head valve to allow flow of the cement slurry and turn on the cement

pumps. Remove the pin supporting the top plug to allow it to lead the slurry to the float collar.

When a spike is seen in the pump pressure the plug has reached the float collar. Pump until the

total number of strokes needed for the desired cement volume is obtained. At this time release

the top plug, discontinue pumping cement and resume pumping mud until the top plug reaches

the bottom plug. Look for a spike in the pump pressure and shut the mud pumps down.

Results:

1) Describe the method of cementing the casing.

2) Compare the method completed in the lab with other methods used in the industry.

3) Describe other uses of cementing.

61

APPENDIX A

MUD ADDITIVES

62

MUD ADDITIVES1

Mud control can be divided into three basic categories: the control of mud weight, the control

of viscosity and gel strength, and the control of water loss. Various mud additives have been

developed for each of these areas of control.

Control of Mud Weight

Mud weight control is almost synonymous with the control of solids. The mud weight

requirements should be based on that weight required to control formation pressures.

For under-pressured reservoirs (i.e. formations with pore pressures less than 0.433 psi/foot

depth) mud weight can be reduced to levels below the fresh water gradient by using oil, oil and

fresh water, or by aerating the fluid column. The use of air (or natural gas) alone as a drilling

fluid is also an acceptable practice, although this technique is restricted to areas where there are

no high volume water sands to be penetrated.

Weighted muds are defined as those where barite or some other high density solid has been

added to increase mud weight.

Control of Viscosity and Gel Strength

The control of viscosity or mud thickness will of course depend on the operator’s objectives.

Viscosity may be maintained at high levels to ensure adequate hole cleaning. Additives, such as

some of the polymers, may be added to increase the mud thickness for adequate hole cleaning

while keeping the mud weight and total solids content at low levels. With weighted muds some

operators have used polymers for increasing thickness in order to keep clay solids that provide

support for the barite, to a minimum.

In general, if there are no specific hole requirements, the operator prefers to use the thinnest

possible drilling fluid. Thinning is also emphasized when using weighted muds close to the

fracture gradient of exposed formations.

When more viscosity is desired it may be obtained by (1) adding Bentonite, (2) flocculating

the clay solids, and (3) adding polymers designed for the purpose. Bentonite is the primary

viscosity builder in the mud system. If fresh water is being used Bentonite will increase viscosity

rapidly with only small increases in mud weight. Flocculation of the clays in a fresh water mud is

also a quick and cheap method of increasing viscosity. The flocculation can usually be done by

adding lime or cement.

Another method for thickening mud is the use of specific polymers.

1Moore, Preston L., Drilling Practices Manual, The Petroleum Publishing Co.

63

There are several different polymers available. Basically, they can be divided into three

groups; (1) the polymers that thicken the mud by acting on the clay solids, (2) polymers that are

colloidal in nature and essentially provide a substitute for bentonite, and (3) the polymers that

thicken the liquid phase and do not react with bentonite.

Viscosity control is generally in terms of reducing mud thickness. Methods used for control

include mechanical aids, water dilution and chemical thinners. The most widely used of these

methods is the chemical thinners. Table 1 includes some of the more common mud thinners.

Table 1. Drilling mud thinners Chemical pH of 1% solution Limitations

Sodium acid

pyro Phosphate4.3

Decomposed and forms flocculating agent above 175 F.

Not effective in the presence of large quantities of

calcium

Sodium

tetraphosphate8.0 Same as 1.0

Chrome

Lignosulfonate7.0

Material starts to decompose at temperatures above 300

F. pH needs to be at least 9.0.

Liginite 3.2Material starts to decompose at temperatures above 350

F. pH needs to be at least 9.0.

Tannin 5.0 Not very effective if pH of mud is less than 11.0.

SurfactantsMany types, temperature stability above 300 F may be a

problem. Most are more expensive than other materials

Control of Water Loss (Filtration Control)

The filtration rate is generally controlled for the following two reasons: (1) to control the

thickness and characteristics of the filter cake which is deposited on permeable formations and

(2) to limit the total filtrate that enters underground formations.

Filter cake thickness and the friction between the filter cake and the drill string relate to the

problems of (1) differential pressure sticking, (2) torque and drag while drilling and tripping the

drill string, (3) running of wireline tools and casing strings and (4) sidewall coring. An increase

in filter cake thickness increases the area of contact between the drill string and the filter cake

and for a given friction coefficient increases the danger of sticking the drill string and also

increases the torque and drag on the drill string.

The running of wireline tools and casing is restricted by the reduction in hole size as the filter

cake gets thicker. A thick filter cake may prevent any formation recovery on a wireline test. For

these problems the operator is not concerned with the actual loss of filtrate. The filtrate loss is

used to indicate the potential thickness of the filter cake.

The problems of differential pressure sticking and torque and drag are related primarily to

high weight drilling muds in deep high temperature environments.

64

Operators are concerned with the total filtrate entering underground formations for the

following reasons: (1) some believe that shale sloughing is caused by filtrate invasion into the

shales, (2) they believe results of formation evaluation methods may be affected by filtrate

invasion, and (3) they believe formation productivity is often affected by filtrate invasion,

especially in low permeability sands. Additives of common usages to control filtration are shown

in Table 2.

Table 2. Additives for the control of filtration rate Bentonite Provides a better basic filter cake

Metal lignosulfonatesReduces filtration by deflocculating the mud also increases the viscosity of

the filtrate. Starts braking down at 300 F. Not very effective above 350 F.

Lignite

Reduces filtration rate by deflocculating and plugging open spaces in filter

cake. Starts breaking down at 300 F. Effective to reduced degrees above

400 F.

Sodium Carboxymethylcellulose,

CMC

Reduces filtration rate by coating solids and sometimes by minimizing

flocculation. Starts breaking down at 300 F.

Starch

Reduces filtration rate by coating solids. Will spoil in a fresh water

environment where pH is less than 11.5. Also a salt concentration of

250,000 ppm will prevent spoiling in any pH water. Breaks down rapidly

when temperature exceeds 275 F.

Baroid Mud Additives

Baroid Petroleum Services Division N.L. Industries, Inc distributes all the additives used in

the mud experiments in the first portion of this lab manual. Brief descriptions of the Baroid mud

additives are shown in Table 3.

Table 3. Baroid mud additives Additive Material Use Features

AQUAGEL

Selected, finely

ground bentonite

clay.

General purpose gel-forming

colloid used to adjust viscosity,

gel strength, and reduce filtrate

loss.

A universally used mud project for both

rotary and cable tool drilling. Yields 100

barrels of 15 centipoises drilling mud per ton

of AQUAGEL.

BARAFOS

Sodium tetra

phosphate in dry

granular form.

A polyphosphate mud thinner.An effective dispersing agent for clays; has

little effect on pH of muds.

BAROID

Processed barite

(barium

sulphate).

Increasing mud density and

making low-solids muds.

Recognized as the industry’s standard mud

weighting material.

CC-16

Modified lignite

in black, free-

flowing power

form.

Thinning and filtration control

in fresh water muds.

Low unit cost. High solubility in normal pH

muds. Stable at high drilling temperatures.

Eliminates or reduces the need for adding

raw caustic soda at the rig. Good tolerance

for soluble contaminants. Complements other

thinners and reduces the need for special

filtration control agents.

65

Table 3. Baroid mud additives (cont.)Additive Material Use Features

GALENA

Pulverized lead

ore with a

specific gravity

of about 6.8

For making ultra-heavy drilling

muds to kill wells of

abnormally high pressure. Also

used to weight cement slurries.

Makes mud weighing up to 321b/gal.

IMPERMEX

Specially

processed, pre-

gelatinized starch

power.

An organic colloid for reducing

filtrate loss of any drilling mud.

Allows continued use of mud that would

otherwise be discarded because of

contamination by salts, acids, cement,

gypsum, anhydrite, and other deleterious

substances. Produces minimum filtration rate

in fresh or salt water.

LOLOSSModified guar

gum.

To control viscosity and

filtration in low-solids muds.

An effective means of controlling viscosity

and filtration in either fresh water or salt

water low-solids mud, while reducing the

amount of formation solids dispersed in these

muds. Particularly effective in brine

workover fluids.

Q-BROXIN

Ferrochrome

lignosulfonate,

non-caking, light

brown, water

soluble powder.

A chemical thinner for drilling

muds, especially for muds

contaminated with salt,

gypsum, or both, or as a general

utility thinner.

Permits use of gyp muds for deep drilling;

allows use of salt water for mud makeup;

emulsifies oil in mud.

QUICK-

GEL

High-yield

bentonite.

To make high viscosity mud

faster than with ordinary clays.

Used particularly in drilling

seismic shot holes and water

wells.

High yield (200 bbl/ton), Easy and fast to

mix. Low cost. Improves wall building. Aids

in preventing lost circulation. Does not

ferment. Reduces water loss. Only half as

much needs to be transported compared to

other bentonites.

SAPPSodium acid

pyrophosphate.

As a thinner, dispersant which

also adds pH control.

Used to lower pH of contaminated muds. Is

very sensitive to concentration.

ZEOGELDry ground

attapulgite clay.

As a suspending agent in

drilling muds of any salt

concentration.

Yields 130 barrels of 15 centipoise mud per

ton in saturated salt water.

66

Tab

le 4

. M

ate

rials

fo

r D

rill

ing

Flu

id S

yst

em

s F

resh

Wate

rM

ud

sF

resh

Wate

rM

ud

s (c

on

t.)

Pro

du

ct T

rad

e N

am

eD

escr

ipti

on

Ma

ker

or

Dis

trib

uto

rP

rod

uct

Tra

de

Na

me

Des

crip

tio

nM

ak

er o

r D

istr

ibu

tor

Alk

atan

Cau

stic

qu

ebra

cho

Mag

cob

arH

igh

Yie

ld

Su

b-b

ento

nit

eM

agco

bar

Aq

uag

elW

yom

ing b

ento

nit

eB

aro

id D

iv.

Nat

ion

alL

ead C

o.

Hy

dro

gel

Ben

ton

ite

Bro

wn

Mu

d C

o.

Atl

as G

el

Wy

om

ing b

ento

nit

eA

tlas

Mud C

om

pan

yH

exap

hos

Phosp

hat

e#W

estv

aco

Atl

as L

ig

Lig

nit

ic c

om

pound

Atl

as M

ud C

om

pan

yH

ydro

pel

Em

uls

ifie

das

phal

t#A

mer

ican

Bit

um

ul

& A

sphal

t

Bar

afo

sS

od

ium

tetr

aph

osp

hat

eB

aro

id D

iv.

Nat

ion

al L

ead C

o.

Hy

dro

carb

Cau

stic

car

bon

ox

Bar

oid

Div

. N

atio

nal

Bar

ium

Car

bo

nit

e B

ariu

m c

arb

onat

eM

agco

bar

Hy

dro

tan

Cau

stic

tannin

Bar

oid

Div

. N

atio

nal

Bar

ium

Car

bo

nit

e B

ariu

m c

arb

on

ate

Mil

whit

e M

ud

Sal

es C

om

pan

yH

.Q.M

. S

tarc

hG

rain

-bas

ed s

tarc

h#

Gib

ralt

er M

iner

als

Bar

oco

Su

b-b

ento

nit

eB

aro

id D

iv.

Nat

ion

alL

ead C

o.

Imp

erm

exP

reg

elat

iniz

ed s

tarc

hB

aro

id D

iv.

Nat

ion

alL

ead C

o.

Ben

exS

odiu

m p

oly

acry

late

#C

her

okee

Lab

ora

tori

esIm

per

mex

Pre

serv

ativ

eF

orm

ald

ehy

de

com

poun

dB

aroid

Div

. N

atio

nal

Lea

d C

o.

Bic

arb.

of

So

da

Bic

arb

onat

e o

f so

da

*#

Ker

o-X

Def

oam

ing

agen

tB

aro

id D

iv.

Nat

ion

alL

ead C

o.

Cau

stic

Soda

So

diu

m h

ydro

xid

e*#

Kw

ik-T

hik

Extr

ahig

h-y

ield

ben

tonit

e M

agco

bar

Car

bo

no

xO

rgan

icth

inner

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Kem

ical

Qu

ick

lim

e #

Dri

l-K

em

Co

ntr

olg

elB

ento

nit

eM

ud

Co

ntr

ol

Lab

ora

tori

esK

emb

reak

Cal

ciu

mli

gn

osu

lfo

nat

eM

arat

ho

n C

hem

ical

Co

rp.

Cas

oP

ota

ssiu

m s

tear

ate

Mud C

ontr

ol

Lab

ora

tori

esK

ylo

Sodiu

mpoly

acry

late

#M

innes

ota

Min

ing &

Mfg

.

Contr

ol

M-D

D

rill

ing d

eter

gen

tM

ud C

ontr

ol

Lab

ora

tori

esL

igco

Min

eral

lig

nit

eM

ilw

hit

e M

ud

Sal

es C

o.

Contr

olt

anL

ignit

eM

ud

Contr

ol

Lab

ora

tori

esL

ime

Cal

cium

hy

dro

xid

e#*

Contr

olc

alC

alci

um

lig

nosu

lfonat

eM

ud

Contr

ol

Lab

ora

tori

esL

ube-

Flo

Gro

und g

ilso

nit

e #G

ibra

lter

Min

eral

s

Cel

lex

So

diu

mca

rbo

xy

met

hy

l-

cel

lulo

se

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Lu

bri

-fil

m

Lig

no

x

Ex

trem

e P

ress

ure

lu

bri

cant

Cal

cium

lig

nosu

lfonat

e

Mil

whit

e M

ud

Sal

es C

o.

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Contr

olo

idP

regel

atin

ized

star

chM

ud C

ontr

ol

Lab

ora

tori

esL

ig-N

o-S

ol

Modif

ied

lignosu

lfat

esA

lpin

e M

ud S

ervic

e

Co

ntr

ols

ol

No

nio

nic

su

rfac

tan

tM

ud

Co

ntr

ol

Lab

ora

tori

esM

acco

gel

Wy

om

ing b

ento

nit

eM

acco

Co

rp.

C-M

-CS

odiu

mca

rboxym

ethy

l-

cell

ulo

se

#E

.I.

duP

ont

Mag

cogel

Mag

cophos

Wy

om

ing b

ento

nit

e

So

diu

m t

etra

ph

osp

hat

e

Mag

cob

ar

Mag

cob

ar

Cro

nox 2

11

Fre

sh w

ater

corr

osi

on

inh

ibit

or

Un

ited

En

gin

eeri

ng

Co

rp.

Mc

Qu

ebra

cho

May

Gel

Qu

ebra

cho

Wy

om

ing b

ento

nit

e

Mag

cob

ar

May

Bro

ther

s, I

nc.

Cy

pan

So

diu

mpo

lyac

ryla

te#A

mer

ican

Cy

anam

id C

orp

. M

ay C

lay

Sub-b

ento

nit

eM

ay B

roth

ers,

Inc.

Cal

tro

lC

alci

um

chlo

ride

Mil

wh

ite

Mu

d S

ales

Co.

May

lig

Min

eral

lig

nit

eM

ay B

roth

ers,

Inc.

Cal

ciu

m C

hlo

ride

Cal

ciu

mch

lori

de

*#

May

star

chP

reg

elat

iniz

ed s

tarc

hM

ay B

roth

ers,

Inc.

Do

wci

de

G

Bac

teri

cid

e#

Do

w C

hem

ical

Co

.M

ayco

lC

alci

um

chlo

ride

May

Bro

ther

s, I

nc.

Dri

sco

se (

Sev

. G

rad

es)

So

diu

m c

arb

oxy

met

hy

l-

cell

ulo

se

#D

rill

ing S

pec

ialt

ies,

Inc.

Mac

o-H

ex.

Mac

cofl

os

Mac

co-L

ig

Com

ple

x p

hosp

hat

es M

iner

al

lig

nit

e

Mac

co C

orp

.

Dak

oli

teP

roce

ssed

lig

nit

e#

No

rth

ern

Ch

emic

al S

ales

M

iko

l S

tarc

hP

reg

elat

iniz

ed s

tarc

h#

Arc

her

-Dan

iels

-Mid

lan

d

Em

uls

ifie

r S

MB

Ino

rgan

ic e

mu

lsif

ier

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Mil

gel

Wy

om

ing b

ento

nit

eM

ilw

hit

e M

ud

Sal

es C

o.

Em

uls

ite

Cau

stic

lig

nit

eM

agco

bar

Mil

Gra

ph

ite

Gra

ph

ite

Mil

wh

ite

Mu

d S

ales

Co.

E P

Mu

dlu

be

Ex

trem

e p

ress

ure

lu

bri

cant

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Mil

star

chP

reg

elat

iniz

ed s

tarc

hM

ilw

hit

e M

ud

Sal

es C

o.

Foxit

Po

lyel

ectr

oly

teM

agco

bar

Mil

Flo

Modif

ied

poly

flav

inoid

com

p.

Mil

whit

e M

ud S

ale

Co.

Gra

ph

ite

Gra

ph

ite

lub

rica

nt

*#

Mu

d-B

acT

risN

itro

(bac

teri

cide)

#C

om

mer

cial

Solv

ents

Co

rp.

Gre

en B

and

Su

b-b

ento

nit

eM

ilw

hit

e M

ud S

ales

Corp

.M

ud F

loc

Clo

ccula

nt

Mud

Con

trol

Lab

ora

tori

es

Gy

psu

mG

ypsu

m*#

Mil

-Nat

an1-2

Cau

stic

queb

rach

oM

ilw

hit

e M

ud S

ales

Co.

Mil

Qu

ebra

cho

Queb

rach

o (

pure

)M

ilw

hit

e M

ud S

ales

Co.

My

-Lo

-Jel

Pre

gel

atin

ized

star

chM

agco

bar

_____________________________________________________

_____________________

*S

ever

al p

ack

agin

g c

om

pan

ies

#S

ever

al d

istr

ibu

tin

g c

om

pan

ies

Pal

cota

nL

ign

osu

lfo

nat

e#

Pac

ific

Lu

mb

er C

om

pan

y

67

Tab

le 4

. M

ate

rials

fo

r D

rill

ing

Flu

id S

yst

em

s (c

on

t.)

Fre

sh W

ate

r M

ud

s (c

on

t.)

Fre

sh W

ate

r M

ud

s (c

on

t.)

Pro

du

ct T

rad

e N

am

eD

escr

ipti

on

Ma

ker

or

Dis

trib

uto

rP

rod

uct

Tra

de

Na

me

Des

crip

tio

nM

ak

er o

r D

istr

ibu

tor

Pal

cota

n 9

50

Red

wood b

ark e

xtr

act

#P

acif

ic L

um

ber

Com

pan

yT

SP

PT

reat

sodiu

m p

yro

phosp

hat

e##B

lock

son C

hem

ical

Pel

tex

Modif

ied

lignosu

lfonat

eA

lam

oL

um

ber

Co.

T-8

Shal

e co

ntr

ol

mud

Mag

cobar

P-9

5C

alif

orn

iacl

ayM

acco

Co

rp.

Un

i-C

alM

od

ifie

dal

ky

l ar

yl

sulf

on

ate

Mil

wh

ite

Mu

d S

ales

Co.

Po

lyto

ne

Tre

ated

lig

nit

e#

Lo

s A

ng

eles

Ch

emic

alU

ni-

Gel

Wy

om

ing b

ento

nit

eU

nit

edE

ng

inee

rin

g C

orp

.

Py

ro,

Anhy

dro

us

Py

rophosp

hat

e#W

estv

aco

Viz

-Thin

Fer

ro-c

hro

mel

ignosu

lfonat

e#C

row

n Z

elle

rbac

h C

orp

.

Par

aform

aldeh

yde

Work

over

Cla

yL

ow

yie

ld w

ork

over

cla

yM

ilw

hit

e M

ud S

ales

Co.

Pre

serv

ativ

e P

araf

orm

ald

ehy

de

*#

Wy

o-J

el 2

00

B

ento

nit

eA

rch

er-D

anie

ls-M

idla

nd

Ph

osp

hat

eC

om

ple

xp

ho

sph

ates

*#

X-C

or

Co

rro

sio

nin

hib

ito

rB

aro

id D

iv.

Nat

ion

al L

ead C

o.

QB

TQ

ueb

rach

o-b

ased

thin

ner

Mud

Contr

ol

Lab

ora

tori

esX

P-2

0C

hro

me

Lig

nit

eM

agco

bar

Q-B

rox

inF

erro

chro

me

lign

osu

lfo

nat

eB

aro

id D

iv.

Nat

ion

alL

ead C

o.

Q-X

Queb

rach

o

com

pound

Queb

rach

o c

om

pound

Mag

cobar

Sa

lt W

ate

r M

ud

s

Queb

rach

oQ

ueb

rach

o*

#A

la-S

ol

Att

apulg

ite

clay

A

lam

o L

um

ber

Co.

Qu

alex

So

diu

m c

arb

oxy

met

hy

l-A

lpin

e G

elA

ttap

ulg

ite

clay

Alp

ine

Mu

d S

ervic

e

ce

llu

lose

#

E.

I. D

uP

on

t A

tlas

Sal

t G

el

Att

apu

lgit

e cl

ayA

tlas

Mu

d C

o.

Qu

ick

-Gel

Ex

tra

hig

h y

ield

ben

ton

ite

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Atl

oso

l S

A

nio

nic

-no

nio

nic

su

rfac

tant

Atl

as C

hem

ical

In

d.

Ray

Flo

H

emlo

ck e

xtr

act

#R

ayonie

r, I

nc.

Att

apulg

us

150

Att

apulg

ite

clay

Min

. &

Chem

. P

hil

ipp

RD

111

Pro

cess

ed l

ignosu

lfonat

e#In

tern

atio

nal

Min

.&

Chem

.C

eox

Em

uls

ifie

rM

ud

Contr

ol

Lab

ora

tori

es

Ran

ger

Pu

re Q

ueb

rach

oP

reu

Qu

ebra

cho

May

Bro

ther

s,In

c.C

on

tro

lfo

amD

efo

amer

Mu

dC

on

tro

lL

abo

rato

ries

Sap

pS

odiu

m a

cid p

yro

pho

sphat

e*#

Cro

nox 6

09

Corr

osi

on i

nhib

itor

Un

ited

En

gin

eeri

ng

Corp

.

Sp

erse

ne

Ch

rom

eli

gn

osu

lfo

nat

eM

agco

bar

Def

oam

er N

o.

23

Mu

d d

efo

amer

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Sh

ale-

Ban

Shal

eco

ntr

ol

com

po

und

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Em

uls

ifie

rS

Nonio

nic

emuls

ifie

r#

Mu

d E

ngin

eeri

ng

Sup

pli

es

Soda

Ash

S

oda

ash

*#

F-S

Cla

yA

ttap

ulg

ite

clay

U

nit

edE

ngin

eeri

ng C

orp

.

So

diu

m B

ich

rom

ate

So

diu

m b

ich

rom

ate

*#

Flo

rig

elA

ttap

ulg

ite

clay

Flo

rid

in C

o.

So

ltex

Mu

d l

ub

rica

nt

#D

rill

ing S

pec

ialt

ies

Co

. F

lori

gel

H-Y

A

ttap

ulg

ite

clay

Flo

rid

in C

o.

Super

-Col

Extr

ahig

h y

ield

ben

tonit

e M

ilw

hit

e M

ud S

ales

Co.

Hev

iwat

erM

ud d

isper

sant

Dow

ell

Div

., D

ow

Chem

.

Super

ligco

Cau

stic

lignit

eM

ilw

hit

e M

ud S

ales

Co.

May

sal

Cla

yA

ttap

ulg

ite

clay

M

ay B

roth

ers,

Inc.

Shal

e-R

ezH

igh

pre

ssure

lubri

cant

Bro

wn M

ud C

o.

Sal

tS

odiu

m c

hlo

ride

*#

Sodap

hos

Phosp

hat

e#W

estv

aco

Sal

tG

elA

ttap

ulg

ite

clay

M

agco

bar

Su

per

ben

Wy

om

ing b

ento

nit

eS

up

erb

ar S

ales

Sal

t-D

rill

Hem

lock

bar

k e

xtr

act

#R

ayo

nie

r, I

nc.

Super

yie

ldS

ub-b

ento

nit

eS

uper

bar

Sal

esS

alt

Wat

er G

elA

ttap

ulg

ite

clay

Mil

whit

e M

ud S

ales

Co.

Super

Queb

rach

oQ

ueb

rach

o m

ixtu

reS

uper

bar

Sal

esS

uper

Sal

Att

apulg

ite

clay

Super

bar

Sal

es

Super

Thin

M

iner

al l

ignit

eS

uper

bar

Sal

es

Su

per

Sta

rch

Pre

gel

atin

ized

sta

rch

Su

per

bar

Sal

es

Sm

ento

xC

emen

tco

nta

min

atio

nA

ir/G

as

Dri

llin

g M

ate

rials

tre

atin

g a

gen

tB

aro

id D

iv.

Nat

ion

al L

ead

Co

.A

fro

xF

oam

ing

agen

t#

Atl

as C

hem

ical

In

du

stri

es

Tan

nex

Qu

ebra

cho c

om

po

un

d

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Atl

as C

orr

osi

on

In

hib

ito

r 1

00

P

ola

r o

rgan

icA

tlas

Mu

d C

o.

Tan

coQ

ueb

rach

o c

om

pound

Mil

whit

e M

ud S

ales

Co.

Am

-9C

hem

ical

gro

ut

#A

mer

ican

Cy

anam

id

Tan

nat

hin

Lig

nit

eM

agco

bar

G-2

Foam

ing a

gen

t D

ow

ell

Div

., D

ow

Chem

ical

To

wer

-Gel

Wy

om

ing b

ento

nit

eB

lack

Hil

ls B

ento

nit

eG

afen

Fa-

1

Fo

amin

g a

gen

t fr

esh

to

mo

d.

salt

An

tara

Chem

ical

Tre

atC

aust

iciz

ed l

ignit

eA

tlas

Mu

d C

o.

Gaf

en F

a-5

F

oam

ing

ag

ent,

satu

rate

d s

alt

An

tara

Chem

ical

________________________

___________________________________________________

*S

ever

al p

ack

agin

g c

om

pan

ies

#S

ever

al d

istr

ibu

tin

g c

om

pan

ies

68

Tab

le 4

. M

ate

rials

fo

r D

rill

ing

Flu

id S

yst

em

s (c

on

t.)

Air

/Gas

Dri

llin

gM

ate

rials

(con

t.)

Inv

ert

Em

uls

ion

an

d O

ilM

ud

s(c

on

t.)

Pro

du

ct T

rad

e N

am

eD

escr

ipti

on

Ma

ker

or

Dis

trib

uto

rP

rod

uct

Tra

de

Na

me

Des

crip

tio

nM

ak

er o

r D

istr

ibu

tor

Gaf

en F

a-7

Fo

amin

g a

gen

t, f

resh

& s

alin

eA

nta

ra C

hem

ical

Inv

erti

nE

mu

lsif

ier

Do

wel

l D

iv.,

Dow

Ch

emic

al

Hal

lib

urt

on-S

orb

Wat

erab

sorb

ing a

gen

tH

alli

bu

rto

n C

o.

Jel-

Oil

Oil

mu

dM

agco

bar

Ho

wco

-Su

ds

Su

rfac

tant,

fo

amin

g a

gen

tH

alli

bu

rto

n C

o.

Ken

Oil

O

il m

ud

#K

en C

orp

.

Hy

dro

-Lok

Wat

er S

huto

ff p

last

ic s

lurr

yH

alli

burt

on C

o.

Ken

-X C

once

ntr

ate

1

Inver

tE

muls

ifie

r#K

en C

orp

.

Oil

fos

Def

locc

ula

tin

gag

ent

#M

on

san

toC

hem

ical

Ken

-X C

on

cen

trat

e 2

S

tab

iliz

er (

wei

ght)

#K

en C

orp

.

OK

Liq

uid

F

oam

ing A

gen

t #P

roct

or

& G

amble

K

en-X

Conce

ntr

ate

3

Sta

bil

izer

(te

mper

ature

)#

Ken

Corp

.

Sy

nfo

amF

oam

ing A

gen

t M

ud C

ontr

ol

Lab

ora

tori

esO

B M

ixfi

x

Vis

cosi

ty r

educe

rO

il B

ase,

Inc.

Ter

git

ol

NP

-35

Nony

l phen

yl

poly

ethy

lene

OB

Gel

T

o i

ncr

ease

vis

cosi

tyO

il B

ase,

Inc.

gly

col

eth

er#

Un

ion

Car

bid

eC

hem

ical

sP

etro

ton

eO

il m

ud

su

spen

din

g a

gen

tB

aroid

Div

. N

atio

nal

Lea

d C

o.

Ter

git

ol

NP

X

Nony

l phen

yl

poly

ethy

lene

Pep

tom

agic

Cru

de

oil

-bas

edfl

uid

Oil

Bas

e, I

nc.

gly

col

eth

er#

Un

ion

Car

bid

eC

hem

ical

sP

erm

-Bas

eO

il m

ud

co

nce

ntr

ate

Mac

co C

orp

.

Ter

git

ol

TM

NT

rim

ethy

ln

ony

l et

her

of

Per

m-W

ate

Cal

ciu

m c

arb

onat

eM

acco

Co

rp.

po

lyet

hy

lene

gly

col

#U

nio

n C

arb

ide

Ch

emic

als

Pro

tect

om

agic

Oil

dis

per

sed a

sph

alt

Oil

Bas

e, I

nc.

Wel

l-F

oam

FS

Fo

amin

g a

gen

t W

ell

Co

mp

leti

on

s, I

nc.

Pro

tect

o-M

ul

Co

nce

ntr

ate

for

inv

ert

Wel

l-F

oam

3

Fo

amin

g a

gen

t W

ell

Co

mp

leti

on

s, I

nc.

e

mu

lsio

n

Mag

cob

ar

Wel

l-F

oam

917

Corr

osi

on i

nhib

itor

Wel

l C

om

ple

tions,

Inc.

N

o-B

loc

Inver

tem

uls

ion f

luid

M

agco

bar

Wel

l-P

arch

Dry

in a

nd

an

ti-b

alli

n a

gen

tW

ell

Co

mp

leti

on

s, I

nc.

Sp

ecia

l A

dd

itiv

e 4

7

To

im

pro

ve

susp

ensi

on

pro

per

ties

Oil

Bas

e, I

nc.

Spec

ial

Addit

ive

58

To i

mpro

ve

susp

ensi

on,

gel

pro

per

ties

Oil

Bas

e, I

nc.

Th

erm

-Oil

Inv

ert

Em

uls

ion

co

nce

ntr

ate

Mil

wh

ite

Mu

d S

ales

Co.

Inver

t E

mu

lsio

n a

nd

Oil

Mu

ds

Low

Soli

ds

Mu

ds

Atl

as-I

nver

t 4

00

Poly

oxy

ethy

lene

pro

duct

A

tlas

Mud C

o.

All

oid

Pre

gel

atin

ized

star

chA

lpin

e M

ud

Ser

vic

e

Bla

ck M

agic

Sup

erm

ixF

luid

fo

r hig

hte

mp

. w

ells

O

il B

ase,

Inc.

An

ti-F

oam

Cap

ryl

alco

hol

Mil

wh

ite

Mu

d S

ales

Co.

Bla

ck M

agic

Pre

mix

O

il f

luid

, n

ot

hig

h w

eig

ht

Oil

Bas

e, I

nc.

Atl

as E

mu

lso

500

No

n-i

on

ic s

urf

acta

nt

Atl

as M

ud

Co

.

Ch

emic

al V

A

ddit

ive

to B

lack

Mag

ic,

im

pro

ve

gel

Oil

Bas

e, I

nc.

Atl

as D

rill

ing

Surf

acta

nt

Anio

nic

surf

acta

nt

Atl

as M

ud C

o.

Ch

emic

al W

Tre

atin

gag

ent

for

Bla

ck M

agic

Oil

Bas

e, I

nc.

Atl

asfl

oc

Flo

ccu

lati

ng g

um

Atl

as M

ud

Co

.

Co

ntr

ol

Inver

tO

il m

ud

co

nce

ntr

ate

Mu

d C

on

tro

l L

abo

rato

ries

Bar

aflo

cC

lay

flo

ccula

nt

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Co

ntr

ol

Em

uls

ion

Oil

N

on

ion

ic s

urf

acta

nt

Mu

d C

on

tro

l L

abo

rato

ries

Dri

llte

xG

uar

gu

m#

T.

M.

Du

che

& S

on

s, I

nc.

Dri

loil

Oil

mu

d c

once

ntr

ate

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Dri

sco

seS

od

ium

car

bo

xy

met

hy

l-

cell

ulo

se

#D

rill

ing S

pec

ialt

ies

Dri

ltre

atO

il m

ud

sta

bil

izer

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Lo

loss

Gu

m G

uar

B

aro

id D

iv.

Nat

ion

alL

ead C

o.

Du

rato

ne

Oil

mu

d f

iltr

atio

n c

on

trol

ag

ent

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Lu

be

Flo

w

Sh

ale

con

tro

l#

Gib

ralt

erM

iner

als

Eco

no

mag

icC

rud

e-o

il b

ased

com

ple

tio

n f

luid

Oil

Bas

e, I

nc.

Mac

-O-M

ul

No

n-i

on

ic s

urf

acta

nt,

emu

lsif

ier

Mac

co C

orp

.

E-Z

Mu

l B

aro

id D

iv.

Nat

ion

alL

ead C

o.

Mu

dfl

oc

Hig

hly

act

ive

flocc

ula

tin

g

agen

t

Mud C

ontr

ol

Lab

ora

tori

es

Gel

ton

eO

il m

ud

gel

lin

gag

ent

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Sep

aran

Flo

ccu

lati

ng a

gen

tM

ilw

hit

e M

ud

Sal

es C

o.

Ho

t L

ime

Var

ifat

lim

e*

#

Inv

erm

ul

Oil

mu

d e

mu

lsif

ier

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

________________________

___________________________________________________

*S

ever

al p

ack

agin

g c

om

pan

ies

#

Sev

eral

dis

trib

uti

ng

co

mp

anie

s

Em

uls

ifie

r fo

r C

aCl

solu

tio

ns

in

oil

69

Tab

le 4

. M

ate

rials

fo

r D

rill

ing

Flu

id S

yst

em

s (c

on

t.)

Su

rface

Act

ive

Agen

ts

Wei

gh

tin

g M

ate

ria

ls

Pro

du

ct T

rad

e N

am

eD

escr

ipti

on

Ma

ker

or

Dis

trib

uto

rP

rod

uct

Tra

de

Na

me

Des

crip

tio

nM

ak

er o

r D

istr

ibu

tor

Alu

min

um

Ste

arat

eA

lum

inu

m s

tear

ate

*#

Ala

-Bar

Bar

ite

(bar

ium

su

lfat

e)A

lam

o L

um

ber

Co

.

Atl

asD

rill

ing

Su

rfac

tan

t 1

00

An

ion

icsu

rfac

e ac

tiv

e

em

uls

ifie

r

Atl

as M

ud

Co

. A

lbar

Bar

ite

Alp

ine

Mu

d S

ervic

e

Atl

as D

rill

ing

Su

rfac

tan

t 2

00

Pet

role

um

sulf

onat

eA

tlas

Mud C

o.

Atl

as B

ar

Bar

ite

Atl

as M

ud C

o.

Atl

as D

rill

ing

Su

rfac

tan

t 3

00

No

nio

nic

su

rfac

tan

tA

tlas

Mu

d C

o.

Bar

oid

Bar

ite

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Atl

as C

muls

o 5

00

Nonio

nic

surf

acta

nt

Atl

as M

ud C

o.

Contr

olb

arB

arit

eM

ud C

ontr

ol

Lab

ora

tori

es

Atl

oso

lM

ixed

est

ers

#A

tlas

Ch

emic

al I

nd

ust

ries

Dri

-Jo

bL

ow

gra

vit

y b

arit

eM

acco

Co

rp.

Ceo

xS

olu

ble

oil

-ty

pe

surf

acta

nt

Mu

d C

on

tro

l L

abo

rato

ries

Dri

llin

g b

ar

Bar

ite

Dri

llin

g M

ud

, In

c.

Co

n D

et

An

ion

ic d

eter

gen

tB

aro

id D

iv.

Nat

ion

al L

ead C

o.

G-7

Su

per

Wei

ght

Iro

n-a

rsen

ic c

om

po

un

dM

agco

bar

Co

ntr

ol

M-D

L

ow

so

lid

s, m

ud a

dd

itiv

e M

ud

Co

ntr

ol

Lab

ora

tori

esG

alen

aL

ead s

ulf

ide

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Contr

ol

Em

uls

ion O

ilA

nio

nic

surf

ace

acti

ve

em

uls

ifie

r

Mud C

ontr

ol

Lab

ora

tori

esIn

ver

tin W

ate

Aci

d-s

olu

ble

mat

eria

l D

ow

ell

Div

., D

ow

Chem

ical

Co

ntr

ol

Flo

wO

il-s

olu

ble

su

rfac

tant

Mu

d C

on

tro

l L

abo

rato

ries

Mac

cow

ate

Bar

ite

Mac

co C

orp

.

Co

ntr

ols

ol

Non

ion

ic s

urf

acta

nt

and

em

uls

ifie

r

Mud C

ontr

ol

Lab

ora

tori

esM

agco

bar

Bar

ite

Mag

cobar

D-D

Mud

det

ergen

tM

agco

bar

May

bar

Bar

ite

May

Bro

ther

s

Dri

llin

g M

ilk

O

/W E

mu

lsif

ier

Mag

cob

arM

il-B

arB

arit

eM

ilw

hit

e M

ud

Sal

es C

o.

Dri

llL

ub

eS

urf

acta

nt,

EP

lub

rica

nt

#M

ud

En

gin

eeri

ng

Su

pp

lies

O

B H

evy

wat

eB

arit

eO

il B

ase,

Inc.

DM

EF

or

com

poundin

g s

urf

acta

nt

muds

#A

nta

ra C

hem

ical

sO

B W

ate

Cal

ciu

mca

rbo

nat

eO

il B

ase,

Inc.

Em

uls

ifie

r F

N

onio

nic

surf

acta

nt

#M

ud E

ngin

eeri

ng S

uppli

es

Super

bar

Bar

ite

Super

bar

Sal

es

Em

uls

ifie

r S

N

onio

nic

surf

acta

nt

#M

ud E

ngin

eeri

ng S

uppli

es

Uni-

Bar

Bar

ite

Unit

edE

ngin

eeri

ng

Corp

.

Mac

o-M

ul

No

nio

nic

su

rfac

tan

t,

em

uls

ifie

r

Mac

co C

orp

.Y

ub

a B

arit

eB

arit

eY

ub

a M

illi

ng

Div

.

Mac

o-L

ub

eS

urf

acta

nt,

EP

lub

rica

nt

Mac

co C

orp

.

Mag

con

ate

Pet

role

um

sulf

on

ate

Mag

cob

ar

Mil

whit

e M

-D

Low

-soli

ds

mud a

ddit

ive

Mil

whit

e M

ud S

ales

Co.

Mil

-Olo

xV

eget

able

oil

soap

M

ilw

hit

e M

ud S

ales

Co.

Olo

xN

eutr

aliz

ed s

oap

#D

ril-

Kem

, In

c.

San

tom

erse

Sodiu

m a

lky

lar

yl

sulf

onat

e#M

onsa

nto

Chem

ical

See

co-M

ul

Veg

etab

le o

il s

oap

#C

ross

ett

Ch

emic

als

Tri

mu

lso

Em

uls

ifie

rB

aro

id D

iv.

Nat

ion

alL

ead C

o.

Wh

ite

Mag

ic

No

n-F

luo

resc

ing e

mu

lsif

ier

Oil

Bas

e, I

nc.

_____________________________________________________

______________________

*S

ever

al p

ack

agin

g c

om

pan

ies

#

Sev

eral

dis

trib

uti

ng

co

mp

anie

s

70

Tab

le 4

. M

ate

rials

fo

r D

rill

ing

Flu

id S

yst

em

s (c

on

t.)

Lost

Cir

cula

tion

Ad

dit

ives

Lo

st C

ircu

lati

on

Ad

dit

ives

(co

nt.

)

Pro

du

ct T

rad

e N

am

eD

escr

ipti

on

Ma

ker

or

Dis

trib

uto

rP

rod

uct

Tra

de

Na

me

Des

crip

tio

nM

ak

er o

r D

istr

ibu

tor

Ala

-Fib

erF

ibro

us

mat

eria

l A

lam

o L

um

ber

Co

.L

eath

er S

eal

Lat

her

fib

ers

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Ala

-Fla

ke

Sh

red

ded

cel

loph

ane

flak

esA

lam

o L

um

ber

Co

.L

eath

-OL

eath

er f

iber

s M

ilw

hit

e M

ud

Sal

es C

o.

Ala

-Mic

aS

hre

dded

mic

a A

lam

o L

um

ber

Co.

Mag

co-F

iber

Shre

dded

wood f

iber

M

agco

bar

Ala

-Plu

gG

rad

ed w

aln

ut

shel

lsA

lam

o L

um

ber

Co

.M

agco

-Mic

aG

rad

ed m

ica

Mag

cob

ar

Als

eal

Can

e, w

ood f

iber

ble

nd

Alp

ine

Mud S

ervic

eM

aste

rbri

dge

Extr

a-co

urs

e al

mond s

hel

lsM

aste

rsea

l S

ales

Corp

.

Atl

as F

iber

S

ugar

can

e bag

asse

Atl

as M

ud C

o.

Mas

terp

lug

Shap

ed r

ubber

M

aste

rsea

l S

ales

Corp

.

Atl

as M

ica

Siz

ed m

ica

Atl

asM

ud C

o.

Mas

ters

eal

Alm

ond

shel

lsM

aste

rsea

l S

ales

Corp

.

Ala

-Shel

lP

ecan

shel

lsA

lam

o L

um

ber

Co.

May

fiber

Can

e, w

ood f

iber

ble

nd

May

Bro

ther

s

Alf

lake

Shre

dded

cel

loph

ane

flak

esA

lpin

e M

ud

Ser

vic

eM

ayfl

akes

Shre

dded

cel

lophan

e fl

akes

May

Bro

ther

s

Alp

ine

Mic

aG

rad

ed m

ica

Alp

ine

Mu

d S

ervic

eM

aym

ica

Gra

de

mic

aM

ay B

roth

ers

Asp

en F

iber

A

spen

fib

ers

#A

spen

Fib

er C

o.

Mic

atex

Mic

aB

aro

id D

iv.

Nat

ion

alL

ead C

o.

Bar

k-S

eal

Shre

dd

ed t

ree

bar

k

Alp

ine

Mud

Ser

vic

eM

il-C

edar

Plu

g

Ced

ar w

oo

d f

iber

s M

ilw

hit

e M

ud

Sal

es C

o.

Bea

ver

Dam

G

round g

ilso

nit

e G

ibra

lter

Min

eral

sM

il-F

iber

Sugar

can

e bag

asse

Mil

whit

e M

ud S

ales

Co.

Bri

stex

Ho

g b

rist

les

#B

rist

ex C

o.

Mil

flak

eS

hre

dd

ed c

ello

ph

ane

flak

esM

ilw

hit

e M

ud

Sal

es C

o.

Bri

stex

-Sea

lH

og

bri

stle

s an

d c

ott

on

lint

#B

rist

exC

o.

Mil

mic

aG

rad

ed m

ica

Mil

wh

ite

Mu

d S

ales

Co.

Cel

-Fla

kes

Gro

und

cell

ophan

eU

nit

edE

ngin

eeri

ng C

orp

. M

il-P

lug

Pulv

eriz

ed w

alnut

shel

ls

Mil

wh

ite

Mu

d S

ales

Co.

Cel

l-O

-Phan

eS

hre

dded

cel

loph

ane

flak

es#A

rno

ld &

Cla

rke

Mil

Sea

l W

ood c

hip

s M

ilw

hit

e M

ud S

ales

Co.

Cel

l-O

-Sea

lS

hre

dded

cel

lophan

e fl

akes

Mag

cobar

Mil

-Wool

Fib

rous

min

eral

wood

Mil

whit

e M

ud S

ales

Co.

Ced

ar S

eal

Ced

ar f

iber

#D

ril-

Kem

, In

c.M

ud F

iber

C

ane

fiber

sM

agco

bar

Cer

t-N

-Cea

lD

elay

ed a

ctio

n b

ento

nit

e,

gra

n.

Mat

.#M

acco

Corp

.

Mic

a

Nu

t P

lug

Siz

ed m

ica

Gro

und

wal

nut

shel

ls

#U

.S.

Mic

a C

o.Jo

lex

Mic

a

Mag

cob

ar

Ch

ek-L

oss

Siz

ed n

eop

rene

rubber

Mil

whit

e M

ud S

ales

Co.

Oil

Pat

ch

Gro

und w

alnut

shel

lsM

ud

Con

trol

Lab

ora

tori

es

Ch

ip-S

eal

Sh

red

ded

wo

od

fib

erM

agco

bar

Pal

co S

eal

Pro

cess

ed r

edw

oo

d f

iber

s #

Pac

ific

Lu

mb

er C

o.

Con

trol

Fib

erF

ibro

us

mat

eria

l M

ud C

ontr

ol

Lab

ora

tori

es

Phen

o-S

eal

Gro

und

pla

stic

#

Con

trol

Wood

Aci

d-s

olu

ble

min

eral

wood

Mud

Contr

ol

Lab

ora

tori

es

Poly

flak

eO

ilso

luble

fil

m

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Cott

onse

ed H

ull

s C

ott

onse

ed h

ull

s*#

Poly

-Plu

gF

iber

s an

d p

last

icC

her

okee

Lab

ora

tori

es

Chem

ical

W

Agen

t to

form

gel

pil

lsO

il B

ase,

Inc.

Poz-

Plu

gW

ood c

hip

s #P

oz-

Plu

g C

orp

.

Ch

rom

e L

eath

erS

hre

dd

ed l

eath

erA

lam

o L

um

ber

Co

.P

lug

-Git

Wo

od

fib

ers

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Dic

k’s

Mud S

eal

Gro

und n

aner

#D

ick’s

Mud S

eal

Co.

Pla

stic

Sea

l G

round f

orm

ica

Ala

mo L

um

ber

Co.

Fea

ther

Sto

p

Fea

ther

sM

ilw

hit

e M

ud S

ales

Co.

Rubber

Sea

l G

round r

ubber

A

tlas

Mud C

o.

Fib

er-S

eal

Ble

nd

edfi

ber

sM

agco

bar

Sea

lfla

kes

Fra

gm

ente

d c

ellu

lose

Mu

d C

on

tro

l L

abo

rato

ries

Fib

erte

xC

ane

fib

ers

Bar

oid

Div

. N

atio

nal

Lea

d C

o.

Sil

vac

elF

ir a

nd

bal

sum

fib

er#

Way

erhau

ser

Tim

ber

Co

.

Fo

rmap

lug

Cla

y-c

emen

tM

agco

bar

Sto

p-I

tC

edar

wo

od f

iber

s #

Tex

as C

edar

Sea

l C

o.

Form

asea

lA

ir b

low

n a

sphal

tO

il B

ase,

Inc.

Str

ata-

Sea

lE

xpan

ded

per

lite

#G

reat

Lak

es C

arbon C

orp

.

Fla

xse

alG

round

fla

x s

hiv

eA

rcher

-Dan

iels

-Mid

land

Super

Fib

er

Can

e, w

ood f

iber

sS

up

erbar

Sal

es

Hy

-Sea

lG

rou

nd

pap

erB

aro

id D

iv.

Nat

ion

al L

ead C

o.

Su

per

Sea

l S

hre

dd

ed c

ello

phan

e fl

akes

Su

per

bar

Sal

es

Jelf

lake

Cel

lop

han

e fl

akes

#D

ow

ell

Div

. D

ow

Chem

ical

Su

per

Mic

a G

rad

ed m

ica

Su

per

bar

Sal

es

Ko-S

eal

Gra

nula

ted c

orn

cobs

Mud

Contr

ol

Lab

ora

tori

esS

uper

bri

dge

Expan

ded

per

lite

Mud

Contr

ol

Lab

ora

tori

es

Kin

g S

eal

Tex

tile

fib

ers

Ala

mo

Lu

mber

Co

.T

uff

ern

ell

Wal

nu

t sh

ells

Mac

co C

orp

.

Kre

vic

e K

log

Dro

p b

ags

of

gra

nula

r

ben

tonit

eB

aro

id D

iv.

Nat

ion

alL

ead C

o.

Wal

l-N

ut

Wal

nu

t P

lug

Nuts

hel

ls

Wal

nut

shel

ls

Bar

oid

Div

. #D

ugdal

e &

Sons

Nat

ion

al L

ead C

o.

Lea

ther

Flo

c L

eath

erfi

ber

sM

agco

bar

___________________________________________________________________________

*S

ever

al p

ack

agin

g c

om

pan

ies

#S

ever

al d

istr

ibu

tin

g c

om

pan

ies

71

APPENDIX B

CEMENT ADDITIVES

72

CEMENT ADDITIVES1

Cement additive materials may be classified as follows:

1. Extenders

2. Accelerators

3. Retarders

4. Weighting Materials

5. Lost Circulation Control

6. Dispersants

7. Water Loss Control

8. Special Materials

Extenders

The use of extenders in cement has allowed the reduction of the slurry density, increase in

the slurry yield, and reduction of cost. Water is the primary extender; however, if the

recommended water content of the cement is exceeded, there is free water. The addition of

extenders will alleviate this problem. Another reason for using extenders in cement is to reduce

the hydrostatic pressure on the formation. The widely used extenders are:

1. Bentonite (montmorillonite)

2. Natural Pozzolan

3. Artificial Pozzolan (Flyash)

4. Perlites (Expanded)

5. Diatomaceous Earth

6. Sodium Silicate

7. Kolite and Gilsonite

Bentonite

Bentonite or commonly referred to as gel may be dry blended with the cement or prehydrated

in the mix water. The API recommended water is 5.3% for each 1% bentonite added to the dry

cement. If the bentonite is prehydrated in the mix water, you may use one fourth the amount of

bentonite dry blended (that is 1:4 ratio). Bentonite may be used from 2 to 25% by weight of

cement; however, it is normally used in the range of 2 to 16%. Table 5 shows the effect of

bentonite on the slurry properties of typical Class H cement.

1 Calvert, D.B., Cementing Materials, Cementing Symposium, Ardmore, OK, May 1977..

73

Table 5. Effect of bentonite on the slurry properties of Class H cement (using 38% water by weight of cement)

Bentonite (%) Water Content (gal/sk) Slurry Weight (lb/gal) Slurry Yield (Cu ft/sk)

0 4.29 16.45 1.05

2 5.49 15.4 1.22

4 6.69 14.7 1.39

8 9.07 14.1 1.56

12 11.48 12.9 2.08

The addition of bentonite reduces the compressive strength and normally will reduce the

thickening time.

Natural Pozzolan

Natural pozzolans have been used for a number of years blended with cement and bentonite

to design reduced weight cement systems. It is used primarily in the California operations.

Artificial Pozzolan (Flyash)

Artificial pozzolan or flyash as it’s commonly referred to has been used widely in the

cementing operations. It normally is blended with cement and bentonite to develop the

lightweight systems.

Perlite (Expanded)

Perlite is a volcanic material that is crushed and then heated to expand it. Perlites were

widely used in field operations; however, it is used very little today.

Diatomaceous Earth

Diatomaceous earth is a special grade of material that may be used to design low density

cement systems. It normally is used at a concentration of 10 to 40% by weight of cement. A

density of about 11 lb/gal using 40% diatomaceous earth by weight of cement.

Sodium Silicate

Sodium silicate has been used in the past few years as a lightweight material because it

allows for large quantities of water to be added while using only small amounts of the additive. It

normally is used at a ratio of 1 to 3% by weight of cement.

Kolite and Gilsonite

Kolite is a graded coal whereas gilsonite is an asphalt material. They both may be used to

reduce the density; however, their primary use is as a lost circulation material.

74

Accelerators

Accelerators are normally used at low temperature conditions to accelerate the thickening

time and increase the early strength development of the cement. The commonly used accelerators

are:

1. Calcium chloride

2. Sodium chloride

3. Calcium sulfate

4. Sodium silicate

Calcium Chloride

Calcium chloride is the most widely used cement accelerator used in field operations. It is

used normally at a concentration of 2 to 4% by weight of cement. It may be added to the dry

cement or it may be mixed in the mix water. Calcium chloride does not affect the ultimate

compressive strength of the set cement. Table 6 shows the effect of calcium chloride on strength

development of set cement.

Table 6. Effect of Calcium Chloride on Set Cement 60°F 80°F 110°FCalcium

Chloride (%) 6 hrs. 12 hrs. 6 hrs. 12 hrs. 6 hrs. 12 hrs.

0 Not set 80 60 450 425 925

2 140 650 350 1190 1350 2500

Sodium Chloride

Sodium chloride is also an effective accelerator for cement systems. It normally is used at a

concentration of 3 to about 10% by weight of mix water to obtain total acceleration. It should

also be noted that at high concentrations (20% by weight of water) sodium chloride becomes a

retarder.

Calcium Sulfate

The himihydrate form (plaster of paris) is the most common calcium sulfate used. It may be

used up to 100% by weight of cement. Very short thickening times may be obtained with these

systems.

Sodium Silicate

The DiacelR cement systems developed by Phillips is the primary use of sodium silicate as an

accelerator. It is used mainly when CMHEC (carboxmethyl hydroxyethyl cellulose) water loss

control material has been added to the system.

75R Trademark

Retarders

Retarders are used in cement systems where bottomhole temperatures are such that adequate

thickening times cannot be obtained with neat cements. Retarders should be compatible with

other additives that might be used in cement systems.

Retarders are designed not only to retard the set of cement, but they may function to increase

or decrease viscosity. The common retarders are:

1. Lignin materials

2. Organic blends

3. Celluloses

4. Inorganic materials

Lignin

Lignin is the retarder most commonly used. They are effective over a wide range of

temperature; however, without a retarder supplement, they are not used at bottomhole circulating

temperatures above about 200°F. The lignin will also reduce slurry viscosity. Normal use is from

0.1 to 1.0% by weight of cement depending on the class of cement. Table 7 shows the effect of

lignin retarder on a Class H cement system.

Table 7. Effect of Lignin Retarder on a Typical Class H Cement Thickening Time (hours: min) API Casing Cementing Tests for

Simulated Well Depth (ft) of:Retarder

(%)8,000 10,000 12,000 14,000

0.0 1:56 1:26 1:09 1:00

0.2 2:15 2:12 1:38 1:25

0.3 3:38 2:40 2:14 1:58

0.4 4:42 3:36 3:10 2:58

Organic Materials

The organic retarders are offered to the industry by all the service companies. Most of these

retarder systems are property in nature and the cement systems are designed for specific well

conditions.

Celluloses

Cellulose materials were initially developed as water loss control materials for cement;

however, it is also found that retardation could also be obtained with these materials. A

secondary function of the cellulose materials is that they will increase the viscosity of the slurry.

The most common cellulose used is CMHEC.

76

Inorganic Materials

Saturated sodium chloride water or salt saturated cement is the most common inorganic

retarder used. Salt saturated cements retard over a wide temperature and at low temperatures may

cause extended thickening times. Formation properties will normally determine salt

concentration.

Weighting Materials

In some areas, normal cement densities are not capable of controlling down hole well

conditions. An increase in the slurry density will require the addition of a weighting material. An

acceptable weighting material should not (1) affect the overall properties of the slurry, (2) not

interfere with well operations and (3) be chemically inert. The most common weighting materials

are:

1. Hematite (Iron oxide)

2. Ilmenite (Iron - titanium oxide)

3. Barite (Barium sulfate)

Hematite

Hematite is an iron oxide with a specific gravity of approximately 5. It is the most widely

used weighting agent in field operations. It is used at a concentration of about 5 pounds to 50

pounds per sack of cement depending on well conditions. It is in the fine to semi-fine particle

size range and may require additional mix water to be added.

Ilmenite

Ilmenite is an iron-titanium oxide with a specific gravity of approximately 4.6. It is used

from about 5 pounds to 50 pounds per sack; however, it is considered to be a coarse ground

particle and slurry properties should be considered.

Barite

Barite is a fine grind barium sulfate with a specific gravity of approximately 4.3. Barite is not

widely used in cement slurry design today because of its fine grid and high water requirement.

Lost Circulation Control

Lost circulation or loss of returns is a problem that is encountered in cementing operations

during placement of slurry in fractured zones (either natural or induced) and/or cavernous type

formations. Lost circulation may be controlled in different ways; however, a reduction in slurry

77

density combined with a budging material and many times a flake material is effective. The most

common lost circulation materials are:

1. Kolite

2. Gilsonite

3. Cellophane flakes

Kolite

Kolite is a graded coal that has been prepared as an aid in lost circulation. It may be used

over a concentration range of 1 to 25 pounds per sack, but common use range is 5 to 20 pounds.

Kolite does require that additional water be used for mixing and for each 25 pounds of kolite, an

additional one gallon of mix water should be used.

Gilsonite

Gilsonite is an asphalt material which is mined and graded to a specific particle size range to

aid in lost circulation control. It may be used at a concentration of 5 to 50 pounds per sack.

Normal usage range is 5 to 25 pounds. The water requirement for gilsonite is for each 25 pounds

added to the system, an additional one gallon of water should be used.

Cellophane Flakes

Cellophane flakes are used in conjunction with the granular type materials to aid in building

a bridging system. They are normally used at a concentration of to ½ pound per sack of

cement. There are also a number of specialty cement systems designed to aid in lost circulation

control. The most common are (1) Gypsum cement (Calseal or Gypseal), (2) Gypsum - Portland

cement blends, (3) gel cement and (4) Diesel oil - cement or diesel oil - bentonite blends. Well

conditions in most cases will indicate which system may be best to solve the lost circulation

problem.

Dispersants

The use of dispersants allowed the application of turbulent flow cementing be performed at

practical pump rates. Slurries containing dispersants have a reduced viscosity which allows

lower pressures on the formation during placement of the slurry. The common dispersants are:

1. Alkyl aryl sulfonates (powder and liquid)

2. Lignin

3. Inorganic salts

4. Organic acids

78

Alkyl aryl Sulfonates

The sulfonates are the most widely used dispersants because of the wide temperature range

and overall effect on slurry properties. Another major benefit of dispersants in cement is the

ability to design reduced water or densified cements. Typical Class H cement may be increased

in weight to about 17.5 pounds per gallon using a dispersant and no weighting material. Table 8

shows the effect of a sulfonate dispersant or critical pump rate (Qc) at given well conditions.

Table 8. Effect of sulfonate dispersant or critical pump rate (Qc)

Cement System Dispersant (%)Critical Pump Rate, Qc 4-1/2”

Pipe in 7-7/8” Hole

Class H cement 0 17 BPM

Class H cement 1.0 4 BPM

Pozzolan: Cement Blend 0 22 BPM

Pozzolan: Cement Blend 1.0 5 BPM

The sulfonate dispersants are compatible with most cement materials; however, salt

concentrations (greater than 18% by weight of water) will have a detrimental effect and should

be tested before use.

Lignin

Lignins have a thinning effect on many cement systems; however, they also retard at low

temperatures and, therefore, are limited somewhat in their overall use. The most common use of

lignin as dispersants is in the high-gel cement systems.

Inorganic Salts

Sodium chloride is the most common inorganic salt used as a dispersant. It is most effective

in the pozzolan; cement blends, bentonite and diatomaceous earth systems.

Organic Acids

Organic acids are used primarily as retarders in cement; however, they will also show a

thinning effect on many cement systems. Well conditions will dictate their use in most cases.

Water Loss Control Materials

A neat cement system when tested under API conditions (Fluid Loss) will show a 30-minute

loss of greater than 1000 cc. The loss of cement filtrate may cause formation damage, premature

setting of the cement, inability to place the cement, and unsuccessful squeeze cement operations.

A water loss control material allows for the development of a filter cake on the formation face,

thereby control of the slurry properties. The most common materials are:

79

1. Cellulose materials

2. Polymers (Liquid)

Cellulose materials

The cellulose materials are the most widely used in water loss control. They are effective in

most cement systems used in the field. Their usage range will vary from 0.5 to 1.5% by weight

of cement. Cellulose presently used may be affected by the common inorganic salts (calcium

chloride, sodium chloride and potassium chloride).

Polymers (Liquid)

A very effective water loss control material was introduced in the late 1960’s which must he

added to the mix water. It is effective over a wide temperature range and has little effect on the

slurry properties from the standpoint of thickening time and compressive strength. It is normally

used in the range of 0.1 to 0.5 gallons per sack of cement.

Special Materials

There are a number of additives that are used in cement slurry design to build specific

properties.

Mud decontaminates are used to decrease the effect of lignin type muds on the set properties

of the cement. They are normally used at a concentration of 1.0% by weight of cement.

The use of fine silica (silica sand and silica flour) is normally added to a cement system

which is to be exposed to high temperatures (may vary depending on cement system) to prevent

loss of strength. Fine silica is compatible with all API cements and normally will be used as a

concentration of 20 to 40% by weight of cement. Additional water is usually required for mixing

when fine silica is used.

There are other materials which have application such as latex, radioactive tracers, fibers,

special lightweight cements, expanding cement, washes, spacers, and antifoam materials.

There is considerable information developed by the service companies in regard to the

properties of the cementing materials that are discussed in this article. Some of the materials may

vary in chemical nature; however, they are designed to perform for your specific well conditions.

Attached is one of the most recent comparative listings of cement materials used by the

cementing service companies.

80

Tab

le 9

. C

EM

EN

T P

RO

DU

CT

CO

MP

AR

ISO

N -

CH

AR

TC

OM

PE

TIT

IVE

EQ

UIV

AL

EN

TS

Cla

ssif

ica

tion

Magci

bar

Hall

ibu

rto

nD

ow

ell

B.J

.W

esla

nP

rod

uct

ion

Des

crip

tio

nA

ccel

erat

ors

CaC

l 2C

aCl 2

S-1

A-7

CaC

l 2C

alci

um

Chlo

ride

MC

A-L

CaC

l 2D

-77

A-7

L-

Liq

uid

Acc

eler

ator

MA

-2H

A-5

D-4

3A

-BW

A-4

Inorg

anic

Acc

eler

ators

Dia

cel

A

Dia

cel

A

D-5

7D

iace

lA

Dia

cel

A

Sodiu

m S

ilic

ate

Sal

tS

alt

D-4

4A

-5S

alt

Sodiu

mC

hlo

ride

Ret

arder

sM

LR

-1H

R-7

-K

emb

reak

WR

-1L

ow

Tem

per

atu

re R

etar

der

HL

R-3

HR

-4D

-13

R-5

WR

-2L

ow

Tem

per

ature

Ret

arder

MH

R-8

HR

-12

D-2

8R

-11

WR

-6H

igh T

emper

ature

Ret

arder

MH

R-9

HR

-15

D-9

3M

-6W

R-7

Hig

h T

emper

ature

Supple

men

t

MF

LR

-7D

iace

l L

WL

D-8

R-6

Dia

cel

LW

LD

iace

l L

WL

CM

HE

C

MH

R-6

00

HR

-20

D-9

9-

-E

xtr

eme

Hig

h T

emper

ature

ML

R-L

HR

-6L

D-8

1R

-14L

WR

-L1

Low

Tem

per

ature

Liq

uid

Ret

arder

MH

R-L

HR

-13L

-R

-14

L-

Hig

h T

emper

ature

Liq

uid

Ret

arder

Flu

id L

oss

Addit

ive

MF

L-4

Hal

ad 9

,14

D-6

0D

-19

CF

-1F

luid

Loss

Contr

ol

Addit

ive

MF

L-5

Hal

ad 9

,14

D-5

9D

-22

CF

-2F

luid

Loss

Contr

ol

Addit

ive

MF

LR

-7D

iace

l L

WL

D-8

R-6

Dia

cel

LW

LD

iace

l L

WL

CM

HE

C

MF

L-L

CF

R-2

, L

A-2

D

-73

--

Liq

uid

Flu

id L

ost

Ad

dit

ive

Turb

ule

nce

Induce

rsM

CD

-3C

FR

-2T

IC I

I D

-45

D-3

1T

F-4

Cem

ent

Dis

per

sant

MC

D-4

CF

R-1

TIC

I D

-65

-T

F-5

Cem

ent

Dis

per

sant

MC

D-L

CF

R-2

D-8

0D

-31-L

-L

iquid

Cem

ent

Dis

per

sant

H-T

LW

Ble

nd

s M

ult

iden

se1

:1 H

-TL

W1

:1 H

-TL

W1

:1 H

-TL

WT

alc

Var

iou

s H

-TL

W B

len

ds

Ex

ten

der

sM

-Gel

Ho

wco

Gel

Ben

ton

ite

BJ

Gel

Ben

ton

ite

Cem

enti

ng

Gra

de

Ben

ton

ite

Gil

son

ite

Gil

son

ite

D-2

4,

D-9

2D

-7G

ilso

nit

eE

xte

nder

and

Lost

Cir

cula

tio

n

Th

rift

yM

ixE

conoli

teD

-79

A-2

Thri

fty

-Lit

eC

hem

ical

Exte

nder

Th

rift

y M

ix-L

Eco

no

lite

-LD

-75

A-3

L-

Liq

uid

Ch

emic

al E

xte

nd

er

Mag

co P

oz

A

Po

zmix

A

Lit

epoz

3

Dia

mix

F

Fo

zmen

t A

A

rtif

icia

l P

ozz

ola

ns

Mag

co P

ox 1

80

Pozm

ix 1

40

Lit

epoz

180

T

her

moss

et-

Pozz

ola

n –

Lim

e M

ixtu

res

Eco

noble

nd

How

coli

ght

Lit

epoz

300

-T

hri

fty

men

tC

lass

II-

Poz

Ble

nds

Anti

-Foam

Agen

ts

MF

P-5

NF

-PD

-46

D-6

AF

-8P

ow

der

ed A

nti

foam

Agen

ts

MF

P-L

D-A

ir 2

D

-47

D-2

1A

F-L

Liq

uid

Anti

foam

Agen

ts

Th

ixo

tro

pic

Cem

ent

Th

ixo

cem

Th

ixo

mix

Reg

.F

ill-

up

Th

ixo

tro

pic

Th

ixo

men

tT

hix

otr

op

ic C

emen

t S

lurr

ies

Sil

ica

San

d

MS

-1S

ilic

a F

lour

D-6

6D

-8S

F-3

Min

us

200 M

esh S

ilic

a F

lour

MS

-2S

ilic

a F

lour

Coar

seD

-30

D-S

CS

F-4

Okla

hom

a #1 S

and

Wei

ghti

ng M

ater

ial

Nag

cobar

Bar

ite

D-3

1W

-1B

arit

eB

arit

e

MW

-2H

i-D

ense

3D

-76

W-5

WM

-2H

emat

ite

MW

-1H

i-D

ense

2D

-18

W-3

Ilm

enit

eIl

men

ite

Spac

ers

& W

ashes

MH

W-1

Mud-F

lush

CW

-7,

CW

-100

Mud-C

lean

WM

W-1

Mud T

hin

ner

-Spac

er

MC

S-2

SA

M-4

,5S

pac

er 1

000

Mud-S

wee

pA

PS

-1W

ater

Bas

ed M

ud S

pac

er

MC

S-3

SM

A-4

,5O

il B

ase

Spac

erO

il B

ase

Mud

Sw

eep

AP

S-1

Oil

Bas

ed M

ud

Spac

er

Lo

st C

ircu

lati

on

Gil

son

ite

Gil

son

ite

D-2

4D

-7G

ilso

nit

eG

ran

ula

r N

atu

ral

Hy

dro

carb

on

Cel

lo-S

eal

Flo

cele

D-2

9C

ello

-Fla

ke

Cel

l-O

-Sea

lC

ello

ph

ane

Fla

kes

Kw

ik-S

eal

-K

wik

-Sea

lK

wik

-Sea

lK

wik

-Sea

lG

rad

edP

arti

cle

Siz

es

Nut

Plu

g

Wal

nut

Shel

ls

D-4

2T

uf-

plu

gT

uf-

plu

gG

round

Wal

nut

Shel

ls

Mu

d D

eco

nta

min

ant

Har

d-S

et 1

M

ud

Kil

-1

K-2

1F

irm

Set

I

Sh

ur

Set

I

Mu

d K

ill

Pat

ente

d b

y G

ulf

Oil

Har

d-S

et I

I M

ud

Kil

-2

K-2

1F

irm

Set

II

Sh

ur

Set

II

Mu

d K

ill

Pat

ente

d b

y G

ulf

Oil

Lat

exM

CL

-2L

AP

-1D

-15

D-5

CL

X-1

Lat

exA

ddit

ive

81

APPENDIX C

RESULTS AND DATA SHEETS

82

Date

:

PN

G 4

51 -

OIL

WE

LL D

RIL

LIN

G L

AB

OR

AT

OR

Y

DA

TA

SH

EE

T 1

Experim

ent

#1:

Pro

pert

ies o

f fr

esh w

ate

r m

uds

Gro

up

No.:

Gro

up

1)

3)

Mem

be

rs:

2)

4)

C.F

.R

ea

din

g(s

ec)

10

rp

m50

rp

m1

00

rp

m2

00

rp

m3

00

rp

m6

00

rp

m1

0se

c1

0 m

in

1 2 1 2 1 23

Gro

up

No.

Mu

d

No.

Mars

hall

Fu

nn

el

Rh

eo

me

ter

(lb

/sq.

ft.)

Ge

l str

en

gth

(lb

/sq.

ft.)

1

Mud b

ala

nce (

ppg)

2

83

Da

te:

PN

G 4

51 -

OIL

WE

LL D

RIL

LIN

G L

AB

OR

AT

OR

Y

DA

TA

SH

EE

T2

Experi

ment #1: P

ropert

ies o

f fr

esh w

ate

r m

uds

Gro

up N

o.:

Gro

up

1)

3)

Mem

bers

:

2)

4)

Spurt

V1

V2

V3

V4

V5

V6

V7

V7

.5V

10

V1

5V

20

V2

5V

30

(in

)M

ud

Filtr

ate

Ca

ke

1 2 1 2 1 2

Gro

up

No.

Mud

No.

Mud

resis

tivity

(ohm

-m)

3

Filte

r pre

ss loss (

ml)

Cake

thic

k.

pH

1 2

84

PN

G 4

51

- O

IL W

EL

L D

RIL

LIN

G L

AB

OR

AT

OR

Y

RE

SU

LT

SH

EE

T

Exp

erim

en

t #

1:

Pro

pe

rtie

s o

f fr

esh

wa

ter

mu

ds

Gro

up

No

.:

Gro

up

1)

3)

Me

mb

ers

:

2)

4)

10

rpm

50 r

pm

100 r

pm

200

rpm

300 r

pm

600

rpm

1 2 1 2 1 2

10 s

ec

10

min

Mud

Filtr

ate

Cake

1 2 1 2 1 2

1 2 32 3

Gro

up N

o.

Mud

No.

1

Mud

density

(ppg)

Pla

stic

vis

cosity

(cp)

Gro

up N

o.

Mud

No.

Appare

nt

Vis

cosity (

cp)

Gel str

ength

(lb/s

q.

ft.)

pH

30-m

in

fluid

loss

(ml)

Cake

thic

kness

(1/3

2's

in)

Yie

ld

poin

t

(lb/f

t2)

Mud r

esis

tivity

(ohm

-m)

85

Da

te:

PN

G 4

51 -

OIL

WE

LL D

RIL

LIN

G L

AB

OR

AT

OR

Y

DA

TA

SH

EE

T 1

Expe

rim

en

t #

2:

Eff

ects

of

so

diu

m s

alts o

n f

resh w

ate

r m

uds

Gro

up

No

.:

Gro

up

1)

3)

Me

mbe

rs:

2)

4)

C.F

.R

ea

din

g1

00

rpm

300

rpm

60

0 r

pm

10

sec

10

min

(in)

1 2 3 4 1 2 3 4 1 2 3 4

Ca

ke

thic

k.

2

Mu

d b

ala

nce

(p

pg

)G

roup

No

.

Mu

d

No.

3

Rheom

ete

r (lb/s

q. ft

.)

1

Gel str

en

gth

(lb/s

q.

ft.)

pH

86

Date

:

PN

G 4

51 -

OIL

WE

LL

DR

ILLIN

G L

AB

OR

AT

OR

Y

DA

TA

SH

EE

T 2

Experi

ment

#2:

Eff

ects

of

sodiu

m s

alts o

n f

resh w

ate

r m

uds

Gro

up N

o.:

Gro

up

1)

3)

Mem

bers

:

2)

4)

Sp

urt

V1

V2

V3

V4

V5

V6

V7

V7.5

V1

0V

15

V2

0V

25

V3

0M

ud

Filtr

ate

Ca

ke

1 2 3 4 1 2 3 4 1 2 3 4

Filte

r pre

ss loss (

ml)

Mud

re

sis

tivity

(ohm

-m)

2 3

Mud

No.

Gro

up

No.

1

87

PN

G 4

51

- O

IL W

EL

L D

RIL

LIN

G L

AB

OR

AT

OR

Y

RE

SU

LT

SH

EE

T

Exp

erim

en

t #

2:

Eff

ects

of

sod

ium

sa

lts o

n f

resh

wate

r m

ud

sG

rou

p N

o.:

Gro

up

1)

3)

Me

mb

ers

:

2)

4)

10 s

ec

10

min

Mud

Filtr

ate

1 2 3 4 1 2 3 4 1 2 3 4

pH

30-m

in

fluid

loss

(ml)

Cake

thic

kness

(1/3

2's

in)

Mud r

esis

tivity

(ohm

-m)

Gel str

ength

(lb/s

q.

ft.)

1 2 3

Yie

ld

poin

t

(lb/f

t2)

Gro

up N

o.

Mud

No.

Mud

density

(ppg)

Pla

stic

vis

cosity

(cp)

88

Da

te:

PN

G 4

51 -

OIL

WE

LL D

RIL

LIN

G L

AB

OR

AT

OR

Y

DA

TA

SH

EE

T 1

Experi

ment #3: V

iscosity r

educin

g a

gents

Gro

up

No

.:

Gro

up

1)

3)

Mem

bers

:

2)

4)

C.F

.R

ea

din

g3

00

rp

m6

00

rpm

10

se

c1

0 m

inS

purt

V1

V2

V3

V4

V5

V6

V7

V7

.5

1 2 1 2 1 2

pH

Filte

r pre

ss loss (

ml)

Gro

up

No.

Mud

No

.

1

Mud b

ala

nce (

ppg)

Rheom

ete

r (l

b/s

q.

ft.)

Gel str

ength

(lb

/sq.

ft.)

2 3

89

PN

G 4

51 -

OIL

WE

LL D

RIL

LIN

G L

AB

OR

AT

OR

Y

RE

SU

LT

SH

EE

T

Experi

ment #3: V

iscosity

reducin

g a

gents

Gro

up N

o.:

Gro

up

1)

3)

Mem

bers

:

2)

4)

10 s

ec

10 m

in

1 2 3 4 1 2 3 4 1 2 3 4

2 3

Gro

up N

o.

Mud

No.

Mud

density

(ppg)

Pla

stic

vis

cosity

(cp)

Yie

ld

poin

t

(lb/f

t2)

Gel str

ength

(lb/s

q.

ft.)

pH

30-m

in

fluid

loss

(ml)

Cake

thic

kness

(1/3

2's

in)

1

90

91

Date

:

PN

G 4

51

- O

IL W

EL

LD

RIL

LIN

G L

AB

OR

AT

OR

Y

DA

TA

SH

EE

T

Expe

rim

en

t #

5: R

egu

lar

ce

me

nts

, ce

men

t exte

nd

ers

and

ce

men

t w

eig

htin

g m

ate

rials

Gro

up

No

.:

Gro

up

1)

3)

Me

mb

ers

:

2)

4)

C.F

.R

ea

din

g300 r

pm

600 r

pm

10

se

c10

min

Spurt

V1

V2

V3

V4

V5

V6

V7

V7

.5V

10

1 2 3 1 2 3 1 2 3

d1(i

n)

d2(i

n)

lbs.

d1

(in

)d2

(in

)lb

s.

d1

(in)

d2

(in)

lbs.

1 2 3 1 2 3 1 2 3

2 3

Filte

r pre

ss lo

ss (

ml)

Sam

ple

No.1

Sa

mp

le N

o.2

Sam

ple

No.3

Ve

rsa

Teste

r

1

Gro

up

No

.

Cem

en

t

No.

3

Gro

up

No

.

Cem

en

t

No.

Ge

lstr

eng

th

(lb

/sq

. ft

.)

1

Mud b

ala

nce

(ppg

)

Rh

eom

ete

r

(lb

/sq

. ft

.)

2

PN

G 4

51 -

OIL

WE

LL D

RIL

LIN

G L

AB

OR

AT

OR

Y

RE

SU

LT

SH

EE

T

Experi

ment

#5: R

egula

r ce

ments

, ce

ment exte

nders

and c

em

ent w

eig

htinG

roup

No

.:

Gro

up

1)

3)

Mem

bers

:

2)

4)

10 s

ec

10 m

in

1 2 3 1 2 3 1 2 4

31 2

Gro

up N

o.

Cem

ent

No.

Mud

density

(ppg)

Pla

stic

vis

cosity

(cp)

Yie

ld

poin

t

(lb/f

t2)

Gel str

ength

(lb/s

q.

ft.)

Dehydra

tio

n T

ime

(min

)

30-m

in

fluid

loss

(ml)

Co

mpre

ssi

ve s

trength

(psi)

92

93

Date

:

PN

G 4

51

- O

IL W

EL

LD

RIL

LIN

G L

AB

OR

AT

OR

Y

DA

TA

SH

EE

T

Expe

rim

en

t #

6: C

em

ent

acce

lera

tors

and

reta

rde

rs

Gro

up

No

.:

Gro

up

1)

3)

Me

mb

ers

:

2)

4)

C.F

.R

ea

din

g300 r

pm

600 r

pm

10

se

c10

min

Spurt

V1

V2

V3

V4

V5

V6

V7

V7

.5V

10

1 2 3 1 2 3 1 2 3

d1(i

n)

d2(i

n)

lbs.

d1

(in

)d2

(in

)lb

s.

d1

(in)

d2

(in)

lbs.

1 2 3 1 2 3 1 2 3

1 2 3

Cem

en

t

No.

Ve

rsa

Teste

r

Sam

ple

No.1

Sam

ple

No.2

Sam

ple

No.3

1 2 3

Gro

up

No

.

Gro

up

No

.

Cem

en

t

No.

Mud b

ala

nce

(ppg

)

Rh

eom

ete

r

(lb

/sq

. ft

.)

Ge

lstr

eng

th

(lb

/sq

. ft

.)F

ilte

r pre

ss lo

ss (

ml)

PN

G 4

51 -

OIL

WE

LL D

RIL

LIN

G L

AB

OR

AT

OR

Y

RE

SU

LT

SH

EE

T

Experi

ment

#6: C

em

ent accele

rato

rs a

nd r

eta

rders

Gro

up N

o.:

Gro

up

1)

3)

Mem

bers

:

2)

4)

10 s

ec

10 m

in

1 2 3 1 2 3 1 2 4

2 3

De

hydra

tio

n T

ime

(min

)

30-m

in

fluid

loss

(ml)

Com

pre

ssi

ve s

trength

(psi)

1

Mud

den

sity

(ppg)

Pla

stic

vis

cosity

(cp)

Yie

ld

poin

t

(lb/f

t2)

Gel str

ength

(lb/s

q.

ft.)

Gro

up N

o.

Cem

ent

No.

94

95

Date

:

PN

G 4

51

- O

IL W

EL

LD

RIL

LIN

G L

AB

OR

AT

OR

Y

DA

TA

SH

EE

T

Expe

rim

en

t #

7:

Wate

r lo

ss

ad

ditiv

es a

nd

dis

pe

rsa

nts

Gro

up

No

.:

Gro

up

1)

3)

Me

mb

ers

:

2)

4)

C.F

.R

ea

din

g300 r

pm

600 r

pm

10

se

c10

min

Spurt

V1

V2

V3

V4

V5

V6

V7

V7

.5V

10

1 2 3 1 2 3 1 2 3

d1(i

n)

d2(i

n)

lbs.

d1

(in

)d2

(in

)lb

s.

d1

(in)

d2

(in)

lbs.

1 2 3 1 2 3 1 2 3

1 2 3

Gro

up

No

.

Cem

en

t

No.

Ve

rsa

Teste

r

Sam

ple

No.1

Sam

ple

No.2

Sam

ple

No.3

Filte

r pre

ss lo

ss (

ml)

1 2 3

Gro

up

No

.

Cem

en

t

No.

Mud b

ala

nce

(ppg

)

Rh

eom

ete

r

(lb

/sq

. ft

.)

Ge

lstr

eng

th

(lb

/sq

. ft

.)

PN

G 4

51 -

OIL

WE

LL D

RIL

LIN

G L

AB

OR

AT

OR

Y

RE

SU

LT

SH

EE

T

Experi

ment

#7: W

ate

r lo

ss a

dditiv

es a

nd d

ispers

ants

Gro

up N

o.:

Gro

up

1)

3)

Mem

bers

:

2)

4)

10 s

ec

10 m

in

1 2 3 1 2 3 1 2 4

1 2 3

Gel str

ength

(lb/s

q.

ft.)

De

hydra

tio

n T

ime

(min

)

30-m

in

fluid

loss

(ml)

Com

pre

ssi

ve s

trength

(psi)

Cem

ent

No.

Mud

density

(ppg)

Pla

stic

vis

cosity

(cp)

Yie

ld

poin

t

(lb/f

t2)

Gro

up N

o.

96

PNG 451 Lab Manual 2012

Documents

Transcript of PNG 451 Lab Manual 2012