Ava Engineering Field Manual [PDF]

Zitiervorschau

ava Drilling Fluids & Services

Engineering Field Manual

ava S.p.A. Via Salaria, 1313/C 00138 Rome, Italy Tel: +39 06 8856111 Email: [email protected] Internet: www.avaspa.it Version 1 November 2004

This manual is provided without warranty of any kind, either expressed or implied. The information contained in this manual is believed to be accurate, however AVA S.p.A, Newpark Drilling Fluids, LLC and any of its affiliates, will not be held liable for any damages, whether direct or indirect which result from the use of any information contained herein. Furthermore, nothing contained herein shall be construed as a recommendation to use any product in conflict with existing patents covering any materials or uses.

DRILLING FLUID TEST PROCEDURES SECTION I

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TABLE OF CONTENTS 1. WATER BASED FLUIDS 1.1 ALKALINITY................................................................................... 6 1.2 AMMONIUM SULFATE .................................................................. 11 1.3 M.B.T. ............................................................................................... 12 1.4 CHLORIDES..................................................................................... 14 1.5 LIQUID AND SOLIDS CONTENT (RETORT)................................. 15 1.6 FILTRATION TESTS........................................................................ 18 1.7 FUNNEL VISCOSITY ...................................................................... 22 1.8 HYDROGEN ION DETERMINATION (pH)..................................... 23 1.9 HYDROGEN SULFIDE CONCENTRATION ................................... 24 1.10 H2SCAVENGING ABILITY AND ZINC CARBONATE ................ 27 1.11 MUD DENSITY .............................................................................. 31 1.12 NITRATE ION CONCENTRATION ............................................... 32 1.13 POLYACRYLAMIDE CONCENTRATION.................................... 33 1.14 POTASSIUM ION ANALYSIS ....................................................... 34 1.15 RHEOLOGICAL MEASUREMENTS ............................................. 37 1.16 SAND CONTENT ........................................................................... 40 1.17 SULFATE ION CONCENTRATION............................................... 41 1.18 SULFITE ION CONCENTRATION ................................................ 43 1.19 TOTAL and CALCIUM HARDNESS .............................................. 44 1.20 LIME CONTENT ............................................................................ 46 1.21 TRU – WATE MUD BALANCE ..................................................... 47 2. OIL BASED FLUIDS 2.1 WHOLE MUD ALKALINITY........................................................... 50 2.2 WHOLE MUD CALCIUM ................................................................ 51 2.3 WHOLE MUD CHLORIDES ............................................................ 52 2.4 DENSITY.......................................................................................... 53 2.5 EMULSION STABILITY.................................................................. 55 2.6 HT/HP FILTRATION........................................................................ 56 2.7 RETORT ANALYSIS (O/W ratio) ..................................................... 58 2.8 LIME AND SALINITY ..................................................................... 60 2.9 OIL/WATER RATIO AND SOLIDS ................................................. 62 2.10 RHEOLOGY ................................................................................... 64 2.11 ACTIVITY MEASUREMENTS ...................................................... 65

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3. COMPLETION FLUIDS 3.1 DENSITY.......................................................................................... 68 3.2 TURBIDITY...................................................................................... 69 3.3 CRYSTALLIZATION TEMPERATURE........................................... 70 3.4 CHEMICAL ANALYSIS................................................................... 71 4. AVA FLUID SYSTEMS 4.1 AVAGLYCO, AVAGLYCO MP ....................................................... 76 4.2 AVAPOLYSIL, AVASILIX, AVASHALESTOP/ACT, AVAEASYDRILL............................................................................ 78 4.3 AVACLAYBLOCK, AVAFASTDRILL, AVASHALESTOP, AVAPOLYMER 5050 ...................................................................... 79 4.4 AVADES 100 .................................................................................... 80 4.5 AVAPOLYOIL (DEEPDRILL™)...................................................... 82 4.6 AVABIOLUBE ................................................................................. 83 4.7 DEOXY DEHA ................................................................................. 84

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-1WATER BASED FLUIDS

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1.1 ALKALINITY Acidity is one measure of alkalinity that is indicated by pH. However, the nature and amount of other ions such as carbonate or bicarbonate can also affect mud filtrates alkalinity. For fresh water mud systems these ions can be indicative of the rheological stability of such mud systems. Concentrations of either ion can result in high, low shear rate viscosity (yield point) and high, progressive gel strengths. Three methods can be employed for the determination of carbonate and bicarbonate concentration. The very common Pf/Mf method is restricted to mud systems having a low organic content whereas the P1/P2 method or the Garrett Gas Train may be used for better, more quantitative analysis, especially in the systems with high organic content.

A. Pf/Mf Method: Equipment: 1. Phenolphthalein indicator 2. Bromocresol green indicator (or methyl orange or methyl red indicators) 3. Distilled water 4. Sulfuric acid N/50 (0.02N) 5. Beaker, 100 ml 6. Stirrer + Stirring rod 7. Graduated pipette (1 ml) Test Procedures: 1. 2.

3.

4.

Using a 1 ml pipette, measure 1 ml of filtrate into a titration vessel. Add 2 to 3 drops of phenolphthalein indicator. - If no colour change occurs, then Pf = 0.0 ⇒ continue to step 4 - If a pink or red colour develops, Pf > 0.0 ⇒ continue to step 3 Using a pipette, add N/50 sulfuric acid continuously while stirring or stirring until the sample changes from pink to colourless, (or original filtrate tint). The number of ml of N/50 sulfuric acid required to reach this point is recorded as the Pf value. To the sample, which has been titrated to the Pf end point, add 2-3 drops of bromocresol indicator to obtain a light blue colour. Continue titrating with stirring until the colour changes from light blue to apple green, (pH = 4.0-4.5). This end point, which includes the number of ml required to obtain the Pf end point is recorded as the Mf end point.

NOTE:

If methyl orange (or methyl red) indicator is used for Mf determination, then color change at end point is yellow to orange/red. Endpoint of titration is not a net change of color and cannot be determined in a correct manner if filtrate is coloured.

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Calculations: Use the following table to estimate the carbonate (CO3-2), bicarbonate (HCO3-), or hydroxyl (OH-), present in the mud filtrate. Pf/Mf Relation Pf = 0 Pf = Mf 2Pf = Mf 2Pf > Mf 2Pf < Mf

Bicarbonate (mg/L HCO3-) 1220⋅Mf 0 0 0 1220⋅(Mf – 2Pf)

Carbonate (mg/L CO3-2) 0 0 1200⋅Pf 1200⋅(Mf – Pf) 1200⋅Pf

Hydroxyl (mg/L OH-) 0 340⋅Mf 0 340⋅(2Pf – Mf) 0

B. P1/P2 Method: Inorganic ions such as borate, silicate, sulfide, and phosphate ions can have a real effect on drilling mud alkalinity. Additionally, organic compounds (e.g., anionic organic thinners, fluid loss additives, or other polymers) and their degradation by-products may also affect the determination of the relative amounts of carbonate, bicarbonate, or hydroxyl ions in solution. The P1/P2 method eliminates these effects. Equipment: 1. Sodium hydroxide 0.2N 2. Barium chloride 10% 3. Phenolphthalein indicator 4. Sulfuric acid N/50 (0.02N) 5. Beaker, 100 ml 6. Stirrer + Stirring rod 7. Distilled water 8. Graduated pipette (1 ml) Test Procedure: 1. 2. 3.

4. 5. 6.

Determine the Pf end point as outlined in step 1-3 of the Pf/Mf method. If the Pf = 0.0 there are no carbonates present. Place 1 ml of filtrate in a titration vessel and add 24 ml of distilled water. Add a measured 2 ml of 0.1N sodium hydroxide solution to convert all bicarbonates to carbonates. Check the pH, if it is less than 11.5, continue to add 0.1N sodium hydroxide in 1-2 ml increments until the pH exceeds 11.5. Make a record of the total amount of sodium hydroxide added in this step. Add a measured amount of barium chloride to precipitate all the possible carbonates. Add 2-4 drops of phenolphthalein solution with stirring. Using a 1 ml pipette, titrate immediately to the end point with N/50 sulfuric acid. Record the number of ml of N/50 sulfuric acid added as the P1 end point. Place exactly the same amounts of 0.1N sodium hydroxide, barium chloride, and indicator into 25 ml of distilled water; titrate to the end point using N/50 sulfuric acid and record this as the P2 end point.

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Calculations: Pf = 0.0: no carbonates present. P1 > P2: mg/L HCO3 = 0.0 mg/L CO3 = 1200⋅[Pf – (P1 – P2)] mg/L OH = 340⋅(P1 – P2) P2 > P1: mg/L OH = 0.0 mg/L CO3 = 1200⋅Pf mg/L HCO3 = 1220⋅(P2 – P1) WARNING:

The reagents may be hazardous to the health and safety of the user if inappropriately handled.

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C. Garrett Gas Train Method: Either of the methods above is still subject to some error and certain situations may require yet another method. The Garrett Gas Train separates gas from liquid, thereby preventing contamination of the CO2 detecting Dräger tube by the liquid phase. The CO2 Dräger tube responds to the CO2 passing through it by progressively staining (purple) along its length as the hydrazine chemical and the CO2 react causing a methyl violet indicator to turn purple. The stain length is dependent on the amount of CO2 present and the total gas volume that passed through the tube. Consequently, for accurate results, the gas exiting the train must first be captured in a one litre gas bag to allow the CO2 to mix uniformly with the carrier gas. Then the contents of the bag are drawn through the tube using 10 strokes of the Dräger hand pump. This will draw exactly 1 litre of gas through the tube. Test Procedures: 1. 2. 3. 4. 5. 6. 7.

Be sure the gas train is clean, dry and on a level surface. With the regulator T-handle backed off, install and puncture a N2O gas cartridge. Add 20 ml distilled water to chamber No. 1. (The chambers are numbered beginning at the regulator). Add 5 drops of octanol defoamer to chamber No. 1. Install the top on the gas train and evenly hand-tighten to seal all O-rings. Attach the flexible tubing from the regulator onto the dispersion tube of chamber No. 1. Inject with syringe, an accurately measured sample of filtrate into chamber No. 1. See table below.

Dräger Tube Identification Carbonate range Sample Volume Dräger Tube Identification (mg/L) (cm3) 25 – 750 1.0 CO2 100/a 50 – 1500 5.0 CO2 100/a 250 – 7500 2.5 CO2 100/a *Tube factor applies to new tubes, CO2 100/a with scale 100 to 3000. Old tubes use tube factor 25000. 8. 9.

10. 11.

12.

13.

14.

Tube Factor 2.5* 2.5* 2.5*

Flow carrier gas through the gas train for one minute to purge the system of air. Stop gas flow. Install one end of a piece of flexible tubing onto the stop cock, which is fitted directly into the gas bag. Have the gas bag fully collapsed. Fit the other end of the tubing onto the outlet tube of chamber No. 3. Slowly inject 10 ml sulfuric acid solution into chamber No. 1 through the septum using the syringe and needle. Gently shake gas train to mix acid with sample in chamber No. 1. Open the stop cock on the gas bag. Restart nitrogen flow gently and allow the gas bag to fill. When the bag is full, (DO NOT burst it) shut off and close the stop cock. Immediately proceed to the next step. Remove the tubing from chamber No.3 outlet tube and re-install it onto upstream end of the CO2 0.01%/a Dräger tube. (Observe that the arrow indicates gas flow direction) Attach Dräger hand pump to other end of Dräger tube. Open stop cock on bag. With a steady hand pressure fully depress the hand pump, then release so that the gas flows out of the bag and through the Dräger tube. Operate pump ten times. This should essentially empty the bag. Observe a purple stain on the Dräger tube if CO2 is present. Record the stain length in the units marked on the Dräger tube.

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Calculations: Carbonates (mg/L CO3-2) =

Carbonates (mg/L) F = tube factor

F ⋅L VS L = tube stain length

VS = ml of sample

Care and Cleaning: To clean the gas train, remove the flexible tubing and gas train top. Wash out the chambers using a brush with warm water and mild detergent. Use a pipe cleaner to clean the passages between the chambers. Wash, rinse and then blow out the dispersion tube with air or nitrogen gas. Rinse the unit with distilled water and allow draining dry.

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1.2 AMMONIUM SULFATE Test is based on a colorimetric reaction. Equipment: 1. HACH AMMONIA NITROGEN TEST KIT (No. 1 – 8) 2. Graduated cylinder, 100 ml 3. Graduated pipette (1 ml) 4. Graduated cylinder (10 ml) Sample Preparation: Add 0.25 ml filtrate to the 100 ml graduated cylinder. Dilute with distilled water to the 100 ml mark. Cover with palm of hand and invert cylinder several times. From this 100 ml solution, pipet 1.0 ml to the 10 ml graduated cylinder. Dilute to the 10 ml mark with distilled water. Invert the cylinder several times. Fill one tube to white line with this solution. Fill other tube to white line with distilled water. 1. 2. 3. 4.

Add 3 drops of Nessler solution to each tube. Stir. Allow 10 minutes for colour development. Insert the filtrate containing tube in the right opening in the top of the colour comparator. Insert the distilled water sample in the left opening in the top of the colour comparator. Hold the colour comparator up to a light such as the sky (preferable), a window or lamp and view through the two openings in the front. Rotate the colour disc until a colour match is obtained. Read the number in the scale window.

Calculation: (NH4)2SO4 (kg/m3) = 19⋅N Ammonium sulphate, (NH4)2SO4 N = number in scale window

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1.3 MBT TEST The methylene blue dye test, MBT, is used to determine the cation exchange capacity of the solids present in a drilling mud. Only the reactive portions of the clays present are involved in the test and materials such as barite, carbonates and evaporites do not affect the results of the test since these materials do not adsorb methylene blue. The cation exchange capacities of some typical clay are: Clay Wyoming Bentonite Soft Shale Kaolinite Drilled Cuttings

CEC (meq/100g) 75 45 10 8 – 12

For bentonite based mud systems the MBT provides an indication of the amount of reactive clays which are present in the drilling mud solids and for bentonite free, water based mud systems the MBT reflects the reactivity of the drilled solids. The test cannot distinguish between the type of clays but, if a reactivity for the drilled solids is known or assumed it can be used to determine the amount of bentonite present in bentonite based systems. Equipment: 1. Erlenmeyer flask 2. Hot plate 3. Stirrer + Stirring rod 4. Hydrogen peroxide 3% 5. Sulfuric acid 5N (20%) 6. Methylene blue solution = 3.20 g/L 7. 10 ml pipette 8. 3 ml syringe 9. Methylene blue test filter paper (Whatmann No. 1) 10. 50 ml graduate cylinder Test Procedure: 1. 2. 3. 4. 5.

Using the completely filled 3 ml syringe, measure 2.0 ml mud sample to be tested into the Erlenmeyer flask containing 10 – 15 ml fresh water. Add l5 ml hydrogen peroxide and 12 drops 5N sulfuric acid. Swirl or stir to mix. Boil gently for approximately 10 minutes and dilute with 20 ml fresh water. Add methylene blue in 1.0 ml increments. After each addition swirl the flask or stir vigorously for at least 20 seconds and remove a drop of sample on the end of the stirring rod. Apply the drop to a piece of filter paper marking the drop with the amount of methylene blue added between each increment. The approximate end point is reached when a blue ring spreads out from the blue spot on the filter paper. At this point, without further addition of methylene blue, swirl the flask an additional two minutes and place another drop on the filter paper. If the blue ring is again apparent, the end point has been reached. If the ring did not appear, continue with the methylene blue increments until a blue ring permanently forms after two additional minutes of swirling.

NOTE:

For increased accuracy, 0.5 ml increments may be used as the end point is approached. The blue ring is more apparent on the reverse side of the filter paper from which the drop is placed.

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Calculations: Methylene blue capacity (meq/100g) = Bentonite equivalent (ppb) = 5 ⋅

VT VM

VT WM

Bentonite equivalent (kg/m3) = 14.25 ⋅

VT = ml of methylene blue solution VM = ml of mud sample volume

VT VM

WM = weight of mud sample (g)

Care of reagents: The methylene blue dye and hydrogen peroxide should be stored in a cool, dark place to extend their life. These solutions should be replaced every four months. Figure 1: MBT test after several methylene blue additions.

C

A: 2 cm3 B: 4 cm3 C: 6 cm3 D: 7 cm3 E: 7 cm3: after 2 minutes F: 8 cm3 G: 8 cm3: after 2 minutes (end point)

D E

B

F

A Dyed mud solids

G

Moisture Moisture

Free, unadsorbed dye

Dyed mud solids

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1.4 CHLORIDES Chloride ions exist in a mud system as salts of sodium, magnesium, calcium or potassium. The determination of the chloride ion present in the mud filtrate may give an indication of salt water flows or the presence of a salt formation or stringer. In mud systems to which salt has been added, chloride ion measurements show the amount of salinity present in the mud. Equipment: 1. Silver nitrate solution: - 0.1N (or 0.0282N) for low chloride concentrations - 1N (or 0.282N) for high chloride concentrations 2. Potassium chromate indicator (5% solution) 3. Sulfuric acid (N/50) 4. Phenolphthalein indicator 5. Graduated pipettes (1 ml) 6. Titration beaker (100 ml) 7. Stirrer + Stirring rod Test Procedure: 1. 2.

3. 4.

Measure 1.0 ml of filtrate into a white titration beaker and dilute to convenient volume with distilled water. Add a few drops of phenolphthalein. If a pink colour develops add N/50 sulfuric acid until the pink colour completely disappears (it is not necessary to record the volume of N/50 sulfuric acid added) Add 4 drops of potassium chromate to obtain a yellow colour. Add silver nitrate while stirring until the colour changes from yellow to orange-red (brick red) or first color change that persists for 30 seconds.

Calculations: g/L Cl- = VT⋅3.545

g/L NaCl = VT⋅5.845

(a)

g/L Cl- = VT⋅35.45

g/L NaCl = VT⋅58.45

(b)

g/L Cl- = VT

g/L NaCl = VT⋅1.65

(c)

g/L Cl- = VT⋅10

g/L NaCl = VT⋅16.5

(d)

VT = ml of Silver Nitrate:

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(a) = 0.1N (c) = 0.0282N

(b) = 1.0N (d) = 0.282N

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1.5 LIQUID AND SOLIDS CONTENT (RETORT) The retort apparatus is used to determine the amount and type of solids and liquids present in a drilling mud sample. Mud is placed in the steel container and then heated until the liquid portion is vaporized. The vapour is passed through a condenser in which it is cooled and then collected in a graduated cylinder. The volume of the water and oil is measured as a fraction of the total mud volume. For accurate results a true mud density should be used for calculations, an accurate air free sample must be used and a volume correction factor should be determined for oil content if it is present in the mud. The correction factor, Fo, can be determined from running the retort in the manner described below and determining the oil correction factor as the fraction of oil recovered by running the oil blank. (For some crude oils Fo may be as low as 0.6, i.e. only 6 ml of an accurately measured 10 ml sample were recovered). Equipment: 1. Retort kit or Ministill (20 or 50 ml capacity) 2. Graduated cylinder, % or 20 ml or 50 ml 3. Anti seize grease 4. Spatula 5. Steel wool Test Procedure: 1.

2.

3.

4. 5. 6.

Lift retort assembly out of insulator block. Using the spatula provided as a screw driver, unscrew the lower mud chamber from the upper chamber. Pack the upper chamber with fine steel wool. Fill the mud chamber carefully with mud, place the levelling lid firmly onto the mud chamber and allow excess mud to escape through the hole in the levelling lid making sure no air is trapped below the lid or in the mud. An accurate sample volume is essential to the accuracy of the test results. Remove the levelling lid with a turning and sliding action so that mud adhering to the lid is wiped back into the sample chamber. Wipe off any excess mud, lightly coat the threads with the high temperature lubricant provided and screw the sample chamber into the bottom of the upper chamber. Place the retort in the insulator block and put the insulator cover in place. Add a drop of wetting agent to the 10 ml, graduated cylinder and place it under the condenser drain tube. Plug in the retort. Continue heating until liquid ceases to drip from the drain tube or until the pilot light goes off.

A. Water, Oil and Solids Calculations: %O =

100 ⋅Vo VM

%O = Volume % oil %W = Volume % water %S = Volume % retort solids

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%W =

100 ⋅VW VM

%S = 100 – (%O + %W)

Vo = ml oil Vw = ml water VM = sample volume (ml)

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To calculate suspended solids, the following formula can be used: VSS = %S – %W⋅

Cl 1680000 − 1.21⋅ Cl

VSS = Volume percent of suspended solids

Cl = chlorides (mg/L)

B. Average density, HGS and LGS Calculations: Average density of solids is calculated: dA =

MW ⋅100 − (%W + %O) %S

dA = average solids density (g/cm3) %O = Volume % oil %S = Volume % retort solids

MW = mud weight (g/cm3) %W = Volume % water

Percentage of HGS and LGS can be calculated as follows:

HGS =

[(1000 ⋅ d A ) − 2500] 1700

LGS = 1.0 – HGS

HGS = Volume % of high gravity solids LGS = Volume % low gravity solids (assume that density is 2500 kg/m3) dA = average solids density (g/cm3) NOTE: 1. 2. 3.

The high gravity solids are taken to have a 4.2 SG and the low gravity solids are taken to have a 2.5 sg. The volume fraction of high and low gravity solids is determined on the basis of the total solids volume present in the mud. The volume fraction solids include both dissolved and un-dissolved solids. The dissolved solids (as NaCl) can be approximated from the following table:

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Volume Fraction Salt (as NaCl) in the Water Phase Chloride Content (mg/L) Volume Fraction (Salt) SG 5000 0.003 1.004 10000 0.006 1.010 20000 0.012 1.021 30000 0.018 1.032 40000 0.023 1.043 60000 0.034 1.065 80000 0.045 1.082 100000 0.057 1.098 120000 0.070 1.129 140000 0.082 1.149 160000 0.095 1.170 180000 0.108 1.194 Handling and Instrument Care: 1. 2. 3. 4. 5.

Use the spatula to scrape the dried mud from the mud chamber and lid to assure correct volume. Use the high temperature lubricant on the threads of the mud chamber and lid to make dismantling easier. Remove and replace any mud caked steel wool. Use the pipe cleaner to clean the drain tube and condenser. The retort should be cooled prior to dismantling. It is extremely hot during and after the test.

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1.6 FILTRATION TESTS The filtration and wall building characteristics of a drilling mud are important for providing a relative measure of the amount of mud filtrate invasion into a porous and permeable formation and the amount of filter cake that will be deposited on the wall of the well bore wherever filtration occurs. From a drilling view point these properties give an indication of the amount of water (or oil) wetting that can take place in filtrate sensitive formations and the potential for tight hole or differential sticking problems. For productive, hydrocarbon bearing formations these properties give an indication of the amount of filtrate invasion and permeability damage that can be expected. Filtration tests are conducted under two different conditions. 1.

The standard API filtration test is conducted at surface (or room) temperature and 700 kPa (100 psi) pressure for thirty minutes. For this test the fluid loss is the volume (ml) of filtrate collected in this time period and the filter cake thickness (mm or 1/32 inch) is the thickness of the cake that is deposited on the filter paper in this time period.

2.

The API high temperature, high pressure test (HTHP test) is conducted for thirty minutes of filtration at a temperature of 149 °C (300 °F) and a differential of 3450 kPa (500 psi). For this test the filtrate must be collected under a back pressure of 700 kPa (100 psi) in order to prevent vaporization of the filtrate.

For all filtration tests the filter paper characteristics are Whatmann 50 or equivalent and the filtration area is 4560 mm2. Many filtration tests are conducted with a "half-area" filter press. In this event the filter cake thickness will be the same but the fluid loss must be corrected to the full size paper by doubling the collected filtrate volume in the thirty minute time period. All HTHP instruments are half area presses.

A. API Filtration Test Instruments: A.

Rig Style, Standard Filter Press

This type of filter press has a test cell with a removable lid and base that is placed onto the cross beam of a frame with a screw handle at the top for holding these component parts together during the test. The instrument is assembled in the following order: 1. 2. 3. 4.

Base cap with filtrate tube, rubber gasket, screen, filter paper, rubber gasket fixed to the mud cell (cylinder) using the locking dowel. Drilling mud poured into the cell to within 10 mm from the top. Rubber gasket and lid put on the cell and placed onto the cross beam of the test cell frame. Turn down the screw handle firmly and connect the pressure source making sure the pressure relief valve is closed.

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B.

Half Area Filter Press

This type of instrument is typical of a "half area" cell for which the filtrate volume must be doubled when the fluid loss is reported. The instrument is self contained with a CO2 cartridge in a cylinder for its pressure source that is adjusted using the T-handle of the built-in regulator at the top of the instrument. The mud cell is a rubber boot that is placed inside a holding cup to separate the mud from the pressure source. The lip of the boot serves as the sealing surface onto which the half area filter paper is placed prior to securing the lid into place. The lid, in the form of a screw cap or other locking device, is either knurled on the inside to simulate a screen or it may contain an actual, fixed screen. The relief valve (sliding bar) on the side of the cell must be open to apply pressure to the outside of the boot and closed when the filtration test is complete in order to permit pressure to be relieved. C.

Model MB Filter Press

This instrument consists of a mud cell assembly, pressure regulator and gauge mounted on the top of the carrying case. The cell is attached to the regulator by means of a coupling adapter by simply inserting the male cell coupling into the female filter press coupling and turning clockwise ¼ turn. The cell is closed at the bottom by a lid fitted with a screen, by placing the lid firmly against the filter paper and turning to the right until hand tight. This forces the filter paper against the O-ring fitted in the O-ring groove at the base of the cell. Pressure is supplied by a CO2 cartridge and may be released by a bleed-off valve prior to uncoupling the cell. (The bleed-off valve is closed when the valve is screwed in). Equipment: 1. API filter press 2. Graduated cylinder, 10 ml, 25 ml or 50 ml 3. CO2 cartridges 4. Filter paper (Whatmann no. 50 or equivalent ∅ 90 mm) Standard API Test Procedure: 1.

2. 3. 4. 5. 6.

7.

Pour the mud sample into the cell, secure the lid and make sure all valves are in the correct positions to permit the application of pressure to the sample to be filtered. If necessary place a fresh CO2 cartridge in the holding cylinder and screw the cylinder on quickly and securely to puncture the cartridge. Place an appropriately sized, graduated cylinder under the filtration tube. Using the pressure gauge as an indicator apply a 100 psi pressure to the sample and begin timing the test. Collect the filtrate in the graduated cylinder for 30 minutes. At this time, remove the graduated cylinder, turn off and relieve the pressure on the test sample. Report the volume of collected fluid as the fluid loss in millilitres making sure the volume is doubled if a half area filter press was used. Disassemble the test cell, discard the mud, and use extreme care to save the filter paper with minimal disturbance to the filter cake. Remove excess mud from the filter cake by light washing or lightly sliding a finger across the filter cake. Measure the thickness of the filter cake and report in millimetres. If desirable, the filter cake texture may also be noted as being dry to slick and mushy to firm to provide an indication of its friction factor and compressibility. Wash all components thoroughly in fresh water and wipe dry with a clean cloth or paper towel.

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B. High Temperature, High Pressure Filtration Test Instruments A.

Baroid, OFI Instruments

These instruments are O-ringed valve stems that act as valves which are closed when the stem is tightened into the mud cell and opened by unscrewing the valve stem approximately one-half turn. The pressure regulator and backpressure cylinder is attached to the valve stems with locking pins. The cell of this type of instrument is loaded by unscrewing the setscrews in the cell body until the cap can be removed. With the valve stem in the body and closed (tightened) mud is added to the cell to within 10 – 15 mm from the top. Filter paper is placed on top of the O-ring, which has its own groove in the cell body. The cap is placed in the cell making sure that the setscrew seats in the cap match the screws in the cell. The pressure source is a CO2 cartridge located in the barrel of the regulator assembly. The backpressure attachment is required only for tests conducted at temperatures above 95 °C. The mud cell is placed into the heating well and seated on the alignment pin located in the well. The filtrate volume obtained from this instrument must be doubled in order to correct the volume to the full sized paper. B.

FANN, OFI Instruments

These instruments use threaded valve stems with valves to which the pressure regulator assembly and back pressure assembly are secured using a lock ring and slip coupling assembly. The cell is filled by closing the valve on the cell, inverting it and then adding the drilling mud to within 10 – 15 mm from the top. Filter paper is placed on the O-ring in its groove. The cap of the cell is secured using setscrews and lowered in to the heating well which has provision to pass the valve and valve stem assembly of the cell through its base. The backpressure assembly is used for tests with temperatures in excess of 95 °C. Pressure is supplied from CO2 cartridges in the barrel of the regulator assembly. The cartridge is punctured when the barrel is tightened onto the regulator assembly. This is a half area instrument whose filtrate volume must be doubled to correct it to the standard full size test. Equipment: 1. HPHT filter press 2. Graduated cylinder, 10 ml, 25 ml or 50 ml 3. CO2 cartridges 4. HPHT Filter paper (Whatmann no. 50 or equivalent ∅ 2 ½”) High Temperature, High Pressure Filtration Test Procedure: The following is the standard procedure adopted by API for testing at 149 °C and 500 psi: 1.

2. 3. 4. 5.

6.

Connect the heating jacket to the correct voltage, place a thermometer in the well of the jacket and preheat the jacket to 155 °C. Adjust the thermostat in order to maintain a constant temperature. Take warm mud from flow line or preheat to 50 – 55 °C while stirring. Load cell as recommended by the manufacturer. Care should be exercised not to fill cell closer than 15 mm from top to allow for expansion. Place the cell in the heating jacket with both top and bottom valves closed. Transfer the thermometer from the heating jacket to the well of the test cell. Place the pressure assembly on the top valve stem and lock into place. Place the bottom pressure receiver and lock into place. Apply 100 psi to both pressure units with valves closed. Open top valve and apply 100 psi while heating. When temperature reaches 149 °C, open bottom valve and increase pressure on the top assembly to 600 psi to start filtration. Collect filtrate for 30 minutes maintaining the 149 °C temperature ± 2 °C. If desired record surge volume after 2 seconds. If back pressure rises

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7. 8. 9.

10.

11. 12. 13.

above 100 psi during the test, cautiously bleed off pressure by collecting portion of the filtrate. Record the total volume. The filtrate volume should be corrected to a filter area of 4581 mm2. (If the filter area is 2258 mm2, double filtrate volume and report.) At the end of test, close both valves. Back T-handle screw off the regulator and bleed off pressure from both regulators. CAUTION: Filtration cell will still contain about 500 psi. Maintain cell in upright position and cool to room temperature. (After the cell is cool, continue to hold cell upright (cap down) and loosen the top valve to bleed off pressure slowly). After the cell has cooled and the pressure has been bled off, the cell may be inverted to loosen the cap screws with an Allen wrench, remove the cap with a gentle rocking motion, carefully retain the filter cake for analysis and thoroughly clean and dry all components. Do not use filtrate for chemical analysis. If filter cake compressibility is desired the test can be repeated using 200 psi on the toppressure and 100 psi for bottom pressure. Record both temperature and pressure with the results of the filtration test at all times. The temperature of 149 °C was selected so as to be within the range where high temperature mud treating procedures and chemicals are required.

Calculation: HPHT filtrate (ml) = 2⋅VF VF = filtrate volume collected (ml) using half-area filter

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1.7 FUNNEL VISCOSITY Funnel viscosity is an indication of the overall viscosity of a drilling mud. The concentration, type, size and size distribution of the solids present and the electrochemical nature of the drilling mud’s solid and liquid phase affect it. Consequently funnel viscosity should only be used to provide an indication of change or consistency of viscosity from time to time. Since gel strength can have a great effect on the magnitude of the funnel viscosity, the measurement should be taken as quickly as possibly. Funnel Calibration: With the funnel in an upright position, fill it with freshwater (at 20 °C) to the level of the screen with a finger placed over the orifice. With the aid of the measuring cup (viscosity cup) the time taken for one quart of water to pass through the funnel orifice tube should be 26 seconds. NOTE:

The marsh funnel orifice is a tube, 50.8 mm in length and 4.76 mm in internal diameter. The orifice may be cleaned by passing a 4.76 mm (3/l6 inch) drill through it by hand.

Test Procedure: 1.

2. 3.

With the funnel in an upright position, cover the orifice with a finger and rapidly pour a freshly collected mud sample through the screen and into the funnel until the mud just touches the base of the screen, (1500 ml). See note below. Immediately remove the finger from the orifice and measure the time required for the mud to fill the viscosity cup to the one 1 litre level. Report the result to the nearest second as the marsh funnel viscosity, at the temperature of measurement in °C.

NOTE:

It is also permissible to overfill the funnel to some level above the screen and begin timing when the mud level reaches the screen. This is sometimes done in conjunction with not placing the finger over the orifice. In this manner the effect of gel strength on funnel viscosity is minimized.

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1.8 HYDROGEN ION DETERMINATION (pH) The acidity or alkalinity of a drilling mud is indicated by the hydrogen ion concentration, which is commonly expressed in terms of pH. A perfectly neutral solution has a pH of 7.0 whereas alkaline (basic) solutions have a pH range between 7.0-14.0 and acidic solutions have a pH less than 7.0. The pH measurement is used as well to indicate the presence of contaminants such as cement or anhydrite. The two most common field methods for determining pH are described below:

A. Method 1: pH-paper: 1. 2.

3.

This method may be used on the mud filtrate or the mud directly. Place a 25 mm strip of indicator paper on the surface of the mud to be tested and allow it to remain until the liquid has wet the surface and the colour has stabilized, (approximately one minute). Compare the colour standards provided with the test paper (which was not in contact with the mud solids) to the colour standards provided with the test paper and estimate the pH of the mud accordingly.

B. Method 2: colour pH strip: 1. 2. 3.

This method applies only to mud filtrates. After obtaining a sample of mud filtrate, totally immerse the coloured portion of the colour pH strip into the filtrate and remove immediately. After a short period of colour stabilization, (10-15 seconds) compare the colour of the wetted strip with the colour standards provided in the colour pH plastic container. An estimate may be necessary if a colour does not exactly match a particular pH value.

C. Method 3: pH-meter: Equipment: 1. pH-meter 2. Buffer solutions (pH = 7.00 and 4.00 or 10.00) 3. Distilled water 4. KCl 3M solution (for probe storage) 1. 2.

3. 4.

This method applies both to mud and filtrates. Prior to run the measurement, calibrate the instrument: immerse the probe into the buffer solutions (4.00, 7.00 or 10.00): use first the buffer solution at pH 7.00 and then that at pH 4.00 or 10.00. After calibration, make the measurement on the sample (mud or filtrate) by immersing the probe until reading is stable. Clean the probe carefully and let it immersed in distilled water or KCl 3M solution.

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1.9 HYDROGEN SULFIDE CONCENTRATION In many areas hydrogen sulfide (H2S) is found by itself or in association with hydrocarbons, especially gas. Hydrogen sulfide gas is not only very lethal but also extremely corrosive. Therefore, when H2S is encountered in the mud it must be reduced to acceptable levels so that it does not pose a health hazard or create drill string failure. The concentration of hydrogen sulfide present may be determined using the Hach Model HS-7 Hydrogen sulfide kit or more quantitatively using the Garrett Gas Train.

A. Method 1: Hach Kit Equipment: 1. Hach Model HS-7 Hydrogen sulfide kit 2. Graduated flask 25 ml 3. Graduated pipette 5 ml or 10 ml Test Procedure: 1.

Fill the sample vial to the 25 ml mark with recently filter pressed filtrate from the mud to be tested. (If 25 ml are not available use a known amount of filtrate and dilute to 25 ml using distilled water; 5 or more ml of filtrate are recommended). NOTE:

2. 3. 4. 5.

For most accurate results, the test should be performed using a recently obtained mud sample. If the sample has been aerated or allowed to stand for some time, much if not all, of the hydrogen sulfide gas will be lost by aeration or oxidation.

Place a circle of hydrogen sulfide test paper (lead acetate paper) inside the cap of the sample vial. Add an alka-seltzer tablet to the sample and IMMEDIATELY snap the cap containing the test paper onto the vial. After allowing ample time for the tablet to dissolve, remove the cap and test paper. Compare the colour of the test paper with the colour chart accompanying the test kit and record the amount of H2S gas present.

Calculations:

H 2S =

25 ⋅ C Vf

H2S = H2S present (mg/L)

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C = H2S recorded (mg/L)

Vf = ml of filtrate used

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B. Method 2: Garrett Gas Train Equipment: 1. Garrett Gas with H2S Dräger tubes & floating ball flow meter 2. Hydrogen sulfide (Hach), paper disks as alternative to Dräger tubes (for more qualitative test) 3. Sulfuric acid (5N) 4. Dropper bottle with octanol defoamer or equivalent 5. Hypodermic syringe (10 ml with 21 gauge needle) 6. CO2 cartridges Test Procedure: 1.

Be sure the gas train is clean, dry and on a level surface. NOTE:

2. 3. 4. 5.

Moisture in the flow metre can cause the ball to float erratically.

With the regulator T- handle backed off, install and puncture a CO2 gas cartridge. Add 20 ml distilled water to chamber No. 1. (The chambers are numbered beginning at the regulator). Add 5 drops of octanol defoamer to chamber No. 1. Measure the sample into chamber No. 1. according to the following table: Dräger Tube Identification Sulfide Range (mg/L) Sample Volume cm3 Dräger Tube Tube Factor 1.2 – 24 10.0 H2S 100/a 0.12* 2.4 – 48 5.0 H2S 100/a 0.12* 4.8 – 96 2.5 H2S 100/a 0.12* 30 – 1050 10.0 H2S 0.2% o/a 1500** 60 – 2100 5.0 H2S 0.2% o/a 1500** 120 – 4200 2.5 H2S 0.2% o/a 1500** *Tube factor 0.12 applies to new tubes, H2S 100/a, with scale 100 to 2000. Old tubes use tube factor 12. **Tube factor 1500 applies to new tubes, H2S 0.2% o/a with scale 0.2 to 7.0. Old tube use tube factor 600 times ratio: “batch factor” /0.40.

6. 7.

8. 9. 10. 11. 12. 13.

Select the proper Dräger tube in accordance with the table above. Break the tips from each end of the tube and apply Lubriseal to each end. Install the tube with the arrow pointing downward into the bored receptacle. Likewise, install the flow metre with the word "TOP" upward. (Be sure O-rings seal around the body of each tube). Install the top on the gas train and evenly hand-tighten to seal all O-rings. Attach the flexible tubing from the regulator onto the dispersion tube of chamber No. 1 and from the outlet tube of chamber No. 3 to the Dräger tube. Adjust the dispersion tube of chamber No. 1 to within 5 mm from the bottom. Flow CO2 gas gently through train form 10 seconds to purge system of air. Stop gas flow. Slowly inject 10 ml sulfuric acid solution into chamber No. 1 through the septum using the syringe and needle. Immediately restart CO2 flow. Using the regulator, adjust the flow so that the ball remains between the two lines on the flow metre tube. NOTE

One CO2 cartridge should provide 15-20 minutes flow at this rate.

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14. Observe a colour change on the Dräger tube if H2S is present. In the units marked on the tube, note and record the maximum darkened length before the front starts to smear. Continue flow for 15 minutes although the front may attain a diffuse, feathery colouration. On the high range tube an orange colour may appear ahead of the black front if sulfites are present. The orange region should be ignored when recording the darkened length. Calculations:

F ⋅L V S-2 = mg/L sulfides L = tube stain length S −2 =

F = tube factor V = ml of sample volume

Care and Cleaning: To clean the gas train, remove the flexible tubing and gas train top. Take the Dräger tube and flow metre out of the receptacles and plug the holes with stoppers to keep them dry. Wash out the chambers using a brush with warm water and mild detergent. Use a pipe cleaner to clean the passages between the chambers. Wash, rinse and then blow out the dispersion tube with air or CO2 gas. Rinse the unit with distilled water and allow draining dry. NOTE

A lead acetate paper disc (Hach) fitted below the O-ring of chamber No. 3 can be substituted for the Dräger tube in the gas train. The lead acetate paper, although not preferred for quantitative work, will show the presence of sulfides.

WARNING:

The reagents in this kit may be hazardous to the health and safety of the user if inappropriately handled. Please read all warnings before performing the test and use appropriate safety equipment.

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1.10 HYDROGEN SULFIDE SCAVENGING ABILITY AND ZINC CARBONATE When zinc carbonate is used as a drilling mud additive to scavenge hydrogen sulfide, H2S, in a sour gas well it is possible to obtain an estimate of the scavenging ability of the drilling mud as well as the amount of zinc carbonate present. Quantitatively, the scavenging ability of the mud and therefore the amount of zinc carbonate present can be determined using the Garrett Gas Train. A more qualitative method to determine the amount of zinc carbonate present employs the Hach Hydrogen Sulfide test kit.

A. Estimation of Zinc Carbonate Concentration (Qualitative): Equipment & Reagents: 1. Hach Model HS-Y Hydrogen sulfide kit 2. Filter press 3. Hamilton Beach mixer or equivalent 4. Hypodermic syringe, 5 ml 5. Fresh sodium sulfide, (Na2S), stock solution – 100 g/L Na2S 6. 5N Sulfuric acid 7. Distilled water 8. Defoamer, octanol or equivalent Test Procedure: 1. 2. 3. 4. 5.

6.

7.

Using the hypodermic syringe, add 2.5 ml of sodium sulfide stock solution (Na2S) to 350 ml of drilling mud. Agitate the sample in the mixer at medium speed for 5 minutes. Using the filter press, obtain at least 3 ml filtrate for each test. Place a circle of hydrogen sulfide test paper (lead acetate paper) inside the cap of the sample vial. Measure 2 ml of filtrate into the sample vial using the syringe and dilute the sample with approximately 20 ml of distilled water. Acidify the solution with 2 drops of acid, quickly drop an Alka Seltzer tablet into the solution and close the sample vial with the cap. After allowing ample time for the tablet to dissolve, remove the cap and test paper. The presence of brown colouration on the lead acetate paper indicates that the zinc carbonate concentration is less than 1.1 kg/m3. If the acetate paper is white (negative) the zinc carbonate concentration is more than 1.1 kg/m3. In order to define the end point more accurately, repeat the entire test using an additional 2.5 ml of sodium sulfide stock solution each time until a brown colouration is apparent on the lead acetate paper.

Calculation: ZnCO3 (kg/m3) = 0.44⋅Vmax ZnCO3 = Approximate zinc carbonate (kg/m3) Vmax = maximum number of ml of sodium sulfide solution used.

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B. H2S Scavenging Ability and Zinc Carbonate Concentration: Equipment & Reagents: 1. Garret Gas Train with H2S Dräger tubes & floating ball flow metre & CO2 gas cartridges 2. Sulfuric acid (5N) 3. Dropper bottle with octanol defoamer or equivalent 4. Hypodermic syringe with 21 gauge needle (10ml) 5. Two, minimum 400 ml jars with lids 6. Osterizer blender, blade type, 10 speed 7. Filter press 8. Fresh sodium sulfide (Na2S) stock solution (100 g/l) Test Procedure: 1. 2. 3. 4.

Label two jars. "A" and "B". Measure 350 ml of drilling mud into jar "A". Measure 350 ml of distilled water into jar "B". Measure 20 ml of stock sodium sulfide (Na2S) solution into each jar, close both jars and shake vigorously by hand for thirty seconds. Transfer the contents of jar A to the Osterizer mixing jar, replace the lid, and stir at the slowest speed for 15 minutes. Transfer the drilling mud - H2S system back to jar A.

NOTE:

5. 6.

Some drilling mud will thicken severely when the Na2S solution is added. If thickening occurs add a dispersant from rig stock at about 3 kg/m3 (roughly a cone shaped pile on a dime). If thickening is observed during the first of a series of tests the mud should be pre-treated with dispersant prior to Na2S addition.

Extract 10 ml of dilute sodium sulfide (Na2S) stock solution from jar "B" and label this filtrate "B". Prepare the Garrett Gas Train for testing as outlined below: a.

Be sure the gas train is clean, dry and on a level surface. NOTE:

b. c. d. e. f. g.

h.

Moisture in the flow metre can cause the ball to float erratically.

With the regulator T-handle backed off, install and puncture a CO2 gas cartridge. Add 20 ml distilled water to chamber No.1 (The chambers are numbered beginning at the regulator.) Add 5 drops of octanol defoamer to chamber No. l. Install the top on the gas train and evenly hand-tighten to seal all O-rings. Select a high range Dräger tube, (H2S 0.2%/A, tube factor is 1500), for installation. Break off the ends of the tube, apply Lubriseal to both ends and install the tube with the arrow pointing downward into the bored receptacle. Likewise, install the flow metre with the word "TOP" upward. (Be sure O-rings seal around the body of each tube.) Attach the flexible tubing from the regulator onto the dispersion tube of chamber No. l and from the outlet tube of chamber No. 3 to the Dräger tube. NOTE:

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Use only latex rubber or inert plastic tubing. Do not clamp tubing unclamped tubing provides a pressure relief in the event the gas train is over pressured.

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i. j. 7.

Adjust the dispersion tube of chamber No.1 to within 5 mm from the bottom. Flow CO2 gas gently through train for 10 seconds to purge system of air. Stop gas flow.

Proceed to the Garrett Gas Train operating procedure outlined below: a. Using the hypodermic syringe, inject 4.0 ml of filtrate ("B") into chamber No.1. b. Slowly inject 10 ml 5N sulfuric acid solution into chamber No. l through the septum using the syringe and needle. c. Immediately restart CO2 flow. Using the regulator, adjust the flow so that the ball remains between the two lines on the flow metre tube. NOTE: d.

One CO2 cartridge should provide 15-20 minutes of flow at this rate.

Observe a colour change on the Dräger tube. In the units marked on the tube, note and record the maximum darkened length before the front starts to smear. Continue flow for 15 minutes although the front may attain a diffuse, feathery colouration. On the high range tube an orange colour may appear ahead of the black front if sulfites are present. The orange region should be ignored when recording the darkened length.

8. Label the darkened, stained length as "B". 9. Filter the mud (“A”) to obtain at least 4 ml of filtrate, label filtrate “A”. 10. Clean the gas train as outlined below: To clean the gas train, remove the flexible tubing and gas train top. Take the Dräger tube and flow metre out of the receptacles and plug the holes with stoppers to keep them dry. Wash out the chambers using a brush with warm water and mild detergent. Use a pipe cleaner to clean the passages between the chambers. Wash, rinse and then blow out the dispersion tube with air or CO2 gas. Rinse the unit with distilled water and allow draining dry. 11. Run the gas train using 4.0 cm3 of filtrate “A” (from the mud) repeating paragraphs 6 and 7. Label the darkened length “A”. 12. Be sure to clean gas train after each test. Calculations: H2S scavenging ability (mg/L) = 375⋅(B – A) Zinc Carbonate (kg/m3) = 0.0037⋅H2S scavenging ability (mg/L)

WARNING:

The reagents in the kit may be hazardous to the health and safety of the user if inappropriately handled. Please read all warnings before performing the test and use appropriate safety equipment.

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NOTE:

The 100 g/L Na2S solution can deteriorate with time. If the 4.0 cm3 of filtrate “B” results in Dräger tube dark lengths, which are too short, the filtrate volumes can be increased. If filtrate sample volume is indeed increased the equation used to calculate H 2S scavenging ability is changed from: H2S scavenging ability (mg/L) = 375⋅(B – A) to: mg/L H 2S scavenging ability =

1500 ⋅ ( B − A) V

V = new volume (ml)

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1.11 MUD DENSITY Drilling mud density is required to calculate the hydrostatic pressure that is being exerted by a column of drilling mud at any given depth. Density is also used to provide an indication of the solids content of a drilling mud. When the test is performed using a standard mud balance, care must be taken to ensure that the cup is full and free of entrapped air. Mud Balance Calibration: 1. 2. 3. 4.

Remove the lid and completely fill the cup with distilled water at room temperature. Replace the lid carefully and wipe the entire balance dry. Place the balance arm on the base with the knife edge resting on the fulcrum. With the rider placed at 1000 kg/m3 (s.g. = 1.0 or 8.33 lb/gal), the bubble of the level vial should oscillate the same distance to the left and right of the centering mark above the vial. If not, the calibration screw at the end of the balance should be adjusted until the oscillations are equal. (Some balances do not have an adjustment screw and require lead shot to be removed or added through a calibration cap.) NOTE:

A more accurate reading is obtained if the mud balance is permitted to oscillate on its knife edge rather than allowing it to come to rest with the bubble centered over the centering mark.

Test Procedure: 1.

2. 3. 4. 5. 6. 7.

Remove the lid from the cup and completely fill the cup with the mud to be tested, it may be necessary to tap or vibrate the cup lightly to bring entrapped air to the surface for high viscosity mud. Replace the lid and seat it firmly on the cup in a rotating manner and allowing the excess drilling mud to be expelled through the centrally located hole in the lid. Wash the mud from the outside of the cup and dry the balance. Place the balance arm on the base with the knife edge resting on the fulcrum. Adjust the rider until the bubble oscillates equally to the left and right of the centering mark above the level vial. Read the mud density (mud weight) as shown by the indicator on the rider. Report the result to the nearest scale division in kg/m3, (specific gravity times 1000).

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1.12 NITRATE ION CONCENTRATION In some instances, after a potential producing horizon is drilled, it is desirable to know how much drilling mud filtrate has permeated the zone. In order to differentiate drilling mud filtrate from formation water a "tracer" is often introduced into the drilling mud. The nitrate ion is often used as such a tracer. Equipment: 1. Hach Model NI-11 nitrate test kit, 0 – 50 mg/l 2. Distilled water Test Procedure: To obtain accurate test results please read carefully before proceeding: Samples containing above 50 mg/L nitrate nitrogen can be tested by diluting the sample before running the test. For example, a one to five dilution can be made by using 1.0 ml of the water to be tested and 4.0 ml of demineralised water. Use the calibrated dropper provided in this kit for the dilution. Demineralised water is not included in this kit. The results of a one to five dilution are multiplied by five to obtain the correct mg/L nitrate nitrogen. The results of other dilutions will follow the same procedure as above; for example, the results of a one to three dilution would be multiplied by three. A small portion of the Nitraver nitrate reagent will remain un-dissolved and fall to the bottom of the colour viewing tube. This will not affect test results but should be rinsed from the tube between tests. WARNING:

1. 2. 3. 4. 5. 6.

7.

The reagents in this kit may be hazardous to the health and safety of the user if inappropriately handled. Please read all warnings before performing the test and use appropriate safety equipment.

Rinse a colour viewing tube several times with the water to be tested; then fill to the 5ml mark. Use the clippers to open one Nitraver 5 nitrate reagent powder pillow. Add the contents of the pillow to the tube. Stopper the tube and shake vigorously for exactly one minute. An amber colour will develop if nitrate is present. Allow the prepared sampled to set undisturbed for one minute; then place the tube of prepared sample in the right opening of the comparator. Fill the other viewing tube to the 5ml mark with some of the original water sample and place it in the left opening of the comparator. Hold the comparator up to a light source such as a window, the sky or a lamp and view through the openings in front. Rotate the disc until a colour match is obtained. Read the mg/L nitrate nitrogen (N) through the scale window. Test results can be converted from mg/L nitrate nitrogen (N) to mg/L nitrate (NO3-) by multiplying the scale reading by 4.4.

Calculation: Nitrate (NO3-), mg/L = N⋅4.4⋅d N = mg/L nitrate nitrogen

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d = dilution ratio (if no dilution: d = 1)

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1.13 POLYACRYLAMIDE CONCENTRATION Very often, mud systems may utilize a partially hydrolyzed polyacrylamide, PHPA, to provide or enhance inhibition by encapsulation of the polymer around the hydratable clays that are encountered while drilling. In order for this method of inhibition to be effective, a residual PHPA concentration must be present in the drilling mud filtrate. Equipment: 1. Hand cranking centrifuge 2. 2 Graduated centrifuge tubes 3. Floc developer solution 4. Cresol red indicator 5. Hydrochloric acid (0.2N) 6. Sodium hydroxide (0.2N) Test Procedure: 1. 2. 3. 4. 5. 6. 7. 8. 9.

Measure 12 ml fresh water into a test tube and place in centrifuge tube for balance. Measure 10.0 ml filtrate in the graduated centrifuge tube. Add 6 drops of cresol red indicator and with the tube covered invert gently. A reddish purple colour will develop to indicate a pH greater than 7.0. Add 0.2N hydrochloric acid, drop by drop, inverting gently each time until the solution just turns an orange-yellow. Add 2ml floc developer solution. Invert the tube gently to mix for 15-20 seconds, and allow the solution to stand for 3-4 minutes. Invert the centrifuge tube a few times and place it in the centrifuge. Centrifuge for one minute at a cranking speed of 120 rpm (same as 10 revolutions every 5 seconds). Remove the centrifuge tubes and note the amount of centrifuged precipitate as millilitres of precipitate.

Calculations: Polyacrylamide (kg/m3) = 1.4⋅V V = ml precipitate

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1.14 POTASSIUM ION ANALYSIS When a drilling mud containing potassium ions (KCl or K2CO3) is used, the primary purpose is to prevent, or at least minimize hydration of water sensitive formations. Inhibition of hydration is provided by the potassium ion K+, which is attracted to negative charges appearing through the flat surface. Therefore, it is extremely important to know the potassium ion concentration at all times in these mud systems. In KCl mud, by monitoring the potassium to chloride ion ratio (K+/Cl-) while drilling the more hydratable formations should coincide with points having a low ratio.

A. Method One: Equipment: 1. Hand cranking centrifuge 2. 2 Graduated, 15 ml centrifuge tubes 3. 750 g/L sodium perchlorate precipitating solution Test Procedure: 1. 2. 3. 4. 5. 6.

In order to balance the centrifuge, measure 14 ml of fresh water in the other centrifuge tube and place it into the centrifuge. Add 4.0 ml sodium perchlorate to 10.0 ml of filtrate to be tested in the centrifuge tube. A white precipitate, which forms immediately, indicates the presence of potassium. Invert slowly for one minute and place in the centrifuge. Centrifuge for one minute at a cranking speed of 120 rpm (10 revolutions every 5 seconds). Remove the centrifuge tube and note the amount of centrifuged precipitate as the floc volume in ml. Do not discard the centrifuged filtrate at this point. Determine the potassium ion concentration from the table below:

NOTE:

For potassium ion concentrations above 55 g/L, save the centrifuge filtrate, clean the tubes, split the centrifuged filtrate evenly into each tube, add 4 ml sodium perchlorate to each tube and centrifuge again. Record the total floc volume as the sum of the original floc volume plus any additional floc volume obtained by double centrifuging.

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Potassium Ion Concentration Floc Volume (ml) Potassium Ion Concentration (mg/L) 0.00 0 0.25 5000 0.50 7500 0.80 10000 1.10 15000 1.30 19000 1.50 24500 1.70 31000 1.90 38000 2.10 45000 2.30 53000 2.50 59000 2.70 65000 2.90 70000 3.10 75500 3.30 81000 NOTE:

5250 mg/L K+ is approximately 10 kg/m 3 KCl (K+/KCl = 39/74.5 ≈ 0.5)

B. Method Two: Equipment: 1. Sodium Tetraphenyl Borate solution (STPB) 2. Quaternary ammonium Salt solution (QAS) 3. Potassium buffer solution (NaOH 20%) 4. Bromophenol blue indicator 5. Filter paper (Whatmann no.1) 6. Glass funnel for filtration 7. Volumetric flask (100 ml) 8. Graduated pipette (25 ml) 9. Beaker (100 ml) 10. Stirrer + stirring rod 11. Erlenmeyer flask 12. Graduated pipette (1 ml) 13. Bi-distilled water Test Procedure: 1. 2. 3. 4. 5.

Put the adequate volume of API filtrate into a volumetric flask (see table). Add 3 – 4 ml of buffer solution. Add 25.0 ml of STPB solution and dilute to mark (100 ml) with bi-distilled water. Shake and let at rest for 10 minutes. White floc will develop. After that time, filtrate the solution into a beaker. Transfer 25.0 of filtrate solution into an Erlenmeyer flask and add 10 – 15 drops of indicator. Titrate with QAS until color change from purple/violet to blue.

NOTE:

STPB and QAS solution are prepared according to API 13A specifications

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Calculations: K+ (mg/L) =

1000 ⋅ (25.0 − VT ) VF

VT = ml of QAS used VF = ml of API filtrate used (see table) Approx. K+ in mud (mg/L) 250 – 2000 2000 – 4000 4000 – 10000 10000 – 20000 > 20000

NOTE:

VF to use (ml) 10.0 5.0 2.0 1.0 0.5

Potassium buffer solution (NaOH) is corrosive and causes severe burns. Avoid contact with eyes and skin. Store in a plastic bottle.

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1.15 RHEOLOGICAL MEASUREMENTS In the field, the rheological characteristics of a drilling mud are determined with a concentric rotational viscometer having an industry standardized bob and sleeve. Shear stress, viscosity or gel strength is determined from the degree of rotation of the bob under the influence of the shear rate created in the mud by the action of the outer, rotating sleeve. Because most drilling muds are nonNewtonian in behaviour, (pseudo-plastic and thixotropic), stress, viscosity and gel strength measurements must be performed at prescribed shear rates (rotational speeds). The industry standard rotational speeds are 600 and 300 rpm for any steady state rheological parameter and 3 rpm for gel strength (an indication of thixotropy) measurements. The most common field viscometers are: A. OFI Rheometer Model 800: This is an 8-speed viscometer capable also of stirring mud. The stirring speed is obtained by moving the shift lever counter clockwise as far as possible, the 600 rpm speed is obtained by moving the shift lever counter clockwise from the stirring speed to the first detent position. Is possible to make rheology measurements at 600, 300, 200, 100, 60, 30, 6 and 3 rpm. Connect the instrument to the power supply and switch on the button at the back of the viscometer body. B. FANN Model 35SA: This is a 6-speed viscometer, which are changed by a shift knob (or wheel) on top of the instrument and by a lever at the bottom (high or low speed). Is possible to make rheology measurements at 600, 300, 200, 100, 6 and 3 rpm. It is not possible to stir the mud sample with this instrument C. FANN Model 34A: This model is a 3-speed electric version of the FANN Model HC 34A. The stirring speed is obtained by pressing the button on left side of the upper body. The 600 rpm speed is obtained with the top shift knob pushed down while the sleeve is rotating and the 300 rpm speed is obtained by moving the top shift knob all the way up while the sleeve is rotating. A neutral position is located by a detent half way between the 600 and 300 rpm position. Gel strengths are determined by rotating the knurled wheel (located below the shift knob) by hand with the shift knob in the neutral middle position.

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A. PROCEDURE FOR RHEOLOGICAL MEASUREMENTS: In conventional field practices the steady state rheological description of a drilling mud is given in terms of the parameters, which describe the fluid as an ideal Bingham Plastic. These parameters are the plastic viscosity and yield point (or yield stress). The time dependent nature of the drilling mud (thixotropy) is measured in terms of gel strength. The temperature at which rheological measurements are taken should be constant and always be recorded. I.

PLASTIC VISCOSITY AND YIELD POINT

Place a recently agitated sample in a suitable container and lower the instrument head until the sleeve is immersed in the drilling mud sample exactly at the scribed line of the sleeve. With the instrument set at 600 rpm rotate the sleeve until a steady dial reading is obtained, (for highly thixotropic muds this may take some time). Consistency of results can be achieved if the 600 rpm dial reading is taken at the point for which the change in dial reading is less than one degree (one dial division over a stirring time of one minute). When the dial reading has reached this steady value, record this as the 600 rpm dial reading, θ600. Lower the speed to 300 rpm and stir the sample at this speed until a steady reading is obtained using the same criterion for the steady state point. Record this value as the 300 rpm dial reading, θ300. Calculations: Apparent Viscosity, AV (cP) =

θ 600 2

Plastic viscosity, PV (cP) = θ600 – θ300 Yield Point, YP (lb/100ft 2) = θ300 – PV Yield Point, YP (g/100cm2) =

θ600 = 600 rpm reading II.

θ 300 − PV = AV – PV 2

θ300 = 300 rpm reading

GEL STRENGTH

Gel strength measurements can be made as a continuation of the steady state measurements. Measurements are taken at two rest periods, 10 seconds and 10 minutes. 1.

2. 3. 4.

Stir the mud sample at 600 rpm until a steady reading has been achieved. (If all time dependence has been taken out of the mud sample, this reading should be the same as the previous 600 rpm dial reading). Stop rotation of the sleeve. (For the FANN Model 34A, the shift knob must be simultaneously brought to the neutral position). Allow a rest time of 10 seconds, then slowly (at 3 rpm) and steadily rotate the gel strength wheel (counter clockwise for the FANN instruments, clockwise for all others). Record the maximum dial deflection as the initial gel strength dial reading.

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5. 6.

Repeat steps (l)-(2) and in step (3) allow a rest time of 10 minutes. Record the maximum dial deflection as the 10 minute gel strength dial reading.

Calculations: Gel strength (lb/100ft 2) = θ3 for 0”, 10” or 10’ Gel strength (g/100cm2) =

θ3 for 0”, 10” or 10’ 2

θ3 = 3 rpm reading NOTE:

If the initial and l0 minute gel strengths are equal, the mud has no thixotropy, i.e., the mud has no ability to build structure while it is at rest. This type of mud does not have any real gel strength or increased suspending power while it is at rest. For this type of mud the gel break is not very evident, rather it will be a gradual increase to a steady value. This is indicated by lower ten minute gel strength in comparison to higher initial gel strength.

III. INSTRUMENT CARE: After every usage the instrument should be thoroughly cleaned. 1. 2.

3.

Run the rotor immersed in water (or solvent for oil based muds) at high speed for a short period of time. Remove the sleeve: hold the spindle, twist and carefully pull straight down for the FANN instruments. hold the spindle and unscrew the sleeve for all other instruments. Wipe the bob and other parts thoroughly clean with a dry, clean cloth or paper towel.

CAUTION:

The bob is hollow and from time to time accumulated moisture inside the bob can be eliminated by removing the bob and drying it out. Immersion of the hollow bob in extremely hot mud can result in a serious explosion. Care should be taken not to immerse the sleeve deeper into the mud than the scribed line on the sleeve. This may result in damage to the bearings holding the bob shaft in place. Similarly, care must be taken not to splash water or solvent up into the sleeve housing when the bob and its shaft are cleaned.

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1.16 SAND CONTENT The API sand content is defined to be that portion of the drilling mud solids whose size is greater than 74 microns (µm). The test can be used to give a qualitative, relative indication of the solids removal equipment effectiveness, the relative amount of coarse barite present and the abrasiveness of the mud. Equipment: 1. Screen sand content 2. Funnel sand content 3. Tube sand content Test Procedure: 1. 2.

3.

Fill the glass measuring tube to the indicated mark with mud to be tested. Add water to the next mark. Close the mouth of the tube and shake vigorously. Pour the mixture onto the screen tapping it lightly to aid passing of the diluted mud through the screen. Add more clean water and repeat this wet screening procedure until the wash water in the tube is clear. Wash the sand retained on the screen to free it of any remaining mud. With the sieve in an upright position, fit the funnel over the sieve, invert slowly and fit the funnel tip into the mouth of the cleaned measuring tube. Back wash the sand from the sieve using a fine spray of clean water with the measuring tube positioned vertically upright, allow the sand to settle in the tube for a few minutes. Report the sand content as the volume fraction of sand, (the volume percent divided by 100). For example if the sand content is read as 0.4% the volume fraction of sand is reported as 0.004.

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1.17 SULFATE ION CONCENTRATION Sulfate ions are present in many natural, ground and surface waters. In bentonite based mud systems flocculation and resultant high viscosity can result from sulfate ion concentrations approaching or exceeding 2000 mg/l. A qualitative or more quantitative test can be performed to establish the sulfate concentration.

A. Qualitative Test: Equipment: 1. Dropper bottle of barium chloride (10% solution) 2. Dropper bottle of strong nitric acid 3. Test tube Test Procedure: 1. 2. 3.

Place 2-4 ml of filtrate in a test tube and add a few drops of barium chloride. Shake the tube gently and observe the presence of a milky, white precipitate. This indicates the presence of carbonates and/or sulfates. Add a few drops of nitric acid and shake again. If the precipitate dissolves and disappears completely, only carbonates were present. If the precipitate remains, its intensity can be used for a qualitative estimate of the sulfate concentration.

Results: "trace"

-

the precipitate is barely discernable less than 50 mg/L sulfate ions are present

"show"

-

the precipitate is a translucent white suspension up to 500 mg/L sulfate ions are present

"light"

-

the precipitate is a milky white suspension up to 1000 mg/L sulfate ions are present

"heavy" -

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the precipitate is a white suspension more than 1500 mg/L sulfate ions are present the precipitate could be diluted for a more accurate determination of the concentration

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B. Quantitative Test: One method of quantitatively determining the sulfate ion concentration is with the use of the Hach Model SF-1 Sulfate Kit. Equipment: 1. Hach Model SF-1 Sulfate Kit Test Procedure: 1. 2. 3. 4. 5.

6.

Fill the calibration tube to the top with filtrate to be tested. Pour this sample into the mixing tube. Add the contents of one SulfaVer IV powder pillow. Swirl to mix. A white, turbid precipitate will appear if sulfate is present. Allow to stand for 5 minutes. Hold the calibrated tube in such a manner so that it can be viewed through the top. Slowly pour the prepared sample into the tube. Continue pouring until the image of the black cross on the bottom of the tube just disappears from view. At this point the tube will appear as a uniform field of view. Read mg/L sulfate (SO4-2) from the scale on the side of the calibrated tube. NOTE:

The difference between mg/L and ppm is not significant until sulfate concentrations exceed 7000 mg/L.

WARNING:

The reagents may be hazardous to the health and safety of the user if inappropriately handled.

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1.18 SULFITE ION CONCENTRATION In many mud systems, especially those, which contain high levels of salt, it is necessary to use an oxygen scavenger to reduce the dissolved oxygen content in the drilling mud in order to reduce drill string corrosion to acceptable levels. One method of reducing oxygen corrosion is with the use of any oxygen seeking ion like the sulfite (SO 3-2) ion, which will react with the dissolved oxygen present in the drilling mud. In order to minimize oxygen corrosion it is necessary to maintain a residual sulfite concentration in the drilling mud at all times. Usually, residual concentrations in the order of 300 mg/L or greater are required to reduce corrosion to acceptable levels. Corrosion results should always be verified with the use of corrosion rings. One method of determining the residual sulfite concentration is with the use of the HACH Model SU-5 Sulfite Kit. The sulfite concentration may be determined using mud or mud filtrate. Equipment: 1. Hach Model SU-5 Sulfite Kit Test Procedure: 1. 2. 3. 4.

Measure a sample by filling the sample bottle to the indicated mark, 10 ml. Add the contents of one Sulfite 1 reagent powder pillow. Swirl to mix. Add the contents of one sulfamic acid powder pillow. Swirl to mix. Titrate with sulfite 3 reagent using the eye dropper, (low and high range Sulfite 3 reagent is available). Add the reagent drop wise with continual swirling of the sample until a permanent grey-blue colour develops. Note the number of drops required to reach the end point.

Calculations: Sulfite mg/L, (SO 3-2) = 0.64⋅N N = No. drops low range sulfite 3 Sulfite mg/L, (SO 3-2) = 6.4⋅N N = No. drops high range sulfite 3

WARNING:

The reagents contained in the kit are harmful. Avoid contact with eyes and skin. Do not ingest. Read warning on chemical container.

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1.19 TOTAL & CALCIUM HARDNESS Water containing large amounts of calcium or magnesium salts is commonly referred to as "hard water". Make-up waters that are hard make it difficult to obtain the maximum yield from bentonite so it becomes necessary to treat our excess calcium, (for this purpose the total hardness as calcium should be brought to less than 40 mg/l). The presence of calcium in the mud filtrate may also indicate the presence of contaminants such as anhydrite or cement. Equipment : 1. Titraver 400 or EDTA (ethylene diammino tetracetic acid) 0.01M 2. Ammonia buffer (hardness buffer) 3. Eriochrome black T (total hardness indicator) 4. Graduated pipettes (1 ml) 5. Distilled water 6. Stirrer + Stirring rod 7. Calver II indicator or murexide (to distinguish calcium from magnesium) 8. Sodium hydroxide (0.1N) solution (to distinguish calcium from magnesium) 9. Methyl red or Potassium chromate 5% indicator (facultative)

A. Total Hardness (as calcium): Test Procedure: 1. 2. 3.

Using a pipette, measure 1.0 ml of filtrate into a white titration dish and dilute to a convenient volume with distilled water. Add 1 or 2 ml of hardness buffer and few grains of Eriochrome Black T indicator. A red colour will develop if calcium is present. While swirling or stirring continuously, add titraver (or EDTA) with a pipette until the colour changes from red to blue. At this end point record the number of millilitres of titrating solution added.

NOTE:

To better appreciate color change at end point, add 2 drops of methyl red (or potassium chromate) indicator until solution becomes orange (red + yellow): after titration color will change to green (blue + yellow).

Calculations: Total hardness (as calcium) mg/L = 400⋅V V = ml of Titraver 400 (or EDTA 0.01M) added

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B. Calcium hardness: Test Procedure: 1. 2. 3. 4.

Using a pipette, measure 1.0 ml filtrate into a white titration dish and dilute with a small amount of distilled water. Add 2 drops of 0.1N NaOH (sodium hydroxide). Solution pH must be approx. 12 – 13. Add several grains of calver II (or murexide) and swirl or stir to mix. Using a pipette, titrate with titraver (or EDTA) to a colour change from red to blue.

Calculation: Calcium hardness (Ca+2, mg/L) = 400⋅V V = ml of Titraver 400 (or EDTA 0.01M) added NOTE:

To better appreciate color change at end point, add 2 drops of methyl red (or potassium chromate) indicator until solution becomes orange (red + yellow): after titration color will change to green (blue + yellow).

C. Magnesium hardness: Test Procedure: The magnesium hardness is calculated as difference: Mg+2 (mg/L) = [Total hardness (mg/L) – Calcium hardness (mg/L)]⋅

24.3 40.1

Or: Mg+2 (mg/L) = [VEDTA (Total hardness, ml) – VEDTA (Calcium hardness, ml)]⋅0.24

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1.20 LIME CONTENT Lime content in a drilling fluid can be determined with Pf/Mf alkalinity method. Test Procedure: 1. 2. 3.

Determine Pf and Mf as described. Determine the % volume of water from retort analysis (%W) Calculate the lime content.

Calculations: Lime content (ppb) = 0.26⋅(Pm – F⋅Pf) Lime content (kg/m3) = 0.742⋅(Pm – F⋅Pf) F = %W/100

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1.21 TRU – WATE MUD BALANCE When a drilling mud contains entrapped air or it is experiencing a foaming problem the mud density may be accurately determined with a pressurized mud balance. Test Procedure: 1. 2.

3. 4.

5.

6.

7.

8. 9.

Fill the sample cup with drilling mud to a level, which is approximately 10 mm below the upper edge of the cup. Place the lid on the cup with the attached check valve in the down (open) position. Push the lid downward into the mouth of the cup until surface contact is made between the outer skirt of the lid and the upper edge of the cup allowing any excess mud to be expelled through the open check valve. Pull the check valve up into the closed position, rinse off the cup and threads, and then, screw the threaded cap onto the cup. With the plunger in hand, push its handle in to place the inner piston to its lower most position. Fill the plunger by immersing its nose in the mud to be tested and pulling out the handle until the inner piston is in its upper most position. (The plunger's operation is similar to a syringe or bicycle pump). Place the nose of the plunger onto the mating O-ring surface of the valve on the cap. The sample cup is pressurized by maintaining a downward force on the cylinder in order to hold the check valve down (open) and at the same time forcing the piston inward. Approximately 220 Newton of force are required on the plunger handle in order to pressurize the sample cup. The check valve in the lid is pressure actuated and will close (move up) under the influence of pressure within the sample cup. Therefore the valve is closed by gradually easing up on the plunger cylinder while maintaining pressure on the piston. When the check valve closes, disconnect the plunger from the lid, rinse the cup in water and wipe it dry. Place the pressurized balance with the knife edge on the fulcrum of the balance stand. Adjust the sliding weight on the balance beam until the bubble oscillates equally to the left and right of the centering mark above the bubble vial. Note the value of the specific gravity at this point. The density is recorded in kg/m3 as determined by multiplying the specific gravity by 1000. The pressure in the mud balance is now released by reconnecting the empty plunger to the lid and pushing downward to the plunger cylinder while permitting the handle to move freely. To complete the procedure all components should be washed and rinsed thoroughly.

NOTE:

For trouble free operation the valve, lid and cylinder should be greased frequently with water proof grease such as "Lubri-Plate".

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NOTES:

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-2OIL BASED FLUIDS

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2.1 WHOLE MUD ALKALINITY Equipment: 1. n-propoxypropanol solvent (or isopropyl alcohol / hexyl alcohol = 50/50) 2. Phenolphthalein indicator 3. 250 ml Erlenmeyer flask 4. Magnetic stirrer 5. Sulfuric acid N/10 (0.1N) 6. Graduated Pipettes (1 ml) 7. Glass syringe (5 ml) Procedure: 1. 2. 3. 4. 5. 6.

To 50 ml of n- propoxypropanol, add 1.0 ml of oil mud, and stir well on magnetic stirrer. Add 100 ml of distilled water and 5 drops of phenolphthalein indicator. While rapidly stirring, slowly titrate entire mixture with N/10 (0.1N) H2SO4 until the pink color disappears. Wait for 5 minutes without stirring: if no pink colors appears, then record the ml of N/10 Sulfuric acid required as VSA. If solution turns pink, then titrate until the pink color disappears*. Record total ml of N/10 Sulfuric acid required as VSA

NOTE:

Adequate ventilation should be maintained using this procedure to avoid inhalation of the organic solvents.

Calculations: Mud alkalinity (Pom) = VSA VSA = ml of N/10 (0.1N) H2SO4 required *NOTE:

After pink color disappears, the determination of chloride using silver nitrate titration may be performed on the same test solution. Want an excess lime content of 10-20kg/m 3 under normal conditions. If hydrogen sulfide or CO2 are expected, the excess lime content must be raised to 30-40 kg/m3.

DO NOT THROW OUT SAMPLE. USE IT FOR CHLORIDE DETERMINATION.

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2.2 WHOLE MUD CALCIUM Equipment: 1. n- propoxypropanol solvent (or isopropyl alcohol / hexyl alcohol = 50/50) 2. Titraver 4000 (or EDTA 0.1M) 3. Calcium buffer (1N NaOH solution) 4. Graduated pipette (1 ml) 5. Calver II indicator or murexide 6. Magnetic stirrer + stirring rod 7. Glass syringe (5 ml) 8. 250 ml Erlenmeyer flask Procedure: 1. 2. 3. 4.

To 50 ml of n- proproxypropanol, add 1.0 ml of oil mud. Mix well on magnetic stirrer for 2 minutes to break the emulsion. While stirring, add 100 ml of distilled water, 2 ml of calcium buffer and 0.1-0.2 grams of Calver II indicator powder. Slowly stir only to agitate the aqueous (lower) phase. Titrate very slowly until the color changes from a light purple to a deep blue.

NOTE:

Adequate ventilation should be maintained using this procedure to avoid inhalation of the organic solvents.

Calculation: Caom (mg/L) = 4000⋅VT Caom = Calcium (whole mud)

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VT = ml of Titraver⋅4000 (or EDTA 0.1M)

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2.3 WHOLE MUD CHLORIDES Equipment: 1. Potassium chromate indicator (5% aqueous solution) 2. Silver nitrate solution: - 0.0282N (or 0.1N) for low chloride concentrations - 0.282N (or 1.0) for high chloride concentrations 3. Graduated pipettes (1 ml ) 4. Magnetic stirrer + stirring rod Procedure: This titration is performed after determining the POM alkalinity on the titrated sample. 1. Make sure that solution is acidic (add 5 – 10 drops of N/10 sulfuric acid). 2. Add 10 – 15 drops of Potassium Chromate indicator. 3. While rapidly stirring, slowly titrate the mixture with Silver nitrate until the first permanent red/orange color appears. NOTE:

Adequate ventilation should be maintained using this procedure to avoid inhalation of the organic solvents.

Calculations: (a) ClOM = VT⋅1000

(b) ClOM = VT⋅10000

(c) ClOM = VT⋅354.5

(d) ClOM = VT⋅3545

ClOM = whole mud chlorides (mg/L) VT = ml of: (a) 0.282N AgNO3 (b) 0.0282N AgNO3 (c) 0.1N AgNO3 (d) 0.01N AgNO3

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2.4 DENSITY Equipment: 1. Mud balance Procedure: 1.

The method for obtaining the density of an invert mud is identical to that used for a waterbased fluid. Insure that the invert mud's temperature is approximately room temperature (i.e. 20-25°C) before weighing.

Conversion factors: kg/m3 = Specific Gravity⋅1000 kg/m3 = pounds/gal (ppg)⋅119.826 kg/m3 = pounds/ft3 (pcf)⋅16.051 pcf ppg SG (g/cm3) = = 62.43 8.345 Alternate Density measurements with Tru-Wate balance: The density of mud containing entrained air or gas can be determined more accurately by using the pressurized fluid density balance (Tru-wate). The pressurized fluid density balance is similar in operation to the conventional mud balance, the difference being that the slurry sample can be placed in a fixed volume sample cup under pressure. The purpose of placing the sample under pressure is to minimize the effect of entrained air or gas upon slurry density measurements. By pressurizing the sample cup, any entrained air or gas will be decreased to a negligible volume, thus providing a slurry density measurement more closely in agreement with that which will be realized under downhole conditions. Procedure: 1. 2.

3.

4.

5.

Fill the sample cup to a level slightly below the upper edge of the cup (approximately ¼ inch). Place the lid on the cup with the attached check valve in the down (open) position. Push the lid downward into the mouth of the cup until surface contact is made between the outer skirt of the lid and the upper edge of the cup. Any excess slurry will be expelled through the check valve. When the lid has been placed on the cup, pull the check valve up in the closed position, rinse off the cup and threads with oil, and screw the threaded cap on the cup. Fill the plunger by submersing its end in the slurry with the piston rod in the completely inward position. The piston rod is then drawn upward thereby filling the cylinder with slurry. This volume should be expelled with the plunger action and refilled with fresh slurry sample to ensure that this plunger volume is not diluted with liquid remaining from the last clean up of the plunger mechanism. Push the nose of the plunger onto the mating O-ring surface of the cap valve. Pressurize the sample cup by maintaining a downward force on the cylinder housing in order to hold the check valve down (open) and at the same time forcing the piston rod inward. Approximately 50 pounds force or greater should be maintained on the piston rod. The check valve in the lid is pressure actuated; when pressure is placed within the cup, the check valve gradually ease up on the cylinder housing while maintaining pressure on the piston rod. When the check valve closes, release pressure on the piston rod before disconnecting the plunger.

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6.

7. 8.

The pressurized slurry sample is now ready for weighing. Rinse the exterior of the cup and wipe dry. Place instrument on the knife edge as illustrated. Move the sliding weight right or left until the beam is balanced. The beam is balanced when the attached bubble is centered between the two black marks. Read the density from one of the four calibrated scales on the arrow side of the sliding weight. The density can be read in units of lb/gal, specific gravity, psi/1000ft, and lb/ft3. To release the pressure inside the cup reconnect the empty plunger assembly and push downward on the cylinder housing. Clean the cup and rinse thoroughly with base oil.

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2.5 EMULSION STABILITY This is another indication of the emulsion’s integrity in an Invert emulsion. This test is run after determining the rheology. The sample remains in the thermo-cup at 50°C and the electrical stability probe is inserted. The voltage required to break the emulsion is taken while making sure the probe does not touch any part of the thermo-cup. This test should be taken 3 times with the results averaged. Equipment: 1.

OFI model 131-50 or FANN model 23D

Test Procedure: 1. 2. 3. 4. 5. 6.

Place the fluid in a non-conductive container and heat to 49°C (120°F). (Same temperature used in Rheology). Insert probe into fluid ensuring that end is totally immersed. Hand-stir the sample with the probe for 10 sec. Depress button on meter until steady reading is observed. Take three readings and average the results. Readings should be recorded in Volts. Clean probe immediately after use.

Discussion of results: There are many variables involved in the stability of an invert emulsion, thus the emulsion stability value should be considered with the data from a complete mud check. As a rule of thumb however, emulsion stability should be at least 250 volts or equal to the bottom hole temperature (whichever is greater).

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2.6 HT/HP FILTRATION All invert systems should be tested in the following manner for filtration loss since API – 30 minute (100 psi) does not give accurate fluid loss values for invert drilling fluids at anticipated wellbore temperatures and pressures. The HTHP fluid loss is normally operated at bottom hole temperatures with a 3500 kPa (500 psi) differential pressure. The fluid is collected over 30 minutes and multiplied by 2 before being reported (half area filter paper is used). At elevated temperatures (> 100°C) it will be necessary to have a regulator on the bottom to provide back pressure. The bottom would have 700 kPa (100 psi) and the top would have 4200 kPa (600 psi) in order to maintain a 500 psi differential. The absence of water in the filtrate collected indicates that the emulsion is tight. Equipment: 1. OFI Instruments HTHP Fluid loss apparatus 2. HPHT filter paper 3. Graduated cylinder (5 or 10 ml) Test Procedure: 1.

2. 3. 4.

5.

6. 7.

8.

Connect the heating jacket to power supply (be sure that voltage is adequate) before test is to be made. Place a thermometer in the thermometer well. Preheat the heating jacket to the desired temperature. Adjust the thermostat in order to maintain constant temperature. Load the cell taking care not to fill the cell closer than 25 mm (1 inch) from top to allow for expansion. Place the cell into the heating jacket with both top and bottom valve-stems closed. Transfer thermometer from well to cell. Place the pressure unit on the top valve and lock in place. Place the bottom pressure receiver and lock in place. Apply 100 psi to both pressure units with valve stems closed. Open top valve and apply 100 psi to the fluid while heating. When sample reaches desired temperature, increase the pressure of the top pressure unit to 4100 kPa (600 psi) and open the bottom valve to start filtration. Collect the filtrate for 30 min, maintaining temperature ± 3°C. If desired, record surge volume after 2 seconds. If back pressure rose above 100 psi during the test, cautiously reduce the pressure by drawing off a portion of the filtrate. Record the total volume. The filtrate volume should be corrected to a filter area of 45.8 cm2. (The filter area is 22.9 cm2, so double filtrate volume and report.) At the end of the test, close both valve stems. Back T-screw off and bleed pressure from both regulators. CAUTION: Filter cell will still contain approximately 500 psi. Maintain cell in upright position and cool to room temperature before releasing cell pressure. After the cell has cooled and the pressure has been bled off, the cell may be inverted to loosen the cap screws with an Allen wrench, remove the cap with a gentle rocking motion, carefully retain the filter cake for analysis and thoroughly clean and dry all components.

Calculations: HPHT filtrate (ml) = 2⋅V V = filtrate volume (after 30 min) (ml)

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NOTE:

Applied minimum back pressure depends on test temperature: Test temperature °F °C 212 100 250 121 300 149 350 177 400 204 450 232

Minimum back pressure psi kPa 100 690 100 690 100 690 160 1104 275 1898 450 3105

WARNING: Do not use nitrous oxide cartridges: under HPHT conditions it can detonate in the presence of oil and grease.

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2.7 RETORT ANALYSIS (O/W ratio) In order to prevent retort error, it is important to use a variable temperature retort when testing an oil mud. Heat sample to the temperature required to distil water by raising the temperature to 160°C (325°F). After allowing the water sufficient time to distil over, then the temperature can be raised to ensure all the oil is distilled. Again, gradually raise the temperature and hold where oil is distilling, as there will be retort error due to flashing-off of oil at extreme temperatures. It is important to realize that drilled solids can contain water within their mineral matrix. If a system has sufficient drilled solids, water can be distilled at extreme temperatures, again, giving retort error. This could be a problem in a pure oil system because the results would indicate free water. Equipment: 1. 20 / 50 ml variable retort 2. Retort cylinder (% graduation) 3. Steel wool, anti-seize grease Procedure: 1. 2. 3. 4. 5. 6. 7. 8. 9.

Fill the chamber with a freshly obtained mud sample, avoiding air bubbles entrapment into sample. Place the lid on the chamber allowing any excess mud to escape. Remove the lid from the chamber being careful not to remove any fluid adhering to the lid. Add 5-6 drops of liquid steel wool or pack steel wool around the upper portion of the immersion heater. The solid steel wool will give better oil/water separation. Apply lubricant/grease on threads. Screw the lower retort chamber into the upper chamber while maintaining both chambers in an upright position. Attach the assembled retort to the condenser. Add a drop of wetting agent (aerosol) to a graduated cylinder and place it under the drain of condenser. Gradually increase temperature by raising temperature from 325°F to 450°F, and finally 950°F. Heating is usually 30-60 minutes, depending on fluid type. Centrifuge sample if necessary to separate the oil and water layers. If emulsion at interface is present, heat the graduated cylinder carefully along the emulsion by touching it with the hot retort chamber: the emulsion will separate into 2 layers.

Calculations: OIL and WATER % Oil/water percentage is calculated as follows: %O =

100 ⋅ VO VR

%O = percent oil in liquid phase %S = percent retort solids VO = ml of oil (from retort)

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%W =

100 ⋅VW VR

%S = 100 – (%O + %W)

(a)

%W = percent water in liquid phase VR = retort cup volume (ml) VW = ml of water (from retort)

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Calculations: CORRECTED RETORT VALUES Corrected retort values for solids and brine are calculated by using the volume increase factor: F=

dW ρ B ⋅ (1 − 0.01 ⋅ S )

F = volume increase factor ρB = brine density (from salt tables, sg)

dW = water density (assume 1.000 sg) S = %w salt in brine (from salt tables, sg)

Then, %SC =

%S F

%BC = %W + (%S – %SC)

%SC = corrected solids % %BC = corrected brine %

%S = percent retort solids %W = percent water in liquid phase

Oil/brine ratio (O/B) is then calculated as follows: O=

%O ⋅100 %O + % BC

B=

% BC ⋅100 %O + % BC

%O = % oil (from retort)

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%BC = corrected brine %

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2.8 LIME AND SALINITY A. Excess Lime It is also called whole mud Lime content. Calculation: LimeOM (ppb) = 1.295⋅VSA

LimeOM (kg/m3) = 3.69⋅VSA

(a)

LimeOM = Ca(OH)2 VSA = ml of 0.1N sulfuric acid

B. Calcium Chloride and Sodium Chloride It is the salt content in the whole mud. Oil based mud may contain both CaCl2 and NaCl. Calculations: CaCl2OM (mg/L) = 2.774⋅CaOM CaCl2 (kg/m3) = 0.002774⋅CaOM

(b) CaCl2 (ppb) = 0.000971⋅CaOM

CaCl2OM = mg/L of CaCl2 in whole mud

VSA = ml of 0.1N sulfuric acid

The chlorides due to CaCl2 can be determined as follows, by calcium analysis: ClCaCl2 (mg/L) = 1.77⋅CaOM

(c)

Two cases are possible: 1. ClCaCl2 ≥ ClOM: only CaCl2 is present (no NaCl in mud): Calcium chloride content is calculated by equation (d) instead of (b). CaCl2OM (mg/L) = 1.57⋅CaOM CaCl2 (kg/m3) = 0.00157⋅CaOM

(d) CaCl2 (ppb) = 0.00035⋅CaOM

2. ClOM > ClCaCl2: both CaCl2 and NaCl are present In this case, Calcium chloride is determined by equation (b). To determine NaCl in the whole mud and chlorides from NaCl, use the following: ClNaCl (mg/L) = ClOM (mg/L) – ClCaCl2 (mg/L) NaClOM (mg/L) = 1.65⋅ClNaCl NaCl (kg/m3) = 0.00157⋅NaClOM Issue 1: November 2004 Rev. 0

(e) NaCl (ppb) = 0.00035⋅NaClOM OBM Analysis Page 60

C. Aqueous Phase Salt Content To determine salt content in the aqueous phase only (not in the whole mud). Calculations: WCaCl2 =

100 ⋅ CaCl 2 OM CaCl 2 OM + NaClOM + %W

WCaCl2 = %w of CaCl2 in brine WNaCl =

(f)

%W = % volume of water (from retort)

100 ⋅ NaClOM CaCl 2 OM + NaClOM + %W

WNaCl = %w of NaCl in brine

(g)

%W = % volume of water (from retort)

The CaCl2 and NaCl concentration in the aqueous phase are therefore: CCaCl2 (ppm) = 10000⋅WCaCl2

CCaCl2 (mg/L) = 10000⋅WCaCl2⋅ρB

(h)

CNaCl (ppm) = 10000⋅WNaCl

CCaCl2 (mg/L) = 10000⋅WCaCl2⋅ρB

(i)

Where ρB is the density of the brine and is calculated as follows: ρB = 0.99707 + 0.006504⋅WNaCl + 0.007923⋅WCaCl2 + 8.3334⋅10-5⋅ WNaCl⋅WCaCl2 + 4.395⋅10-5⋅(WNaCl)2 + 4.964⋅10-5⋅(WCaCl2)2

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OBM Analysis Page 61

2.9 OIL/WATER RATIO AND SOLIDS A. Corrected Solids It takes into account volume occupied by solids both in oil and in brine. Calculation: Volume percent of brine is calculated as follows: %B =

100 ⋅ %W ρ B ⋅ [100 − (W NaCl + WCaCl 2 )

%B = %v of brine

(a)

%W = %v of water (from retort)

The volume percent of corrected solids is therefore: VCS = 100 – (%O + %B) VCS = %v of corrected solids

%O = %v of oil (from retort)

B. Oil/Water Ratio (O/W) It is calculated as follows: Calculation: O=

100 ⋅ %O %O + %W

(b)

W=

O/W =

100 ⋅ %W %O + %W

(c)

O W

O = oil percentage in the O/W ratio W = water percentage in the O/W ratio

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C. Average Density of Suspended Solids Drill solids consists both in low-gravity solids (LGS) and high-gravity solids (HGS). Average density of solids contained in OBM is calculated as follows: Calculation: ρS (ppg) =

100 ⋅ d − %O ⋅ ρ O − VB ⋅ ρ B ⋅ 8.345 8.345 ⋅VCS

ρO = oil base density (ppg) d = mud density (ppg) VB = %v brine

(d) ρS = average density of solids (g/cm3) VCS = volume % of corrected solids ρB = brine density (ppg)

D. LGS and HGS The %v of HGS and LGS is: Calculation: VHGS =

ρ S − ρ LDS ⋅VCS ρ HDS − ρ LGS

VHGS = %v of HGS ρHGS = density of HGS (g/cm3) VLGS = %v of LGS

VLGS = VCS – VHGS ρS = average density of solids (g/cm3) ρLGS = density of LGS (g/cm3) VCS = %v of corrected solids

The concentration of HGS and LGS is: CHGS = 3.5⋅ρHGS⋅VHGS

CLGS = 3.5⋅ρLGS⋅VLGS

CHGS = HGS concentration (ppb)

CLGS = LGS concentration (ppb)

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OBM Analysis Page 63

2.10 RHEOLOGY When measuring the rheology of oil based drilling fluid, generally near bottom hole temperatures are used. A thermo-cup is used in order to heat the drilling fluid. A temperature of 49°C or 120°F is normally used. Equipment (Method 1): 1. Marsh Funnel The procedure for obtaining viscosity of oil- and water-based fluid are identical. Equipment (Method 2): 1. FANN 6-Speed Viscometer Model 35 or equivalent (OFI model 800) Procedure: 1. 2.

3. 4. 5. 6.

7.

Place a sample of drilling fluid in a heat cup. Leave enough empty volume in the cup for the displacement of the viscometer bob and sleeve. Heat the sample to the selected temperature. Intermittent or constant shear at the 600 rpm speed should be used to stir the sample while heating to obtain a uniform sample temperature. After the cup temperature has reached selected temperature, immerse the thermometer into the sample and continue stirring until the sample reaches the selected temperature. With the sleeve rotating at 600 rpm, wait for dial reading to reach a steady value (the time required is dependent on the mud characteristics). Record the dial reading for 600 rpm. Shift to 300 rpm and wait for dial reading to reach steady value. Record the dial readings. Stir drilling fluid sample for 10 seconds at high speed. Allow mud to stand undisturbed for 10 seconds. Slowly and steadily turn on the viscometer at 3 rpm. The maximum reading is the initially gel strength. Record the initial gel strength (10” gel). See calculations below. Re-stir the mud at high speed for 10 seconds and then allow the mud to stand undisturbed for 10 minutes. Repeat the measurement at 3 rpm as above and report maximum dial reading as 10’ gel.

Calculations: Apparent viscosity, AV (cP) = θ600/2 Plastic viscosity, PV (cP) = θ600 – θ300 Yield Point, YP (lb/100ft 2) = θ300 – PV Yield Point, YP (g/100cm2) =

θ 300 − PV = AV – PV 2

Gel strength (lb/100ft2) = θ3 for 0”, 10” or 10’ Gel strength (g/100cm2) =

θ3 for 0”, 10” or 10’ 2

θ600 = 600 rpm reading

θ300 = 300 rpm reading

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θ3 = 3 rpm reading

OBM Analysis Page 64

2.11 ACTIVITY MEASUREMENTS An important aspect of the brine phase is referred to as "activity". The term activity, in a drilling sense, describes the tendency for the movement of water vapor from an area of low salt concentration to an area of high salinity. The water activity (Aw) is measured as a fraction of the vapor pressure of water or relative humidity. In an invert emulsion drilling fluid the brine phase is not isolated from the formation by the oil phase. Water vapor may pass from the brine droplet into the formation or vice-versa depending upon the osmotic pressure differential between the brine phase and the formation. The osmotic pressure of the formation or brine phase is a measure of the activity and salinity of the formation and brine. The concentration of salt in the brine phase will largely determine whether water will flow from the brine to the formation, from the formation into the brine phase or whether there will be no net movement of water in either direction. Equipment: 1. A2101 AwQuick bench meter / HygroPalm Aw 1 hand held meter Procedure: 1. 2.

Place sample in cup (clear plastic 5ml dish) provided up to the fill line. Close cup with cover and place sample in the same general area as the probe to equalize the temperature to ambient. 3. When sample is ready, remove cover from the sample cup and place the cup inside the holder. 4. Put the probe on top of the sample holder. Make sure that the probe rests properly on the sample holder so that the O-ring located at the bottom of the probe can seal the sample. 5. Verify that the red LED at the top of the probe is flashing (fan indicator). 6. Immediately after placing the probe on top of the sample holder, press the ENTER key on the AwQuick 2101 meter to start the measurement. 7. Instrument will notify that reading has been obtained through a series of beeps. 8. If the temperature is not stable (+ 1°C) during the measurements, a warning is given on the readout. (i.e. + TS) 9. Press enter again, until temperature stabilizes and a reading is obtained. 10. The activity meter must be located in a stable temperature environment to operate properly, i.e. no drafts, heaters or fans located nearby.

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-3COMPLETION FLUIDS (CLEAR BRINES)

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Brine Analysis Page 67

3.1 DENSITY Equipment (Method 1): 1. Mud balance The procedure is the same as for WBM and OBM. Equipment (Method 2): 1. Hydrometers set (ranging from 0.8 to 2.4 sg) 2. 500 ml glass cylinder 3. Glass thermometer (0 – 100 °C) Hydrometers are more accurate than mud balance (accuracy: ± 0.002 g/cm3). Density measurement is greatly affected by temperature. Procedure: 1. 2. 3. 4. 5. 6.

Pour a sufficient brine volume into a 500 ml glass cylinder. Record sample temperature. Place the adequate hydrometer into the cylinder: it must float freely away from the walls of cylinder. If hydrometer touches the bottom of cylinder, choose another one. Read the density value at the point at which brine surface cuts hydrometer stem scale. The measured density must be corrected to 70 °F (21.1 °C) by use of following formulas.

Calculations: D70 = Dm + (T m – 70)⋅CF D70 = corrected density @ 70 °F (ppg) Tm = measured temperature (°F)

Dm = measured density @ T m temperature (ppg) CF = correction factor

CF = – 5.9659⋅10-4 + 8.341⋅10-4⋅Dm – 6.904⋅10-5⋅Dm2 + 2.1795⋅10-6⋅Dm3 Correction factor CF can be also determined by measuring brine density at 2 different temperatures: CF =

D1 − D2 T2 − T1

D1 = density at the lower temperature (ppg) D2 = density at the upper temperature (ppg)

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T1 = lower temperature (°F) T2 = upper temperature (°F)

Brine Analysis Page 68

3.2 TURBIDITY Brine turbidity is due to suspended solids, insoluble in water. Quantity, type and particle size distribution of solids affect brine quality. Turbidity is expressed as Nephelometric Turbidity Units (NTU): low NTU values indicate that brine is “clear” (low solids content). Equipment: 1. Turbidity meter (HANNA, mod. HI 93703) or equivalent. Turbidity range: Low-range: 0 – 50 NTU High-range: 50 – 1000 NTU Turbidity is not a measure of concentration of suspended solids, but a measure of their particle size distribution (PSD), shape, refractive index. Estimation of solids concentration by turbidity measurement can be done only if a calibration curve is generated. Coarse solids (greater than 200 mesh, 75 µm) are not determined with this method. Procedure: 1. 2. 3. 4. 5. 6. 7.

Collect a 100-ml sample of brine and pour it into a 200 mesh (75 µm) screen. Recover the sieved brine. Turn on the instrument and fill a clean cuvet with the filtered sample up to ¼” inch (0.5 cm) from its rim. Tighten the cap and wipe the cuvet with a clean paper. Do not touch the cuvet with fingers! Place the cuvet into the cell and check that notch on the cap is positioned securely into the groove. Be sure that the mark on cuvet cap points towards the LCD. Press “READY” key and wait for 25 – 30 seconds. Record the value displayed. Clean as soon as possible the cuvet with the cleaning solution or distilled water.

Calibration: A monthly calibration is recommended. To check last calibration date, just hold “DATE” for few seconds. 1. Turn on the instrument and press “CAL”. 2. When “CAL” message is blinking (about 6 sec) press “CAL” again, other wise calibration is stopped. 3. In the calibration mode “CL” will appear at the bottom of display: the new date of calibration can be edited simply pressing “DATE” and after “READY” (format: MM.DD). 4. To confirm displayed data press “CAL” and “ZERO” will be displayed. 5. Fill the cuvet with the 0 NTU standard provided (code HI 93703-0) and press “CAL”: after about 50 seconds the measurement is completed and will be displayed the next standard required, 10 NTU solution (code HI 93703-10). 6. Fill the cuvet with 10 NTU standard solution and press “CAL”: after about 50 seconds the measurement is completed and the instrument is calibrated.

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Brine Analysis Page 69

3.3 CRYSTALLIZATION TEMPERATURE The actual crystallization temperature (T C) of brine is the temperature at which a solid (salt or ice) will begin to form out of solution if given sufficient time and proper nucleating agents. TC is the temperature at which the brine is saturated with one or more salts that it contains. At this temperature, the least soluble salt’s solubility is exceeded and crystallizes. Cooling brine below TC results in additional formation of salt crystals. Salt precipitation due to temperatures lower than TC can lead to several problems (settling, plugging …) and brine viscosity rises. During crystallization, brine volume doesn’t expand (water expands when becomes ice). TC depends on brine density: TC decreases until salt saturation is reached; when salt concentration is greater than saturation, then T C increases with salt concentration. Several TC can be determined for brines: • FCTA (First Crystal To Appear): it is the temperature at which visible crystals start to form; • TCT (True Crystallization Temperature): it is the maximum temperature reached following the super-cooling minimum. If no super-cooling occurs, TCT = FCTA; it is the best measure of TC for a brine; • LCTD ( Last Crystal To Dissolve): it is the temperature at which, during heating, crystals disappear. Super-cooling effect appears when brines are cooled below TC and no crystals form due to lack of nucleating agents (BaO, Ba(OH)2, CaCO3, bentonite…). When crystals begin to form at FCTA, the heat released by the crystallization process increases brine temperature; further, the formation of crystals lowers the salt concentration in the remaining brine. In mixed brines, NaCl and KCl are less soluble than CaCl2, CaBr2, ZnBr2. Equipment: 1. Brine crystallization kit 2. Bath temperatures: Ice/Water slurry (50/50): 0°C (32°F) Ice/Saltwater slurry (50 Ice + 50 saturated NaCl solution): -15/-12°C (5/10°F) Ice/CaCl2 slurry (50 Ice + 50 CaCl2 solution: 50g of CaCl2 in 50g water): -40°C (40°F) The instrument permits determination of TCT, FCTA and LCTD. Procedure: 1. 2. 3. 4. 5.

6. 7.

Measure approximately 25 ml of brine and pour into container. Add nucleating agent to sample and put in the proper cooling bath, measuring brine temperature with thermometer. Stir the brine and record the temperature decrease. Record the minimum temperature reached before crystals begin to form as FCTA. Record maximum temperature achieved immediately after crystallization has occurred as TCT. Temperature should stabilize after 10 – 20 sec; if not super-cooling effects are present and test must be repeated using a warmer bath. Allow brine to warm slowly: record the temperature at which all crystals are dissolved as LCTD. Repeat this procedure at least 3 times and calculate the average value for each temperature.

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Brine Analysis Page 70

3.4 CHEMICAL ANALYSIS Chemical analysis can be done directly on a measured volume of brine sample.

A. Calcium The procedure is the same described for Calcium hardness in WBM. Equipment : 1. Titraver 4000 or EDTA 0.1M 2. Calver II indicator or murexide (to distinguish calcium from magnesium) 3. Sodium hydroxide (0.1N) solution (to distinguish calcium from magnesium) 4. Graduated pipettes (1 ml) 5. Distilled water 6. Stirrer + Stirring rod Procedure: 1. 2. 3. 4.

Using a pipette, measure 1.0 ml of brine into a white titration dish and dilute with a small amount of distilled water. Add 2 drops of 0.1N NaOH (sodium hydroxide). Solution pH must be approx. 12 – 13. Add several grains of calver II (or murexide) and swirl or stir to mix. Using a pipette, titrate with titraver (or EDTA) to a colour change from red to blue.

Calculation: Calcium (Ca+2, kg/m3) = 0.4⋅V V = ml of Titraver 400 (or EDTA 0.01M) added NOTE:

To better appreciate color change at end point, add 2 drops of methyl red (or potassium chromate) indicator until solution becomes orange (red + yellow): after titration color will change to green (blue + yellow).

NOTE:

Zinc ion interferes with this titration if present. In this case, quantity determined is the sum of Ca +2 and Zn+2.

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Brine Analysis Page 71

B. Chlorides and Bromides The procedure is the same described for chlorides in WBM. Equipment: 1. Silver nitrate solution: - 0.1N (or 0.0282N) for low chloride concentrations - 1N (or 0.282N) for high chloride concentrations 2. Potassium chromate indicator (5% solution) 3. Sulfuric acid (N/50) 4. Phenolphthalein indicator 5. Graduated pipettes (1 ml) 6. Titration beaker (100 ml) 7. Stirrer + Stirring rod Test Procedure: 1. 2.

3. 4.

Measure 1.0 ml of brine sample into a white titration beaker and dilute to convenient volume with distilled water. Add a few drops of phenolphthalein. If a pink colour develops add N/50 sulfuric acid until the pink colour completely disappears (it is not necessary to record the volume of N/50 sulfuric acid added) Add 4 drops of potassium chromate to obtain a yellow colour. Add silver nitrate while stirring until the colour changes from yellow to orange-red (brick red) or first color change that persists for 30 seconds.

NOTE:

If chlorides and bromides are both present in brine formulation, then they are titrated together. In this case, quantity determined is the sum of Cl- and Br-. This quantity can be expressed as only Cl- or Br-.

Calculations: 1. For NaCl, KCl, NaBr brines: kg/m3 = VT⋅F VT = ml of Silver Nitrate

0.1N Cl- = 3.545 Br-= 7.99 NaCl = 5.845 NaBr = 10.29 KCl = 7.455 Correction factors.

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F = correction factor Silver Nitrate concentration 1.0N 0.0282N Cl- = 35.45 Cl- = 1.0 Br = 79.9 Br-= 2.25 NaCl = 58.45 NaCl = 1.65 NaBr = 102.9 NaBr = 2.90 KCl = 74.55 KCl = 2.10

0.282N Cl- = 10.0 Br-= 22.5 NaCl = 16.50 NaBr = 29.0 KCl = 21.0

Brine Analysis Page 72

2. For CaCl2, CaBr2, ZnBr2 brines: kg/m3 = VT⋅F VT = ml of Silver Nitrate

0.1N Cl- = 7.09 Br-= 15.98 CaCl2 = 11.10 CaBr2 = 19.99 Correction factors.

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F = correction factor Silver Nitrate 1.0N 0.0282N Cl- = 70.9 Cl- = 1.99 Br-= 159.8 Br-= 4.50 CaCl2 = 111.0 CaCl2 = 3.13 CaBr2 = 199.9 CaBr2 = 5.64

0.282N Cl- = 19.9 Br-= 45.0 CaCl2 = 31.3 CaBr2 = 56.4

Brine Analysis Page 73

NOTES:

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Brine Analysis Page 74

-4AVA FLUID SYSTEMS

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AVA Systems Analysis Page 75

4.1 AVAGLYCO, AVAGLYCO MP The most suitable methods for rig site glycol analysis are refractometric analysis and cloud point determination. The value of refractive index is affected by many factors, such as solids, organic polymers (PAC, CMC …) and inorganic salts. In a mud system, glycol concentration is determined measuring the refractive index of filtrate with a refractometer; it is converted to glycol concentration through a calibration graph. The use of a commercial refractometer with 0 – 32 (or 0 – 18) °Brix scale reading is very useful (Brix degrees can be simply converted in refractive index). The cloud point temperature depends both on glycol and salt concentration (KCl, NaCl, …). Determination of cloud point in mud system can be quite difficult especially if there are suspended solids. Tables can help in evaluating cloud point of mud system, as function of glycol and salt concentrations.

A. Refractive index method Equipment: 1. Portable Refractometer 2. Plastic Pasteur Procedure: 1. 2. 3. 4. 5.

Prepare at least 3 standard solutions with concentration ranging from 10.0 to 50.0 kg/m3. Standard glycol solutions must be as close as possible to filtrate composition. Put a drop of distilled water on refractometer: it must indicate 0 °Brix. If not so, adjust calibration screw until 0 °Brix are displayed. Put a drop of standard glycol solutions at different concentrations and read. Draw a calibration curve using the standard solutions. Put a drop of filtrate and compare with calibration curve.

NOTE:

Clean refractometer display with adsorbent paper after each measurement.

Calculations: Brix degree can be converted into glycol concentration after calibration curve has been determined.

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AVA Systems Analysis Page 76

NOTE:

°Brix 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

If refractometer used displays refractive index instead of Brix degrees, then the following correlation chart can be used. n20 1.33299 1.33442 1.33586 1.33732 1.33879 1.34026 1.34175 1.34325 1.34476 1.34629 1.34782 1.34937 1.35093 1.35250 1.35408 1.35568 1.35729 1.35891 1.36054 1.36218 1.36384 1.36551 1.36720 1.36889 1.37060 1.37233

°Brix 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51

n20 1.37406 1.37582 1.37758 1.37936 1.38115 1.38296 1.38478 1.38661 1.38846 1.39032 1.39220 1.39409 1.39600 1.39792 1.39986 1.40181 1.40378 1.40576 1.40776 1.40978 1.41181 1.41385 1.41592 1.41799 1.42009 1.42220

°Brix 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77

n20 1.42433 1.42647 1.42862 1.43080 1.43299 1.43520 1.43743 1.43967 1.44193 1.44420 1.44650 1.44881 1.45113 1.45348 1.45584 1.45822 1.46061 1.46203 1.46546 1.46790 1.47037 1.47285 1.47535 1.47787 1.48040 1.48295

°Brix 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95

n20 1.48552 1.48810 1.49071 1.49333 1.49597 1.49862 1.50129 1.50398 1.50671 1.50944 1.51219 1.51496 1.51775 1.52056 1.52338 1.52622 1.52909 1.53196

n20 is refractive index @ 20°C.

INTERFERENCES:

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The followings products interfere with this determination: Sorbitol-based compounds, such as Avabiolube

AVA Systems Analysis Page 77

4.2 AVAPOLYSIL, AVASILIX, AVASHALESTOP/ACT, AVA EXTRA-DRILL To determine AVAPOLYSIL, AVASILIX 39 or AVASILIX 22, AVSHALESTOP/ACT and AVA EXTRA-DRILL concentration in WBM, a colorimetric method for silica is used. At pH 1 – 2 soluble silicates react with ammonium molibdate to form silico-molibdic acid; this acid is reduced by “methol” (n-p-methylaminophenol sulphate) in a silico-molibdic blue complex. Chemical reaction that takes place is the following one: H4SiO4 + 12 H2MoO4 ⇒ H4Si(Mo3O10)4 + 12 H2O Methol → Blue complex

Equipment: 1. Silica kit (Carlo Erba “Idrimeter” or equivalent) 2. Bi-distilled water 3. Graduated Pipette (5 ml) Procedure: 1. 2. 3. 4. 5.

Pour 2 portions of 5.0 ml filtrate into the 2 vials (left side: blank – right side: sample) Into the right vial add 4 drops of Reagent A. Shake the sample and wait for 10 min. Add into the right vial 4 drops of Reagent B and 4 drops of Reagent C. Wait for 5 min and compare the colors of the 2 vials. If necessary, using a graduated pipette, put the adequate filtrate volume into a volumetric flask to dilute it. Dilution ratio depends on concentration of silicate into the drilling fluids and on the range of concentration detectable with the kit used.

NOTE:

Colorimetric kit permits determination of silica at concentrations of: 0.2 mg/L < SiO2 < 5.0 mg/L.

NOTE:

Average percentage of silicate (express as SiO2) contained in AVA products are the followings: AVAPOLYSIL

%SiO2 = 12% ± 1%

AVASILIX 22

%SiO2 = 27 ± 1%

AVASILIX 39

%SiO2 = 28 ± 1%

AVA EXTRA-DRILL

%SiO2 = 2.5 ± 0.5%

AVASHALESTOP/ACT

%SiO2 = 12% ± 1%

INTERFERENCES:

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The followings ions interfere with this determination: Iron and Copper if conc. >50 ppm; Calcium, Magnesium, Potassium, and Sodium if conc. >500 ppm; Phosphates if conc. >500 ppm.

AVA Systems Analysis Page 78

4.3 AVACLAYBLOCK, AVAFASTDRILL, AVASHALESTOP, AVAPOLYMER 5050 Determination of AVACLAYBLOCK is based upon a colorimetric method and is therefore a semiquantitative analysis. Equipment: 1. Boric acid 4% 2. Iodine/Iodide (I2/I-) solution (indicator) 3. Graduated pipette (5 ml) 4. Beaker (100 ml) 5. Distilled water Procedure: 1. 2. 3. 4. 5.

Prepare at least 3 standard solutions with concentration ranging from 10.0 to 40.0 kg/m3. Standard solutions must be as close as possible to filtrate composition. Add a few drops of indicator to these solutions. To 5.0 ml of filtrate, add 1.5 ml of boric acid solution and a few drops of indicator. Wait for 15 minutes. Compare color with the one obtained using the standard solutions.

NOTE:

Preparation of I2/I- solution: add 12.5 g of KI to 100 ml of distilled water; add then 6.35 g of I2. After solubilization, dilute to 500 ml. Store solution in a dark bottle. Shelf life is about 3 months.

INTERFERENCES:

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The followings products interfere with this determination: Glycol compounds, such as Avaglyco; Sorbitol-based compounds, such as Avabiolube

AVA Systems Analysis Page 79

4.4 AVADES 100 AVADES 100 is based on triazine derivatives; it reacts rapidly and irreversibly with H2S. Test is therefore used to determine Avades 100 excess in WBM. This quantity can be estimated by detection of total formaldehyde in filtrate. Quantity of formaldehyde is directly related to presence of free (non-reacted) triazine. This is a colorimetric test, based on the following chemical reactions: CH2O + Na2SO3 ⇒ CH2O4SNa2 CH2O4SNa2 + 2HCl ⇒ 2NaCl + SO 2 + H2O + CH2O Although test is semi-quantitative, results can be interpreted as follows: • Positive test (presence of formaldehyde): Avades 100 is still present in mud (no H2S is present) • Negative test (absence or little presence of formaldehyde): Avades 100 has been consumed totally by H2S. It is necessary add it again to the mud in order to scavenge remaining quantity of H2S. Equipment 1: 1. Formaldehyde kit (Hanna mod. HI 3838 or similar) Equipment 2: 1. Reagent 1: Alizarin Yellow solution (indicator) 2. Reagent 2: Sodium Sulfite, powder 3. Reagent 3: Hydrochloric acid < 20% 4. Graduated pipettes (1 ml and/or 5 ml) 5. Beaker (100 ml) 6. Syringe (0.01 ml division) Procedure: Test can detect both high (0 – 10%) and low (0 – 1%) formaldehyde concentration. For rig analysis, procedure for low range is usually used.

A. High range (0 – 10 %): 1. 2. 3. 4.

Put 0.5 ml of filtrate into the beaker. Dilute with 4.5 ml of distilled water (up to the mark). Add 2 drops of Reagent 1 (indicator). Add few grains of Reagent 2: if formaldehyde is present a red-orange color will appear. Fill the syringe with Reagent 3 and titrate drop-by drop until color change to yellow.

B. Low Range (0 – 1 %): 1. 2. 3. 4.

Put 5.0 ml of filtrate into the beaker. Add 2 drops of Reagent 1 (indicator). Add few grains of Reagent 2: if formaldehyde is present a red-orange color will appear. Fill the syringe with Reagent 3 and titrate drop-by drop until color change to yellow.

NOTE:

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1 ppm of formaldehyde corresponds approx. to 4.6 ppm of Avades 100. Calibration curve can be useful to have better results. AVA Systems Analysis Page 80

Calculations: If High range (0 – 10 %) method is used: AVADES 100 (kg/m3) = VT⋅460 If Low range (0 – 1 %) method is used: AVADES 100 (kg/m3) = VT⋅46 VT = ml of Reagent 3 used NOTE:

Factors used in formulas are indicatives.

INTERFERENCES:

A. Sodium Sulfite (DEOXY SS): DEOXY SS can react with formaldehyde coming from Avades 100: this reaction is influenced by pH. Under alkaline or neutral conditions (as in drilling fluids), formaldehyde is released from Avades 100 slowly and therefore formaldehyde concentration is low. DEOXY SS is therefore available for scavenging oxygen. B. Filtrate alkalinity: Test is based on acid-base titration with colorimetric indicator (range of color change: 10.5 < pH < 12.0). Therefore alkaline products such as Caustic Soda, Caustic Potash, Sodium Carbonate, Potassium Carbonate … can cause positive interference.

NOTE:

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Test doesn’t represent a hazard to human health because of small quantities of formaldehyde involved (< 1 – 2%) and because formaldehyde is present only in aqueous solution.

AVA Systems Analysis Page 81

4.5 AVAPOLYOIL (DEEPDRILL™) AVAPOLYOIL (DEEPDRILL™) is a blend of polyhydroxyl alcohols; its determination in drilling fluids is based upon a refractometric method. Equipment: 1. Portable Refractometer 2. Plastic Pasteur Procedure: Analysis of filtrate chlorides must be performed prior to begin testing. 1. Prepare at least 3 standard solutions with concentration ranging from 80.0 to 150.0 kg/m3. Standard solutions must be as close as possible to filtrate composition. 2. Put a drop of distilled water on refractometer: it must indicate 0 °Brix. If not so, adjust calibration screw until 0 °Brix are displayed. 3. Put a drop of standard solutions at different concentrations and read. 4. Draw a calibration curve using the standard solutions. 5. Put a drop of filtrate and compare with calibration curve. Calculation: Avapolyoil (%v) =

( R − 2.58) − (0.000138 ⋅ Cl ) 0.558

R = refractometer reading (°Brix) Avapolyoil = volume %

Cl = filtrate chlorides (mg/L)

NOTE:

Carefully clean refractometer display with adsorbent paper after each measurement taking care not to scratch the lens.

INTERFERENCES:

The followings products interfere with this determination: Glycol compounds, such as Avaglyco

Issue 1: November 2004 Rev. 0

AVA Systems Analysis Page 82

4.6 AVABIOLUBE AVABIOLUBE is polysorbitol-based compound; its determination in drilling fluids is based upon a refractometric method. Equipment: 1. Portable Refractometer 2. Plastic Pasteur Procedure: 1. 2. 3. 4. 5.

Prepare at least 3 standard solutions with concentration ranging from 20.0 to 600.0 kg/m3. Standard solutions must be as close as possible to filtrate composition. Put a drop of distilled water on refractometer: it must indicate 0 °Brix. If not so, adjust calibration screw until 0 °Brix are displayed. Put a drop of standard solutions at different concentrations and read. Draw a calibration curve using the standard solutions. Put a drop of filtrate and compare with calibration curve.

NOTE:

Clean refractometer measurement.

INTERFERENCES:

The followings products interfere with this determination: Glycol compounds, such as Avaglyco

Issue 1: November 2004 Rev. 0

display

with

adsorbent

paper

after

each

AVA Systems Analysis Page 83

4.7 DEOXY DEHA DEOXY DEHA is oxygen scavenger product based on amine compounds. Excess of product in drilling fluids must be guaranteed and therefore its determination is important. Test is based on a colorimetric reaction and is performed according ASTM D-5543/94 procedure. Equipment: 1. Dissolved oxygen kit (Chemetrics code K-7501 or similar): 0 – 1 ppm O2 Procedure: 1. 2. 3. 4. 5. 6.

Insert the glass ampoule into the mud sample with the pointed end down. Allow the sample to flow in at least 5 min. Gently press the ampoule toward the wall of sampling tube to snap the tip and remove the ampoule, keeping the tip down, immediately after filling is complete. Place a finger over the broken tip (CAUTION: glass may be sharp). Invert the ampoule several times to allow mixing of content. Compare color developed (pink) in the ampoule by placing it in the center of the comparator, with the flat end downward. Rotate wheel until the color in the ampoule matches the one of the comparator.

NOTE:

Compare color within 30 seconds after snapping the tip of the ampoule. After 30 sec color may continue to increase

NOTE:

Store glass ampoule in a dark place.

INTERFERENCES:

Color, turbidity and oxidizing agents interfere with this determination. Easily reduced metal ions, Cu+2, Fe+3 interfere at concentration >50 µg/L. Oxygen in atmosphere does not interfere.

Issue 1: November 2004 Rev. 0

AVA Systems Analysis Page 84

CONVERSIONS, CALCULATIONS & PROPERTIES SECTION II

TABLE OF CONTENTS

CONVERSION FACTORS......................................................................................................... 1 GENERAL FORMULAS ............................................................................................................ 5 PILOT TESTING GUIDELINES............................................................................................... 9 DENSITY ADJUSTMENTS ....................................................................................................... 11 DENSITY ADJUSTMENT WITH BARITE ................................................................................. 11 DENSITY ADJUSTMENT WITH CALCIUM CARBONATE .................................................... 12 MUD VOLUME TO PREPARE 1 M3 OF MUD WEIGHTED WITH BARITE........................... 13 DENSITY REDUCTION WITH WATER .................................................................................... 14 DENSITY REDUCTION WITH DIESEL OIL ............................................................................. 15 DENSITY REDUCTION WITH LT OIL ...................................................................................... 16 COMPLETION FLUIDS ............................................................................................................ 17 BRINE DILUTION ....................................................................................................................... 17 WEIGHTING BRINES ................................................................................................................. 18 BRINE DENSITY TABLE............................................................................................................ 22 BRINE CALCULATIONS ............................................................................................................ 24 TEMPERATURE CORRECTION FACTORS.............................................................................. 30 VOLUME EXPANSION CORRECTION..................................................................................... 33 PROPERTIES OF SODIUM CHLORIDE SOLUTIONS.............................................................. 34 PROPERTIES OF POTASSIUM CHLORIDE SOLUTIONS ....................................................... 35 Issue 1: November 2004 Rev. 0

Index

Page i

PROPERTIES OF POTASSIUM BROMIDE SOLUTIONS......................................................... 36 PROPERTIES OF POTASSIUM CARBONATE SOLUTIONS................................................... 37 PROPERTIES OF SODIUM BROMIDE SOLUTIONS ............................................................... 38 PROPERTIES OF POTASSIUM SULFATE SOLUTIONS.......................................................... 40 PROPERTIES OF CALCIUM CHLORIDE SOLUTIONS ........................................................... 41 PROPERTIES OF CALCIUM BROMIDE SOLUTIONS ............................................................. 44 PROPERTIES OF SODIUM/CALCIUM CHLORIDE BLENDS ................................................. 46 PROPERTIES OF CALCIUM CHLORIDE/BROMIDE BLENDS .............................................. 47 PROPERTIES OF ZINC/CALCIUM BROMIDE BLENDS ......................................................... 48 PROPERTIES OF ZINC/CALCIUM BROMIDE/CALCIUM CHLORIDE BLENDS ................. 49 PROPERTIES OF AMMONIUM CHLORIDE SOLUTIONS ...................................................... 50 PROPERTIES OF MAGNESIUM CHLORIDE SOLUTIONS ..................................................... 51 PROPERTIES OF POTASSIUM ACETATE SOLUTIONS ......................................................... 52 PROPERTIES OF SODIUM FORMATE SOLUTIONS............................................................... 53 PROPERTIES OF POTASSIUM FORMATE SOLUTIONS ........................................................ 55 PUMPS ......................................................................................................................................... 59 DUPLEX PUMP OUTPUT ........................................................................................................... 60 TRIPLEX PUMP OUTPUT........................................................................................................... 61 CAPACITIES AND VOLUMES ................................................................................................ 63 CAPACITY OF HOLE VOLUMES.............................................................................................. 63 CAPACITY OF DRILL COLLARS.............................................................................................. 65 CAPACITY AND DISPLACEMENT OF CASING ..................................................................... 66 CAPACITY AND DISPLACEMENT OF DRILL PIPES ............................................................. 68 Issue 1: November 2004 Rev. 0

Index

Page ii

CAPACITY AND DISPLACEMENT OF TUBINGS ................................................................... 69 ANNULAR VOLUME BETWEEN DRILL PIPE AND OPEN HOLE OR CASING................... 70 ANNULAR VOLUME BETWEEN DRILL COLLARS AND OPEN HOLE OR CASING......... 71 DIMENSIONS AND STRENGTHS OF DRILL PIPE .................................................................. 73 HOLE VOLUME........................................................................................................................... 74 ANNULAR VELOCITY MULTIPLIERS..................................................................................... 75 STORAGE TANK VOLUMES ..................................................................................................... 76 BUOYANCY FACTORS .............................................................................................................. 81 MUD PROPERTIES ................................................................................................................... 83 RECOMMENDED SOLID CONTENT OF WATER BASED MUD ........................................... 83 SUGGESTED RANGES OF PLASTIC VISCOSITY ................................................................... 84 SUGGESTED RANGES OF YIELD POINT ................................................................................ 84 INFLUENCE OF CAUSTIC SODA ON CALCIUM SOLUBILITY............................................ 85 INFLUENCE OF SALT ON CALCIUM SOLUBILITY .............................................................. 85 CHEMICAL AND PHYSICAL DATA ...................................................................................... 87 MOHS’ HARDNESS SCALE ....................................................................................................... 87 HARDNESS: COMMON OIL FIELD MATERIAL ..................................................................... 87 PH RANGES OF COMMON INDICATORS ............................................................................... 88 APPROXIMATE PH OF ACIDS, BASES AND OILFIELD CHEMICALS ................................ 89 CALCULATED EQUILIBRIUM GEOMETRY MODEL ............................................................ 90 SIEVE MESH-MICRON CORRELATION CHART .................................................................... 91 COMMON CHEMICAL FORMULAS AND NAMES................................................................. 92 COMMON DRILLING MUD CATIONS ..................................................................................... 93 Issue 1: November 2004 Rev. 0

Index

Page iii

COMMON DRILLING MUD ANIONS ....................................................................................... 93 SPECIFIC GRAVITY OF COMMON MATERIALS ................................................................... 94 CEMENT DATA.......................................................................................................................... 95 CEMENT DATA AND CLASSES................................................................................................ 95 FRESH-WATER CEMENT SLURRIES....................................................................................... 96 SALT-WATER CEMENT SLURRIES ......................................................................................... 97 BENTONITE CEMENT SLURRIES ............................................................................................ 99 EFFECTS OF SOME ADDITIVES ON CEMENT PROPERTIES ............................................... 103

Issue 1: November 2004 Rev. 0

Index

Page iv

CONVERSION FACTORS Property Annular Velocity Pump Pressure Slip Velocity Temperature Funnel viscosity Apparent &Plastic Viscosity Shear rate Yield point Gel Strength Dial reading Area Distance

Liner Length & Diameter Bentonite Yield MBT (Bentonite Equivalent) Filter Cake Thickness Additive concentration Solids & liquids Bit Size Depth Hole & Pipe Diameter Weight on Bit Casing Capacity / displacement Casing Weight Hook Load Corrosion Rate Issue 1: November 2004 Rev. 0

Common Units (API) ft/min pound/sq inch (psi) ft/min Fahrenheit (°F) Seconds/quart (s/qt) seconds/m3 Centipoises (cP) Reciprocal second (s-1) lb/100ft2 lb/100ft2 lb/100ft2 Acre miles miles inches yards (yd) feet (ft) inches (in) bbl/sh ton lb/bbl 32’nds inch (1/32 in) pounds/barrel (ppb) Volume percent Inches (in) Feet (ft) Pound (lb) bbl/ft lb/ft thousands of pounds lb/ft2/day mils per year (mpy)

Convert to (multiply by): 0.3048 6.9 0.3048 (°F-32)/1.8 1.057 1.0 1.0 1.0 0.48 0.48 0.51 0.4047 1609.35 1.6093 39.37 1.0936 3.2808 25.4 0.175 2.85 0.794 2.8 0.01 25.4 0.3048 4.4 0.5216 0.188 0.444 13.377 0.254

“SI” or Metric Unit meters/minute kilopascal meter/minute Celsius seconds/liter seconds/liter millipascal second Reciprocal second Pascal Pascal Pascal hectares meters kilometers meters meters meters millimeters cubic meters/tonne kilograms/cubic meter millimeters kilogram/cubic meter cubic meter/cubic meter Millimeters meters Newton cubic meters/meter kilograms/meters decanewtons grams/square meter/day milligrams/day

Symbol m/min kPa m/min °C s/L s/L mPa.s s-1 Pa Pa Pa ha m km m m m mm m3/tonne kg/m3 mm kg/m3 m3/m3 mm m N m3/m kg/m daN g/m2/day mg/day Conversion Factors

Page 1

Property Flow Rate Fluid Loss Drill Rate Horsepower Horsepower /sq. inch Nozzle Size Nozzle velocity Rotary Speed Pounds Force Pressure Pump Data Pump Output/Stroke Shear Rate Shear stress Torque Ionic Concentration in Water Material Concentration Mud Density Mud Gradient Particle Size Volumes

Issue 1: November 2004 Rev. 0

Common Units (API) US gallons/min bbl/min milliliters or cc (ml) feet/hour (ft/h) Horsepower (hp) Hp/in2 32’nds inch (1/32 in) feet/sec (ft/s) revolutions/min (rpm) Pounds (lb) psi bbl/stroke bbl/stroke reciprocal second (s-1) lb/100ft2 dynes/cm2 ft/lb parts per million (ppm) lb/bbl (ppb) equivalents (eq) lbs/gal psi/foot microns (µm) Barrels (bbl) US gallons/stroke US gallons/stroke US gallon (gal US) Imperial Gallon (gal UK) US gallon (gal US) Imperial Gallon (gal UK) Oilfield barrel (42 US gal) Cubic yards (yd3)

Convert to (multiply by): 0.003785 0.159 1.0 0.3048 745.7 1.15 0.794 0.3048 1.0 4.448 6.895 0.006895 0.1589873 m3 159.0 1.0 0.48 0.10 1.3558 1.0 2.85 1.0 119.83 22.621 1.0 0.158984 0.003785 3.785 3.785 4.546 0.003785 0.004546 0.1589 0.7646

“SI” or Metric Unit cubic meters/min cubic meters/min milliliters or cc’s meters/hour watts megawatts/square meter millimeters meter/second revolutions/min (rpm) Newton kilopascals megapascals cubic meters/stroke liters/stroke reciprocal second Pascal Pascal Newton⋅metre milligram/liter kilogram/cubic meter moles/cubic meter kilograms/cubic meters kilopascals/meter micrometers cubic meters cubic meters/stroke liters/stroke liter liter cubic meter cubic meter cubic meter cubic meter

Symbol m3/min m3/min ml or cm3 m/h W MW/m2 mm m/s rpm N kPa MPa m3/stroke L/stroke sec-1 Pa Pa N⋅m mg/L kg/m3 mol/m3 kg/m3 kPa/m µm m3 3 m /stroke L/stroke L L m3 m3 m3 m3 Conversion Factors

Page 2

Property Weight Density

Issue 1: November 2004 Rev. 0

Common Units (API) Short ton Long ton

Convert to (multiply by): 907 1016

“SI” or Metric Unit kilos kilos

Symbol kg kg

lb/bbl (ppb) lb/gal (ppg) lb/ft3 (pcf)

2.853 0.1198 0.01602

grams/liter grams/cubic meter grams/cubic meter

g/L g/cm3 g/cm3

Conversion Factors

Page 3

NOTES:

Issue 1: November 2004 Rev. 0

Conversion Factors

Page 4

GENERAL FORMULAS 1. Annular Volume (m3) =

8. Annular Velocity (m3/min) =

[Hole Capacity (m3/m) – (Pipe Displacement (m3/m) + Pipe Capacity (m3/m))]⋅Length (m) 2. Pipe Volume (m3) =

9. Hydrostatic Pressure (kPa) =

3. Total Hole Volume (m3) = 3

[Hole Capacity (m /m) – Pipe Displacement (m /m)]⋅Length (m)

Density (kg/m3)⋅0.00981⋅Depth (m) 10. Pressure Gradient (kPa/m) =

4. Tank Volume (m3) = Length (m)⋅Width (m)⋅Height (m) 5. Total Circulating Volume (m3) = Total Hole Volume (m3) + Tank Volume (m3) 6. Total Circulating Time (min) = Total Circulating Volume (m3) Pump Output (m3/min) 7. Bottoms Up Time (min) = 3

Total Annular Volume (m ) Pump Output (m3/min)

Issue 1: November 2004 Rev. 0

Dh 2 − Dp 2

Dh = Hole Diameter (mm) Dp = Pipe Diameter (mm)

Pipe Capacity (m3/m)⋅Length (m)

3

PumpOutput(m 3 / min) ⋅ 1273000

Density (kg/m3)⋅0.00981 11. Barite Required for a Mud Density Increase (kg/m3) = 4250⋅

(W2 − W1 ) 4250 − W2

W2 = Desired Mud Density (kg/m3) W1 = Initial Mud Density (kg/m3)

12. Volume Increase form Barite Addition (m3 ) = Amount of Barite Added (kg) 4250

General Formulas

Page 5

13. Density Reduction with Water; water required (m3) = V ⋅ (W1 − W2 ) W2 − 1000

17. Hydraulic Horsepower Across the Face of the Bit HH (MH/m2) = HHb ⋅ 1.27 d2

V = Initial Starting Volume (m3) W1 = Initial Mud Density (kg/m3) W2 = Desired Mud density (kg/m3)

HHb – Hydraulic Horsepower at the Bit (W) d = Diameter of the Bit (mm) 3

14. Density Reduction with Oil; final mud density (kg/m ) =

18. Equivalent Circulating Density (kg/m3) = MW =

W1 + %Oil (Wo ) 1 + %Oil

W1 = Initial Mud Density (kg/m3) Wo = Density of Oil (kg/m3) % Oil = Volume Fraction of Oil, i.e.: 2% oil as volume fraction is 0.02

15. Pressure Loss at the Bit ∆Pb (mPa) =

∆P L ⋅ 0.00981

MW = Mud Weight P = Sum of all the Annular Pressure Losses (kPa) L = Depth of Interest (m)

19. “n” Factor Power Law Index = 3.32 log 10

MW ⋅ Q 2 ⋅ 248 (d12 + d 22 + d 32 ) 2

MW = Mud Weight (kg/m3) Q = Pump Output (m3/min) d1, d2, d3 = Bit Nozzle Diameter (mm)

16. Hydraulic Horsepower at the Bit HHb (W) = Q⋅∆Pb⋅(1.66⋅104) 3

θ 600 θ 300

θ = Viscometer Dial Reading 20. Volume Fraction of Solids (unweighted mud) % volume fraction = MW − 1 ⋅ 0.625 1000

MW = Mud Weight (kg/m3)

Q = Pump Output (m /min) Pb = Pressure Loss at the Bit (mPa) Issue 1: November 2004 Rev. 0

General Formulas

Page 6

21. Temperature conversion factors: °F = °C⋅

9 + 32 5

°C = (°F+32)⋅

1 short ton = 2000 lb = 907 kg 1 long ton = 2240 lb = 1016 kg 1 metric ton = 2205 lb = 1.10 short ton = 0.984 long ton

5 9

26. Increasing O/W ratio:

22. Correspondence between Degrees API and density: Degrees API =

141.5 − 131.5 d0

d0 = specific gravity @ 15.6 °C (60 °F) 23. Resistance and resistivity: R (Ω) = ρ⋅

25. Cement conversion units:

l S

ρ = R⋅

V +VB O⋅( O ) − VO 100 VO = ⋅V B

VO = Oil volume (bbl) O = Desired O/W ratio V = Mud volume (bbl)

VB = Brine volume (bbl) B = Desired O/B ratio

27. Decreasing O/W ratio: S l

B ⋅(

VB = R = Resistance. Ω ρ = Resistivity. Ω⋅m l = length of conductor (m) S = cross-sectional area of conductor (m2)

VO + VB ) − VB 100 ⋅V O

VO = Oil volume (bbl) O = Desired O/W ratio V = Mud volume (bbl)

VB = Brine volume (bbl) B = Desired O/B ratio

24. Temperature variance of Resistance and Resistivity: RT = R0⋅(1 + αt)

ρT = ρ0⋅(1 + αt)

RT, ρT = resistance and resistivity at temperature T R0, ρ0 = resistance and resistivity at temperature 0 °C α = temperature coefficient at 15 °C

Issue 1: November 2004 Rev. 0

General Formulas

Page 7

NOTES:

Issue 1: November 2004 Rev. 0

General Formulas

Page 8

PILOT TESTING–GUIDELINES FOR MEASURING PRODUCTS The following table is provided as an accurate approximation of mass when no balance is present. 1. Procedure: • Powdered materials: Fill the measuring spoon to overflowing. Tap lightly, and level with a straight edge. • Liquid material: Use a syringe 2. Example: 1 gram is equivalent to 1 kilogram 1 liter is equivalent to 1 m3 Adding 33.5 grams (5 tablespoons) of Bentonite to 1 liter of freshwater would be equivalent to a concentration of 33.5 kg/m3.

Issue 1: November 2004 Rev. 0

Pilot Testing Guidelines

Page 9

PRODUCT Barite Bentonite Calcium Carbonate Calcium Chloride Caustic Soda CMC Desco CF Drispac Gilsonite HT Gypsum Lignite Lime Magnesium Sulfate Mica Potassium Sulfate Salt Soda Ash Sodium Bicarbonate Soltex Victosal VISCO 83 Visco XCD Zinc Carbonate

Issue 1: November 2004 Rev. 0

SPECIFIC GRAVITY 4.20 2.50 2.80 2.20 2.13 1.50 1.60 1.50-1.60 1.05 2.90 1.50 2.20 2.66 2.90 2.66 2.17 2.53 2.16 1.2-1.5 1.45 0.3-0.9 1.5 4.4

¼ Teaspoon (grams) 1.15 0.76 0.9 0.56 1.28 0.55 0.58 0.60 0.26 0.85 0.51 0.37 0.9 0.76 1.14 1.05 1.00 1.1 0.62 0.47 0.51 0.58 0.4

½ Teaspoon (grams) 2.3 1.52 1.8 1.12 2.56 1.10 1.16 1.20 0.52 1.70 1.02 0.74 1.8 1.52 2.28 2.1 2.00 2.2 1.24 0.94 1.02 1.16 0.8

1 Teaspoon (grams) 4.6 3.04 3.6 2.24 5.12 2.20 2.32 2.40 1.04 3.40 2.04 1.48 3.6 3.04 4.56 4.2 4.00 4.4 2.48 1.88 2.04 2.32 1.6

1 Tablespoon (grams) 21.2 9.14 9.5 9.53 12.87 9.15 7.67 7.60 4.34 7.6 7.19 4.60 12.9 10.66 16.97 14.82 14.0 10.6 8.92 6.83 6.28 7.47 5.92

Pilot Testing Guidelines

Page 10

DENSITY ADJUSTMENT WITH BARITE Weight (kg) of Barite to add to 1 m3 of mud. Desired s.g. Initial s.g. 1.00 1.05 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80 1.85 1.90 1.95 2.00 2.05 2.10 2.15 2.20

1.05

1.10

1.15

1.20

1.25

1.30

1.35

1.40

1.45

1.50

1.55

1.60

1.65

1.70

1.75

1.80

1.85

1.90

1.95

2.00

2.05

2.10

2.15

2.20

2.25

67

135 68

207 138 69

280 210 140 70

356 285 214 142 71

434 362 290 217 145 72

516 442 368 295 221 147 74

600 525 450 375 300 225 150 75

687 611 535 458 382 305 229 153 76

778 700 622 544 467 389 311 233 156 78

872 792 713 634 555 475 396 317 238 158 79

969 888 808 727 646 565 485 404 323 242 162 81

1071 988 906 824 741 659 576 494 412 329 247 165 82

1176 1092 1008 924 840 756 672 588 504 420 336 252 168 84

1286 1200 1114 1029 943 857 771 686 600 514 429 343 257 171 86

1400 1313 1225 1138 1050 963 875 788 700 613 525 438 350 263 175 88

1519 1430 1340 1251 1162 1072 983 894 804 715 626 536 447 357 268 179 89

1643 1552 1461 1370 1278 1187 1096 1004 913 822 730 639 548 457 365 274 183 91

1773 1680 1587 1493 1400 1307 1213 1120 1027 933 840 747 653 560 467 373 280 187 93

1909 1814 1718 1623 1527 1432 1336 1241 1145 1050 955 859 764 668 573 477 382 286 191 95

2051 1953 1856 1758 1660 1563 1465 1367 1270 1172 1074 977 879 781 684 586 488 391 293 195 98

2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100

2356 2254 2151 2049 1946 1844 1741 1639 1537 1434 1332 1229 1127 1024 922 820 717 615 512 410 307 205 102

2520 2415 2310 2205 2100 1995 1890 1785 1680 1575 1470 1365 1260 1155 1050 945 840 735 630 525 420 315 210 105

2692 2585 2477 2369 2262 2154 2046 1938 1831 1723 1615 1508 1400 1292 1185 1077 969 862 754 646 538 431 323 215 108

W = 4200⋅

W = quantity of barite (kg) for 1 m3

Issue 1: November 2004 Rev. 0

d2 = desired density (s.g.)

d 2 − d1 4.2 − d 2

d1 = initial density (s.g.)

Density Adjustment

Page 11

DENSITY ADJUSTMENT WITH CALCIUM CARBONATE Weight (kg) of Calcium Carbonate to add to 1 m3 of mud. Desired s.g. Initial s.g.

1.00 1.05 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70

1.05

1.10

1.15

1.20

1.25

1.30

1.35

1.40

1.45

1.50

1.55

1.60

1.65

1.70

1.75

83

171 85

265 177 88

366 274 183 91

473 379 284 189 95

589 491 393 294 196 98

713 612 510 408 306 204 102

848 742 636 530 424 318 212 106

994 883 773 663 552 442 331 221 110

1152 1325 1037 1205 922 1084 807 964 691 843 576 723 461 602 346 482 230 361 115 241 120

1514 1388 1262 1136 1010 883 757 631 505 379 252 126

1723 1590 1458 1325 1193 1060 928 795 663 530 398 265 133

1953 1813 1674 1534 1395 1255 1116 976 837 697 558 418 279 139

2208 2061 1914 1767 1619 1472 1325 1178 1031 883 736 589 442 294 147

W = 2650⋅

W = quantity of calcium carbonate (kg) for 1 m3

Issue 1: November 2004 Rev. 0

d 2 − d1 2.6 − d 2

d2 = desired density (s.g.)

d1 = initial density (s.g.)

Density Adjustment

Page 12

MUD VOLUME TO PREPARE 1 m3 OF MUD WEIGHTED WITH BARITE Mud volume (Liters) required to prepare 1 m3 of mud weighted with barite. Desired s.g. Initial s.g. 1.00 1.05 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80 1.85 1.90 1.95 2.00 2.05 2.10 2.15 2.20

1.05

1.10

1.15

1.20

1.25

1.30

1.35

1.40

1.45

1.50

1.55

1.60

1.65

1.70

1.75

1.80

1.85

1.90

1.95

2.00

2.05

2.10

2.15

2.20

2.25

984

969 984

953 968 984

938 952 968 984

922 937 952 967 983

906 921 935 951 967 983

891 905 919 934 950 966 983

875 889 903 918 933 949 966 982

859 873 887 902 917 932 948 965 982

844 857 871 885 900 915 931 947 964 982

828 841 855 869 883 898 914 930 946 964 981

813 825 839 852 867 881 897 912 929 945 963 981

797 810 823 836 850 864 879 895 911 927 944 962 981

781 794 806 820 833 847 862 877 893 909 926 943 962 980

766 778 790 803 817 831 845 860 875 891 907 925 942 961 980

750 762 774 787 800 814 828 842 857 873 889 906 923 941 960 980

734 746 758 770 783 797 810 825 839 855 870 887 904 922 940 959 979

719 730 742 754 767 780 793 807 821 836 852 868 885 902 920 939 958 979

703 714 726 738 750 763 776 789 804 818 833 849 865 882 900 918 938 957 978

688 698 710 721 733 746 759 772 786 800 815 830 846 863 880 898 917 936 957 978

672 683 694 705 717 729 741 754 768 782 796 811 827 843 860 878 896 915 935 956 977

656 667 677 689 700 712 724 737 750 764 778 792 808 824 840 857 875 894 913 933 955 977

641 651 661 672 683 695 707 719 732 745 759 774 788 804 820 837 854 872 891 911 932 953 976

625 635 645 656 667 678 690 702 714 727 741 755 769 784 800 816 833 851 870 889 909 930 952 976

609 619 629 639 650 661 672 684 696 709 722 736 750 765 780 796 813 830 848 867 886 907 929 951 975

Vi = 1000⋅Vf⋅

Vi = initial volume (Liters) of s.g. d1 d2 = desired density (s.g.)

Issue 1: November 2004 Rev. 0

4.2 − d 2 4.2 − d1

Vf = final volume (Liters) of s.g. d2 (in the table Vf = 1000 L) d1 = initial density (s.g.)

Density Adjustment

Page 13

DENSITY REDUCTION WITH WATER Volume of water (Liters) to add to 1 m3 of mud. Desired s.g. Initial s.g. 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80 1.85 1.90 1.95 2.00 2.05 2.10 2.15 2.20 2.25 2.30

1.05

1.10

1.15

1.20

1.25

1.30

1.35

1.40

1.45

1.50

1.55

1.60

1.65

1.70

1.75

1.80

1.85

1.90

1.95

2.00

2.05

2.10

2.15

2.20

2.25

1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 22000 23000 24000 25000

500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000

333 667 1000 1333 1667 2000 2333 2667 3000 3333 3667 4000 4333 4667 5000 5333 5667 6000 6333 6667 7000 7333 7667

250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500

200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200

167 333 500 667 833 1000 1167 1333 1500 1667 1833 2000 2167 2333 2500 2667 2833 3000 3167 3333

143 286 429 571 714 857 1000 1143 1286 1429 1571 1714 1857 2000 2143 2286 2429 2571 2714

125 250 375 500 625 750 875 1000 1125 1250 1375 1500 1625 1750 1875 2000 2125 2250

111 222 333 444 556 667 778 889 1000 1111 1222 1333 1444 1556 1667 1778 1889

100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600

91 182 273 364 455 545 636 727 818 909 1000 1091 1182 1273 1364

83 167 250 333 417 500 583 667 750 833 917 1000 1083 1167

77 154 231 308 385 462 538 615 692 769 846 923 1000

71 143 214 286 357 429 500 571 643 714 786 857

67 133 200 267 333 400 467 533 600 667 733

63 125 188 250 313 375 437 500 562 625

59 118 176 235 294 353 412 471 529

56 111 167 222 278 333 389 444

53 105 158 211 263 316 368

50 100 150 200 250 300

48 95 143 190 238

45 91 136 182

43 87 130

42 83

40

V = 1000⋅

V = quantity of water (Liters) for 1 m3

Issue 1: November 2004 Rev. 0

d 2 − d1 d2 − 1

d2 = desired density (s.g.)

d1 = initial density (s.g.)

Density Adjustment

Page 14

DENSITY REDUCTION WITH DIESEL OIL Volume of diesel (Liters) to add to 1 m3 of mud. Initial s.g. Desired s.g. 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80 1.85 1.90 1.95 2.00 2.05 2.10 2.15 2.20 2.25 2.30

1.05

1.10

1.15

1.20

1.25

1.30

1.35

1.40

1.45

1.50

1.55

1.60

1.65

1.70

1.75

1.80

1.85

1.90

1.95

2.00

2.05

2.10

2.15

2.20

2.25

238 476 714 952 1190 1429 1667 1905 2143 2381 2619 2857 3095 3333 3571 3810 4048 4286 4524 4762 5000 5238 5476 5714 5952

192 385 577 769 962 1154 1346 1538 1731 1923 2115 2308 2500 2692 2885 3077 3269 3462 3654 3846 4038 4231 4423 4615

161 323 484 645 806 968 1129 1290 1452 1613 1774 1935 2097 2258 2419 2581 2742 2903 3065 3226 3387 3548 3710

139 278 417 556 694 833 972 1111 1250 1389 1528 1667 1806 1944 2083 2222 2361 2500 2639 2778 2917 3056

122 244 366 488 610 732 854 976 1098 1220 1341 1463 1585 1707 1829 1951 2073 2195 2317 2439 2561

109 217 326 435 543 652 761 870 978 1087 1196 1304 1413 1522 1630 1739 1848 1957 2065 2174

98 196 294 392 490 588 686 784 882 980 1078 1176 1275 1373 1471 1569 1667 1765 1863

89 179 268 357 446 536 625 714 804 893 982 1071 1161 1250 1339 1429 1518 1607

82 164 246 328 410 492 574 656 738 820 902 984 1066 1148 1230 1311 1393

76 152 227 303 379 455 530 606 682 758 833 909 985 1061 1136 1212

70 141 211 282 352 423 493 563 634 704 775 845 915 986 1056

66 132 197 263 329 395 461 526 592 658 724 789 855 921

62 123 185 247 309 370 432 494 556 617 679 741 802

58 116 174 233 291 349 407 465 523 581 640 698

55 110 165 220 275 330 385 440 495 549 604

52 104 156 208 260 313 365 417 469 521

50 99 149 198 248 297 347 396 446

47 94 142 189 236 283 330 377

45 90 135 180 225 270 315

43 86 129 172 216 259

41 83 124 165 207

40 79 119 159

38 76 115

37 74

35

V = 1000⋅

V = quantity of Diesel (Liters) for 1 m3

Issue 1: November 2004 Rev. 0

d 2 − d1 d 2 − 0.84

d2 = desired density (s.g.)

d1 = initial density (s.g.)

Density Adjustment

Page 15

DENSITY REDUCTION WITH LOW-TOXICITY OIL Volume of Low-toxicity oil (Liters) to add to 1 m3 of mud. Initial s.g. Desired s.g. 1.10 1.15 1.20 1.25 1.30 1.35 1.40 1.45 1.50 1.55 1.60 1.65 1.70 1.75 1.80 1.85 1.90 1.95 2.00 2.05 2.10 2.15 2.20 2.25 2.30

1.05

1.10

1.15

1.20

1.25

1.30

1.35

1.40

1.45

1.50

1.55

1.60

1.65

1.70

1.75

1.80

1.85

1.90

1.95

2.00

2.05

2.10

2.15

2.20

2.25

200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000

167 333 500 667 833 1000 1167 1333 1500 1667 1833 2000 2167 2333 2500 2667 2833 3000 3167 3333 3500 3667 3833 4000

143 286 429 571 714 857 1000 1143 1286 1429 1571 1714 1857 2000 2143 2286 2429 2571 2714 2857 3000 3143 3286

125 250 375 500 625 750 875 1000 1125 1250 1375 1500 1625 1750 1875 2000 2125 2250 2375 2500 2625 2750

111 222 333 444 556 667 778 889 1000 1111 1222 1333 1444 1556 1667 1778 1889 2000 2111 2222 2333

100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000

91 182 273 364 455 545 636 727 818 909 1000 1091 1182 1273 1364 1455 1545 1636 1727

83 167 250 333 417 500 583 667 750 833 917 1000 1083 1167 1250 1333 1417 1500

77 154 231 308 385 462 538 615 692 769 846 923 1000 1077 1154 1231 1308

71 143 214 286 357 429 500 571 643 714 786 857 929 1000 1071 1143

67 133 200 267 333 400 467 533 600 667 733 800 867 933 1000

63 125 188 250 313 375 438 500 563 625 687 750 812 875

59 118 176 235 294 353 412 471 529 588 647 706 765

56 111 167 222 278 333 389 444 500 556 611 667

53 105 158 211 263 316 368 421 474 526 579

50 100 150 200 250 300 350 400 450 500

48 95 143 190 238 286 333 381 429

45 91 136 182 227 273 318 364

43 87 130 174 217 261 304

42 83 125 167 208 250

40 80 120 160 200

38 77 115 154

37 74 111

36 71

34

V = 1000⋅

V = quantity of LT-oil (Liters) for 1 m3

Issue 1: November 2004 Rev. 0

d 2 − d1 d 2 − 0.80

d2 = desired density (s.g.)

d1 = initial density (s.g.)

Density Adjustment

Page 16

BRINE DILUTION To dilute brines, simply use the standard mass balance equation: Vi⋅di + V2⋅d2 = Vf⋅df Where: Vi = initial brine volume (m3) Vf = final brine volume (m3) = Vi + V2 V2 = diluent’s volume (m3)

di = initial brine density (g/cm3) df = desired (final) brine density (g/cm3) d2 = diluent’s density (g/cm3)

Example 1: 50 m3 of 1.35 s.g. brine must be diluted with water to 1.20 s.g. brine. Calculate the amount of water and the final volume. Vi = 50 m3 Vf = Vi + V2 = 50 + x V2 = water

di = 1.35 g/cm3 df = 1.20 g/cm3 d2 = 1.00 g/cm3

50⋅1.35 + V2⋅1.00 = 1.20⋅(50 + V2) V2 = 37.5 m3 (amount of water) V3 = 87.5 m3 (final volume)

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 17

WEIGHTING BRINE WITH THE SAME SALT To weight up brines, use the following method and the salt tables: 1. Find the amount of salt and water from the appropriate salt table for the initial brine density; 2. Find the amount of salt and water from the appropriate salt table for the desired brine density; 3. Determine the difference (missing) of salt necessary to reach the desired density; 4. Determine the difference (excess) of water necessary to reach the desired density; 5. Determine the quantity of salt necessary to reach the desired density. W1 = kg/m3 (ppg) of salt in the initial brine V1 = m3/m3 (gal/gal) of water in the initial brine 3 W2 = kg/m (ppg) of salt in the desired brine V2 = m3/m3 (gal/gal) of water in the desired brine X = W2 – W1 = kg/m3 (ppg) of missing salt Y = V2 – V1 = m3/m3 (gal/gal) of excess water 3 Z = Y⋅W2/V2 = kg/m (ppg) of salt necessary to weight up the excess of water

(from salt tables) (from salt tables)

Wf = X + Z Vf = Vi⋅F Wf = X + Z = kg/m3 (ppg) of salt necessary to add to reach the desired density F = volume factor = 1+ Y/V2 Vf = final volume = Vi⋅F

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 18

Example 1: 50 m3 of 1.20 sg CaCl2 brine must be weighted up to 1.34 sg. Calculate the amount of 95% CaCl2 needed (Wf) and the final volume. W1 = 278.3 kg/m3 of salt (in the 1.20 brine) W2 = 494.3 kg/m3 of salt (in the 1.34 brine)

V1 = 0.921 m3/m3 of water (in the 1.20 brine) V2 = 0.845 m3/m3 of water (in the 1.34 brine)

X = W2 – W1 = 216.0 kg/m3 of missing salt Z = Y⋅W2/V2 = 0.076⋅494.3/0.845 = 44.46 kg/m3 of salt Wf = 216.0 + 44.46 = 260.46 kg/m3 of CaCl2 ⇒ (260.46⋅50 = 13023 kg)

Y = V2 – V1 = 0.076 m3/m3 of excess water F = 1 + Y/V2 = 1 + 0.076/0.845 = 1.090 Vf = Vi⋅F = 50⋅1.090 = 54.5 m3

Note:

Total salt = 278.3 + 260.46 = 538.76 kg/m3 Total water = 0.921 m3/m3

(from salt tables. page 39) (from salt tables. page 39)

df = (538.76 + 921)/1.090 = 1.34 sg

Example 2: Prepare 200 m3 of 1.306 sg CaCl2 brine starting form 1.21 sg CaCl2 brine. Calculate the amount of 95% CaCl2 needed (Wf) and the initial volume required (Vi). W1 = 293.4 kg/m3 of salt (in the 1.21 brine) W2 = 440.6 kg/m3 of salt (in the 1.306 brine)

V1 = 0.917 m3/m3 of water (in the 1.21 brine) V2 = 0.867 m3/m3 of water (in the 1.306 brine)

X = 440.6 – 293.4 = 147.20 kg/m3 of missing salt Z = 0.050⋅440.6/0.867 = 25.41 kg/m3 of salt Wf = 147.20 + 25.41 = 172.61 kg/m3 of CaCl2 (172.61⋅189.03 = 32.63 ton)

Y = 0.917 – 0.867 = 0.050 m3/m3 of excess water F = 1 + 0.050/0.867 = 1.058 Vi= Vf/F = 200/1.058 = 189.03 m3

Issue 1: November 2004 Rev. 0

⇒

(from salt tables. page 39) (from salt tables. page 39)

Completion Fluids

Page 19

WEIGHTING BINARY BRINES WITH 1 OF THE 2 SALTS To weight up binary brines, use the following method and the salt tables: 1. Consider the binary brine as a single-salt brine; 2. Follow the same procedure of single-salt brine. For the following binary brines, consider the following salt only: • NaCl/CaCl2: use tables of CaCl2 • CaCl2/CaBr2: use tables of CaBr2 • CaBr2/ZnBr2: use tables of ZnBr2 Example 1: A 1.58 sg CaCl2/CaBr2 brine must be weighted up to 1.64 sg. Calculate the amount of 95% CaBr2 needed (Wf) and volume increase. W1 = 780.2 kg/m3 of salt (in the 1.58 brine) W2 = 863.3 kg/m3 of salt (in the 1.64 brine)

V1 = 0.7973 m3/m3 of water (in the 1.58 brine) V2 = 0.7740 m3/m3 of water (in the 1.64 brine)

X = W2 – W1 = 83.1 kg/m3 of missing salt Z = Y⋅W2/V2 = 25.99 kg/m3 of salt Wf = X + Z = 109.09 kg/m3 of CaBr2

Y = V2 – V1 = 0.0233 m3/m3 of excess water F = 1 + Y/V2 = 1.0301

Issue 1: November 2004 Rev. 0

(from CaBr2 tables. page 42) (from CaBr2 tables. page 42)

Completion Fluids

Page 20

WEIGHTING BINARY BRINES WITH BOTH SALTS To weight up binary brines, use the following method and the appropriate salt tables: 1. Determine the amount of each salt needed as for single-salt brine 2. Follow the same procedure of single-salt brine. This is the general procedure that covers all cases previously described. W1A, W1B = kg/m3 (ppg) of the 2 salts in the initial brine V1 = m3/m3 (gal/gal) of water in the initial brine (from salt tables) W2A, W2B = kg/m3 (ppg) of the 2 salts in the desired brine V2 = m3/m3 (gal/gal) of water in the desired brine (from salt tables) XA = W2A – W1A = kg/m3 (ppg) of missing “A” salt XB = W2B – W1B = kg/m3 (ppg) of missing “B” salt Y = V2 – V1 = m3/m3 (gal/gal) of excess water ZA = W2A⋅Y/V2 = kg/m3 (ppg) of “A” salt necessary to weight up the excess of water ZB = W2B⋅Y/V2 = kg/m3 (ppg) of “B” salt necessary to weight up the excess of water Wf.A = XA + ZA Wf.B = XB + ZB Vf = V1⋅F Wf.A = XA + ZA = kg/m3 (ppg) of “A” salt necessary to add to reach the desired density Wf.B = XB + ZB = kg/m3 (ppg) of “B” salt necessary to add to reach the desired density F = volume factor = 1+ Y/V2 Vf = final volume = V1⋅F

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 21

BRINE DENSITY TABLE It becomes more and more common to use low solids or completely solids-free systems to drill certain sections of a well. The main application of these systems is to drill the reservoir section where a minimized solid content provides exceptionally low formation damage. The density of those systems is not adjusted with solids, but instead with heavy brines and normally only a small amount of soluble solids (Calcium Carbonate or sized Salts) is added to build a thin filter cake for fluid loss control. BRINE CaBr2 CaBr2 / ZnBr2 CaCl2 CaCl2 / CaBr2 CaCl2 / CaBr2 / ZnBr2 CsCOOH KCl KCOOH NaBr NaCl NaCl / CaCl2 NaCOOH ZnBr2 – 56.7%

Issue 1: November 2004 Rev. 0

DENSITY RANGE (SG) (PPG) 1.70-1.80 14.2-15.0 1.71-2.30 14.3-19.2 1.01-1.39 8.4-11.6 1.33-1.81 11.1-15.1 1.80-2.30 15.0-19.2 2.340 19.5 1.01-1.16 8.4-9.7 1.560 13.0 1.01-1.52 8.4-12.7 1.01-1.20 8.4-10.0 1.21-1.33 10.1-11.1 1.340 11.2 2.300 19.2

CRYSTALLIZATION TEMP. (°C) (°F) -9/+18 +15/+65 -40/-5 -40/+23 -50/+10 -59/+50 -24/+20 -12/+68 -22/+18 -8/+18 -10/+16

+14/+60

-33/+17 -18/0 -41/-18

-28/+63 -1/+31 -42/0

Completion Fluids

Page 22

SALT KCl (Potassium Chloride) – 97% KBr (Potassium Bromide) – 98% NaCl (Sodium Chloride) – 98% NaBr (Sodium Bromide) – 95% NaCOOH (Sodium Formate) CaCl2 (Calcium Chloride) – 95% CaCl2 (Calcium Chloride) – 36% NaBr (Sodium Bromide) – 98% KCOOH (Potassium Formate) CaBr2 (Calcium Bromide) – 95% CaBr2 (Calcium Bromide) – 52% ZnBr2 (Zinc Bromide) – 56.7% CsCOOH (Cesium Formate)

Issue 1: November 2004 Rev. 0

FORM Powder Powder Powder Powder Liquid Powder Liquid Powder Powder Powder Liquid Liquid Powder

SPECIFIC GRAVITY 1.99 2.76 2.18 3.20 1.75 1.37

2.85 1.72 2.30

Completion Fluids

Page 23

BRINE CALCULATIONS 1. PURITY CONVERSION: This is useful as salt tables don’t cover all purity grades of salt available. To formulate brine with different purity salt, the following procedure can be adopted. 1. Convert the quantity for percentage reported in table to 100% purity; 2. Convert the 100% purity quantity to the quantity for purity available; 3. Determine the approximate quantity of water needed. Example 1: Formulate a 1.20 sg CaCl2 brine using 77% purity grade CaCl2. W1 = 278.3 kg/m3 of 95% CaCl2 (for 1.20 sg) V1 = 0.921 m3/m3 of water (for 1.20 sg)

(from salt table. page 39) (from salt table. page 39)

Convert to 100% purity: W2 = W1⋅0.95 = 278.3⋅0.95 = 264.38 kg/m3 of 100% CaCl2 Convert to 77% purity: W3 = W2/0.77 = 264.38/0.77 = 343.35 kg/m3 of 77% CaCl2 Difference in water volume (approximate): V2 ≈ 343.45 – 264.38 = 78.97 Liters (0.078 m3) Volume of water needed = V3 = V1 – V2 = 0.921 – 0.078 = 0.843 m3/m3 So 1.20 sg brine will be formulated with: 343.35 kg/m3 of 77% CaCl2 and 0.843 m3/m3 of water.

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 24

2. SALTS DETERMINATION: To determine salt composition when brine must be diluted. 1. Find the actual brine composition (from salt tables); 2. Determine volume factor from brine dilution formula; 3. Calculate the new brine composition. W1A = kg/m3 of “A” salt in the initial brine W1B = kg/m3 of “B” salt in the initial brine V1 = m3/m3 of water in the initial brine (from salt table) Volume of water needed = Vw = Where:

d1 = initial density

d2 = final density

d1 − d 2 d2 − dw

dw = water (diluent) density

F = 1 + Vw W2A = W1A/F W2B = W1B/F V2 = (V1 + Vw)/F F = Volume factor W2A = kg/m3 of “A” salt in the final brine W2B = kg/m3 of “A” salt in the final brine V2 = m3/m3 of water in the final brine

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 25

3. COMPOSITION DETERMINATION: To determine salt percentage in a brine. % Salt =

C⋅% d

C = salt concentration (kg/m3 or ppb) D = brine density (kg/m3 or ppb) % = salt purity (%) Example 1: A 1.80 sg brine contains 57 kg/m3 of 95% CaCl2. Calculate the % CaCl2. % CaCl2 (95% purity) = (57⋅95)/1800 = 3.0% Example 2: A 1.86 sg brine contains 0.25 m3 of a 2.30 sg ZnBr2 brine (composition: 56.7% ZnBr2 + 19.7% CaBr2). Calculate the % ZnBr2. % ZnBr2 = (0.25⋅56.7⋅2.3)/1860 = 17.5%

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 26

4. ION DETERMINATION: To determine ion composition in a brine. Ion composition depends on molecular weights ratio and molecular formula of salt. Percentages are w/w%. A. CaCl2 brine: % Ca+2 = % Cl- =

MWCa MWCaCl2 2 ⋅ MWCl MWCaCl2

⋅%CaCl2

% Ca+2 = 0.3611⋅%CaCl2

⋅%CaCl2

% Cl- = 0.6389⋅%CaCl2

⋅%CaBr2

% Ca+2 = 0.2005⋅%CaBr2

⋅%CaBr2

% Br- = 0.7995⋅%CaBr2

B. CaBr2 brine: % Ca+2 = % Br- =

MWCa MWCaBr2 2 ⋅ MW Br MWCaBr2

C. ZnBr2 brine: % Zn+2 = % Br- =

Issue 1: November 2004 Rev. 0

MW Zn MWZnBr2 2 ⋅ MWBr MWZnBr2

⋅%ZnBr2 ⋅%ZnBr2

% Zn+2 = 0.3611⋅%ZnBr2 % Br- = 0.6389⋅%ZnBr2

Completion Fluids

Page 27

D. NaCl brine: % Na+ =

MW Na MW NaCl

⋅%NaCl

% Na+ = 0.3932⋅%NaCl

% Cl- =

MWCl MW NaCl

⋅%NaCl

% Cl- = 0.6066⋅%NaCl

% Na+ =

MW K MWKCl

⋅%KCl

% Na+ = 0.5245⋅%KCl

% Cl- =

MWCl MWKCl

⋅%KCl

% Cl- = 0.4755⋅%KCl

E. KCl brine:

Note: w/w % can be easily converted in ppm or in mg/L by the following formulas: ppm = 10000⋅% w/w mg/L = ppm⋅d d = brine density (sg)

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 28

Example 1: Calculate Ca+2 and Cl- percentages in brine containing 4.18% CaCl2. % Ca+2 = 4.18⋅0.3611 = 1.51% % Cl- = 4.18⋅0.6389 = 2.67%

Example 2: Calculate Br- percentage in 2.30 sg brine (composition: 56.7% ZnBr2 + 19.7% CaBr2). % Br- = % Br- (from CaBr2) + % Br- (from ZnBr2) % Br- = 19.7⋅0.7995 + 56.7⋅0.7097 = 55.99%

Note: Ion analysis can be easily converted into brine composition. % CaCl2 = 1.565⋅%Cl% ZnBr2 = 3.444⋅%Zn+2 % CaBr2 = 4.987⋅(%Ca+2 – 0.565⋅%Cl-)

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 29

TEMPERATURE CORRECTION FACTORS Brine densities are usually given with reference to a specific temperature; the standard used is with reference to 15.6 °C. As the temperature changes, so does the volume. This will cause a density variation. Brine Fresh water NaCl CaCl2 CaBr2 / CaCl2 CaBr2 ZnBr2 / CaBr2 ZnBr2 / CaBr2 / CaCl2

Issue 1: November 2004 Rev. 0

Density range sg 1.00 1.08 – 1.23 1.02 – 1.07 1.08 – 1.19 1.20 – 1.37 1.40 – 1.57 1.58 – 1.80 1.70 – 1.80 2.30 1.85 – 2.05 2.06 – 2.14 > 2.15

ppg 8.34 9.0 – 10.2 8.5 – 8.9 9.0 – 9.9 10.0 – 11.4 11.6 – 13.0 13.2 – 15.0 14.2 – 15.0 19.2 15.4 – 17.0 17.2 – 17.8 > 18

Per 1°F⋅10-4 TCFe

Per 1°C⋅10-4 TCFm

4.7 2.5 3.8 3.1 2.45 2.55 2.45 2.3 2.5 2.3 2.4 2.6

8.46 4.50 6.84 5.58 4.40 4.59 4.40 4.14 4.50 4.14 4.32 4.68

Completion Fluids

Page 30

1. Brine density correction factor at surface: SG (T0) = SG (T)⋅[1 + (T – T0)⋅TCFm] ppg (T0) = ppg (T)⋅[1 + (T – T0)⋅TCFe] Where: T0 = 15.6 °C (60 °F) or initial temperature

T = different temperature (°C or °F)

Example 1: CaCl2 brine density is 1.285 sg @ 45°C. Calculate the density @ 15.6 °C. sg (T0) = sg (T)⋅[1 + (T – T0)⋅TCFm] sg (15.6) = 1.285⋅[1 + (45 – 15.6)⋅4.4⋅10-4] = 1.3016 sg T0 = 15.6 °C

Issue 1: November 2004 Rev. 0

T = 45 °C

Completion Fluids

Page 31

2. Brine density correction in hole: The density for brine at in hole can be determined from the following formulas: Tavg = Tavg =

BHST + ST 2

BHCT + SCT 2

Where: BHST = bottom hole static temperature (°C or °F) Tavg = average temperature (°C or °F) SCT = surface circulating temperature (°C or °F)

under static conditions under circulating conditions

BHCT = bottom hole circulating temperature (°C or °F) ST = surface temperature (°C or °F)

Example 2: CaBr2 brine of 1.72 sg is required to control the formation pressure. BHST is 72 °C and surface temperature is 10 °C. Calculate density of CaBr2 required at 15.6 °C to have an average density in the well of 1.72 sg. Tavg =

72 + 10 2

sg (T0) =

= 41 °C

sg (T ) 1 − (Tavg − T0 ) ⋅ TCFm

sg (15.6) =

1.72 1 − (41 − 15.6) ⋅ 4.14 ⋅ 10 −4

Issue 1: November 2004 Rev. 0

= 1.738 sg

Completion Fluids

Page 32

VOLUME EXPANSION CORRECTION To determine volume expansion, use factors given in previous table and the following formula: ∆V = TCF⋅Tavg⋅V Where: ∆V = volume expansion (m3) TCF = temperature correction factor (°C or °F)

V = initial volume (m3) Tavg = average temperature (°C or °F)

Example 1: Calculate volume expansion for a well with 100 m3 of aCaCl2 brine @ 1.37 s.g. with BHT = 130 °C and surface temperature = 10 °C. Tavg =

130 + 10 2

= 70 °C

∆V = 4.4⋅10-4⋅70⋅100 = 3.08 m3

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 33

PROPERTIES OF SODIUM CHLORIDE SOLUTIONS (NaCl, Salt) %w

ppm

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26

10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 210000 220000 230000 240000 250000 260000

International units KCl Water SG kg/m3 Lt/m3 1.007 10.0 997 1.014 20.3 994 1.021 30.6 991 1.029 41.1 987 1.036 52.0 984 1.043 62.6 979 1.050 73.7 977 1.058 84.9 973 1.065 96.0 969 1.073 107.4 965 1.080 118.9 961 1.088 130.6 957 1.095 142.6 952 1.103 154.6 949 1.111 166.9 944 1.118 179.1 939 1.126 191.7 934 1.134 204.3 929 1.142 217.1 925 1.150 230.3 920 1.158 243.4 915 1.166 256.9 910 1.174 270.3 904 1.183 284.3 899 1.191 298.3 893 1.199 312.3 887

PPG 8.40 8.46 8.52 8.59 8.65 8.70 8.76 8.83 8.89 8.95 9.01 9.08 9.14 9.20 9.27 9.33 9.40 9.46 9.53 9.60 9.66 9.73 9.80 9.87 9.94 10.01

British units NaCl Water ppb gal/bbl 3.5 41.9 7.1 41.8 10.7 41.6 14.4 41.5 18.2 41.3 21.9 41.1 25.8 41.0 29.7 40.9 33.6 40.7 37.6 40.5 41.6 40.4 45.7 40.2 49.9 40.0 54.1 39.9 58.4 39.7 62.7 39.4 67.1 39.3 71.5 39.0 76.0 38.9 80.6 38.6 85.2 38.4 89.9 38.2 94.6 38.0 99.5 37.7 104.4 37.5 109.3 37.3

Ion composition mg/L mg/L NaCl Cl10070 6106 20280 12297 30630 18573 41160 24958 51800 31410 62580 37946 73500 44568 84640 51323 95850 58120 107300 65063 118800 72036 130560 79167 142350 86316 154420 93635 166650 101051 178880 108467 191420 116071 204120 123772 216980 131569 230000 139464 243180 147456 256520 155545 270020 163731 283920 172160 297750 180546 311740 189029

Cryst. Temp. (°C)

F factor

Aw

-0.5 -1.0 -2.0 -2.5 -3.0 -3.5 -4.5 -5.0 -6.0 -6.5 -7.5 -8.0 -9.0 -10.0 -11.0 -12.0 -13.0 -14.0 -15.0 -16.0 -18.0 -19.0 -21.0 -11.5 -9.5 -4.0

1.003 1.006 1.010 1.012 1.016 1.020 1.024 1.027 1.032 1.036 1.040 1.044 1.050 1.054 1.059 1.065 1.070 1.075 1.081 1.087 1.093 1.100 1.106 1.112 1.120 1.127

0.996 0.989 0.983 0.976 0.970 0.964 0.957 0.950 0.943 0.935 0.927 0.919 0.910 0.901 0.892 0.882 0.872 0.861 0.850 0.839 0.827 0.815 0.802 0.788 0.774 0.759

Properties based @ 20.0°C and 99% purity

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 34

PROPERTIES OF POTASSIUM CHLORIDE SOLUTIONS (KCl) %w

ppm

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 210000 220000 230000 240000

International units KCl Water SG kg/m3 Lt/m3 1.005 10.0 995 1.011 20.3 990 1.017 30.6 986 1.024 41.1 983 1.030 51.7 979 1.037 62.3 974 1.044 73.1 969 1.050 84.0 964 1.057 95.1 962 1.063 106.6 957 1.070 117.7 952 1.077 129.4 948 1.084 141.1 943 1.091 152.9 938 1.097 164.6 931 1.104 176.9 926 1.111 188.9 921 1.119 201.4 917 1.126 214.0 912 1.131 226.6 905 1.140 239.7 900 1.147 252.6 895 1.155 266.0 890 1.162 279.1 883

PPG 8.39 8.44 8.49 8.55 8.60 8.65 8.71 8.76 8.82 8.87 8.93 8.99 9.05 9.10 9.15 9.21 9.27 9.34 9.40 9.44 9.51 9.57 9.64 9.70

British units KCl Water ppb gal/bbl 3.5 41.8 7.1 41.6 10.7 41.4 14.4 41.3 18.1 41.1 21.8 40.9 25.6 40.7 29.4 40.5 33.3 40.4 37.3 40.2 41.2 40.0 45.3 39.8 49.4 39.6 53.5 39.4 57.6 39.1 61.9 38.9 66.1 38.7 70.5 38.5 74.9 38.3 79.3 38.0 83.9 37.8 88.4 37.6 93.1 37.4 97.7 37.1

Ion composition mg/L mg/L mg/L KCl K+ Cl10050 5271 4776 20220 10605 9610 30510 16002 14500 40960 21483 19466 51500 27011 24475 62220 32633 29570 73080 38329 34731 84000 44056 39921 95130 49894 45211 106300 55752 50519 117700 61731 55937 129240 67784 61422 140920 73910 66972 152740 80109 72590 164550 86303 78203 176640 92644 83948 188870 99059 89761 201420 105641 95725 213940 112207 101675 226200 118637 107502 239400 125561 113775 252340 132347 119925 265650 139328 126251 278880 146267 132538

Cryst. Temp. F factor (°C) -0.5 -1.0 -1.5 -2.0 -2.5 -3.0 -3.5 -4.0 -4.5 -5.0 -5.5 -6.0 -6.5 -7.0 -7.5 -8.5 -9.0 -9.5 -10.0 -10.5 -5.5 1.0 9.0 15.0

1.005 1.009 1.014 1.017 1.022 1.026 1.030 1.035 1.040 1.045 1.050 1.055 1.060 1.066 1.072 1.078 1.084 1.090 1.096 1.105 1.110 1.118 1.124 1.132

Properties based @ 20°C and 97% purity

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 35

PROPERTIES OF POTASSIUM BROMIDE SOLUTIONS (KBr) %w

ppm

4.2 6.0 7.6 9.3 10.8 12.3 13.6 15.0 16.4 17.7 19.0 20.2 21.5 22.8 24.0 25.2 26.3 27.5 28.7 29.8 30.9 32.0 33.2 34.3 35.2 36.3 37.3 38.3 39.3 40.2

42000 60000 76000 93000 108000 123000 136000 150000 164000 177000 190000 202000 215000 228000 240000 252000 263000 275000 287000 298000 309000 320000 332000 343000 352000 363000 373000 383000 393000 402000

International units KBr Water SG kg/m3 Lt/m3 1.03 5.3 985 1.04 7.7 980 1.05 9.8 974 1.07 12.2 967 1.08 14.3 962 1.09 16.5 956 1.10 18.4 954 1.11 20.5 947 1.13 22.6 942 1.14 24.7 937 1.15 26.8 932 1.16 28.8 928 1.17 31.0 922 1.19 33.2 916 1.20 35.3 911 1.21 37.4 905 1.22 39.4 901 1.23 41.7 895 1.25 43.9 888 1.26 46.0 883 1.27 48.2 878 1.28 50.3 872 1.29 52.7 865 1.31 55.0 858 1.32 56.9 854 1.33 59.2 847 1.34 61.4 842 1.35 63.4 835 1.37 65.9 829 1.38 68.0 824

PPG 8.6 8.7 8.8 8.9 9.0 9.1 9.2 9.3 9.4 9.5 9.6 9.7 9.8 9.9 10.0 10.1 10.2 10.3 10.4 10.5 10.6 10.7 10.8 10.9 11.0 11.1 11.2 11.3 11.4 11.5

British units KBr Water ppb bbl/bbl 15.1 985 21.9 980 28.1 974 34.8 967 40.8 962 47.0 956 52.6 954 58.6 947 64.7 942 70.6 937 76.6 932 82.3 928 88.5 922 94.8 916 100.8 911 106.9 905 112.7 901 119.0 895 125.4 888 131.4 883 137.6 878 143.8 872 150.6 865 157.0 858 162.6 854 169.2 847 175.5 842 181.2 835 188.2 829 194.2 824

mg/L KBr 43283 62552 80144 99185 116477 134128 149934 167166 184733 201498 218574 234799 252487 270485 287597 304997 321462 339425 357675 374955 392499 410306 429670 448017 463990 482840 500611 518622 536872 553984

Ion composition mg/L mg/L K+ Br9668 33615 13972 48580 17901 62242 22155 77030 26017 90460 29960 104168 33490 116444 37339 129827 41263 143470 45008 156490 48822 169752 52446 182353 56397 196089 60418 210068 64240 223358 68126 236871 71804 249658 75816 263608 79893 277782 83753 291202 87671 304827 91649 318657 95974 333696 100072 347945 103640 360350 107851 374989 111820 388791 115843 402779 119920 416953 123742 430243

Cryst. Temp. (°C)

F factor

-1.0 -1.0 -1.5 -2.0 -3.0 -3.0 -3.5 -3.5 -4.0 -4.5 -5.0 -5.5 -5.5 -6.0 -7.0 -8.0 -8.5 -9.0 -9.5 -10.0 -11.0 -10.5 -6.5 -3.0 0.5 5.0 9.5 14.0 19.0 24.0

1.013 1.020 1.026 1.034 1.039 1.046 1.050 1.056 1.062 1.067 1.073 1.078 1.085 1.092 1.098 1.105 1.110 1.118 1.125 1.132 1.139 1.147 1.157 1.165 1.171 1.180 1.188 1.197 1.206 1.213

Properties based @ 20.0 °C and 98% purity Issue 1: November 2004 Rev. 0

Completion Fluids

Page 36

PROPERTIES

OF

%w

ppm

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 22 24 26 28 30 32 34 36 38 40

10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 220000 240000 260000 280000 300000 320000 340000 360000 380000 400000

POTASSIUM International units K2CO3 Water SG kg/m3 Lt/m3 1.009 10.1 997 1.017 20.3 996 1.027 30.8 994 1.035 41.4 993 1.045 52.2 991 1.055 63.2 990 1.063 74.3 988 1.072 85.7 986 1.082 97.3 983 1.092 109.0 981 1.101 121.0 979 1.111 133.2 976 1.120 145.5 974 1.130 158.1 971 1.141 170.9 969 1.150 183.8 964 1.160 197.0 962 1.171 210.5 959 1.180 224.1 955 1.191 238.0 952 1.212 266.3 945 1.233 295.7 936 1.255 325.9 929 1.277 357.1 919 1.299 389.4 909 1.322 422.6 898 1.345 456.8 886 1.368 492.0 874 1.392 528.3 862 1.415 565.6 848

CARBONATE

PPG 8.42 8.49 8.57 8.64 8.72 8.80 8.87 8.95 9.03 9.11 9.19 9.27 9.35 9.43 9.52 9.60 9.68 9.77 9.85 9.94 10.11 10.29 10.47 10.66 10.84 11.03 11.22 11.42 11.62 11.81

British units K2CO3 Water ppb bbl/bbl 3.5 41.9 7.1 41.8 10.8 41.8 14.5 41.7 18.3 41.6 22.1 41.6 26.0 41.5 30.0 41.4 34.1 41.3 38.2 41.2 42.4 41.1 46.6 41.0 50.9 40.9 55.3 40.8 59.8 40.7 64.3 40.5 69.0 40.4 73.7 40.3 78.4 40.1 83.3 40.0 93.2 39.7 103.5 39.3 114.1 39.0 125.0 38.6 136.3 38.2 147.9 37.7 159.9 37.2 172.2 36.7 184.9 36.2 198.0 35.6

SOLUTIONS

(K

2

CO

3

)

Ion composition mg/L mg/L mg/L K2CO3 K+ CO3-2 10089.87 5709 4380 20347.51 11513 8833 30808.87 17432 13375 41414.02 23432 17979 52246.85 29562 22682 63271.42 35799 27468 74403.83 42098 32300 85799.88 48546 37248 97387.66 55102 42278 109167.2 61767 47392 121138.4 68541 52589 133301.4 75423 57869 145656.1 82413 63233 158202.5 89512 68679 171120.4 96821 74287 184062.3 104143 79905 197195.9 111575 85607 210737 119236 91486 224266 126891 97359 238226.5 134790 103419 266530.9 150805 115707 295937.7 167443 128473 326207.3 184570 141614 357675.3 202375 155275 389694.4 220491 169175 422959.9 239313 183616 457136 258650 198453 492654.3 278747 213872 529131.2 299385 229707 566087.5 320295 245751

Properties based @ 20.0 °C and 99% purity Issue 1: November 2004 Rev. 0

Completion Fluids

Page 37

PROPERTIES OF SODIUM BROMIDE SOLUTIONS (NaBr) %w

ppm

0.8 2.2 3.8 5.2 6.7 8.2 9.7 11.0 12.4 13.8 15.1 16.5 17.7 18.9 20.1 21.3 22.5 23.6 24.8 25.8 26.8 27.9 29.0 30.0 31.0 31.9 32.9 33.8 34.8 35.7 36.6

8000 22000 37800 52000 67000 82000 96500 110000 124000 137500 151000 164500 176500 189300 201000 212500 225000 236000 247500 257500 268000 278500 289500 299500 309500 319000 328500 338000 347500 357000 366000

Issue 1: November 2004 Rev. 0

International units NaBr Water SG kg/m3 Lt/m3 1.01 0.7 999 1.02 2.7 996 1.03 4.8 992 1.04 6.7 989 1.05 8.8 984 1.07 10.9 979 1.08 12.8 975 1.09 14.9 970 1.10 16.9 966 1.11 19.0 961 1.13 21.1 956 1.14 23.2 950 1.15 25.2 946 1.16 27.3 941 1.17 29.3 937 1.19 31.2 933 1.20 33.4 927 1.21 35.4 923 1.22 37.5 918 1.23 39.4 914 1.25 41.4 910 1.26 43.4 905 1.27 45.6 900 1.28 47.6 895 1.29 49.6 891 1.31 51.7 886 1.32 53.7 882 1.33 55.7 877 1.34 57.8 872 1.35 59.9 867 1.37 62.0 862

PPG 8.4 8.5 8.6 8.7 8.8 8.9 9.0 9.1 9.2 9.3 9.4 9.5 9.6 9.7 9.8 9.9 10.0 10.1 10.2 10.3 10.4 10.5 10.6 10.7 10.8 10.9 11.0 11.1 11.2 11.3 11.4

British units NaBr Water ppb bbl/bbl 2.1 999 7.6 996 13.7 992 19.2 989 25.0 984 31.0 979 36.7 975 42.6 970 48.3 966 54.2 961 60.2 956 66.4 950 72.0 946 77.9 941 83.6 937 89.2 933 95.4 927 101.1 923 107.1 918 112.6 914 118.2 910 124.1 905 130.2 900 136.0 895 141.7 891 147.6 886 153.3 882 159.2 877 165.1 872 171.1 867 177.0 862

mg/L NaBr 8053 22409 38955 54212 70653 87454 104074 119952 136705 153235 170090 187268 203044 220037 236046 252097 269623 285632 302516 317825 333996 350419 367729 384020 400551 416669 433014 449587 466387 483415 499988

Ion composition mg/L mg/L Na+ Br1012 3518 2816 9790 4895 17019 6812 23685 8878 30868 10989 38208 13078 45470 15073 52407 17178 59726 19255 66948 21373 74312 23531 81817 25514 88710 27649 96134 29661 103128 31678 110141 33880 117798 35891 124792 38013 132169 39937 138857 41969 145923 44032 153098 46207 160660 48255 167778 50332 175000 52357 182042 54411 189183 56493 196424 58604 203764 60744 211203 62827 218444

Cryst. Temp. (°C)

F factor

ND ND ND ND ND ND -7.2 -9.0 -10.8 -12.6 -14.4 -16.2 -23.4 -25.2 -27.0 -28.8 -30.6 -34.2 -36.0 -37.8 -39.6 -41.4 -46.8 -52.2 -53.8 -61.2 -66.6 -68.4 -72.0 -75.6 -79.2

1.001 1.004 1.008 1.012 1.016 1.021 1.026 1.030 1.035 1.040 1.046 1.051 1.056 1.061 1.066 1.070 1.077 1.081 1.087 1.091 1.096 1.102 1.108 1.113 1.119 1.124 1.130 1.136 1.142 1.149 1.155 Completion Fluids

Page 38

%w

ppm

37.6 38.4 39.3 40.0 40.8 41.7 42.4 43.2 43.8 44.7 45.4 46.2 46.8

375500 383500 392500 400000 408000 416500 423500 432000 438000 447000 454000 461500 468000

International units NaBr Water SG kg/m3 Lt/m3 1.38 64.1 857 1.39 66.0 853 1.40 68.2 847 1.41 70.1 844 1.43 72.1 839 1.44 74.2 834 1.45 76.1 831 1.46 78.3 825 1.47 80.0 823 1.49 82.3 816 1.50 84.2 812 1.51 86.3 807 1.52 88.2 804

PPG 11.5 11.6 11.7 11.8 11.9 12.0 12.1 12.2 12.3 12.4 12.5 12.6 12.7

British units NaBr Water ppb bbl/bbl 183.0 857 188.6 853 194.8 847 200.2 844 206.0 839 212.0 834 217.3 831 223.6 825 228.5 823 235.1 816 240.7 812 246.7 807 252.0 804

mg/L NaBr 517466 533086 550300 565608 581809 598922 614062 631564 645584 664206 680048 696812 712235

Ion composition mg/L mg/L Na+ Br65023 226080 66986 232904 69149 240425 71072 247113 73108 254192 75258 261668 77161 268283 79360 275929 81122 282055 83462 290191 85452 297112 87559 304436 89497 311174

Cryst. Temp. (°C)

F factor

-82.8 -86.4 -91.8 -95.4 -81.0 -21.1 -15.0 -12.2 -9.0 -2.9 ND ND ND

1.162 1.167 1.174 1.179 1.185 1.192 1.196 1.204 1.207 1.217 1.223 1.230 1.235

Properties based @ 20.0 °C and 95% purity

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 39

PROPERTIES OF POTASSIUM SULFATE SOLUTIONS (K Composition for 1m3 K2SO4 %w SG (kg/m3) 1.0 1008 10.0 1.5 1012 15.1 2.0 1016 20.2 2.5 1020 25.4 3.0 1024 30.5 3.5 1028 36.0 4.0 1032 41.5 4.5 1037 46.5 5.0 1041 52.0 5.5 1045 57.3 6.0 1049 62.7 6.5 1053 68.1 7.0 1057 73.8 7.5 1061 79.2 8.0 1066 84.9 8.5 1070 90.6 9.0 1074 96.3 9.5 1078 102.0 10.0 1083 107.8

Ion composition K+ SO4-2 (mg/L) (mg/L) 4532 5568 6821 8379 9110 11190 11443 14057 13776 16924 16110 19790 18488 22712 20911 25689 23920 28610 25758 31642 28181 34619 30649 37651 33162 40738 35675 43825 381888 46912 40746 50054 43304 53196 45907 56393 48509 59591

F Factor

TCT (°C)

1.004 1.005 1.006 1.007 1.008 1.009 1.011 1.012 1.013 1.014 1.016 1.017 1.019 1.020 1.021 1.023 1.024 1.026 1.027

-0.28 -0.06 -0.05 -0.06 -0.06 -0.11 -0.11 -1.06 -1.17 N/D N/D N/D N/D N/D N/D N/D N/D N/D N/D

2

SO

4

)

Properties based @ 20°C and 100% purity

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 40

PROPERTIES OF CALCIUM CHLORIDE SOLUTIONS (CaCl A . %w

ppm

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29

10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 210000 220000 230000 240000 250000 260000 270000 280000 290000

Issue 1: November 2004 Rev. 0

International units CaCl2 Water SG kg/m3 Lt/m3 1.009 10.6 998 1.017 21.4 995 1.026 32.4 993 1.034 43.7 990 1.043 54.9 988 1.051 66.6 984 1.060 78.3 981 1.068 90.0 979 1.077 102.0 974 1.085 114.3 971 1.094 126.9 967 1.103 139.4 964 1.113 152.6 959 1.122 165.6 957 1.132 178.9 952 1.141 192.4 949 1.151 206.3 945 1.160 220.0 940 1.170 234.3 936 1.180 248.9 931 1.190 263.4 926 1.200 278.3 921 1.210 293.4 917 1.220 308.6 912 1.231 324.3 907 1.241 340.1 902 1.252 356.3 895 1.262 372.6 890 1.273 389.1 883

9 5 %

PPG 8.42 8.49 8.56 8.63 8.70 8.77 8.85 8.91 8.99 9.05 9.13 9.20 9.29 9.36 9.45 9.52 9.61 9.68 9.76 9.85 9.93 10.01 10.10 10.18 10.27 10.36 10.45 10.53 10.62

C a l c i u m

British units CaCl2 Water ppb gal/bbl 3.7 41.9 7.5 41.8 11.4 41.7 15.3 41.6 19.2 41.5 23.3 41.4 27.4 41.2 31.5 41.1 35.7 40.9 40.0 40.8 44.4 40.6 48.8 40.5 53.4 40.3 58.0 40.2 62.6 40.0 67.4 39.9 72.2 39.7 77.0 39.5 82.0 39.3 87.1 39.1 92.2 38.9 97.4 38.7 102.7 38.5 108.0 38.3 113.5 38.1 119.1 37.9 124.7 37.6 130.4 37.4 136.2 37.1

2

)

C h l o r i d e Ion composition mg/L mg/L mg/L CaCl2 Ca+2 Cl10090 3644 6446 20340 7346 12994 30780 11116 19664 41360 14937 26423 52150 18834 33316 63060 22774 40286 74200 26797 47403 85440 30856 54584 96930 35006 61924 108500 39184 69316 120340 43460 76880 132360 47801 84559 144690 52254 92436 157080 56729 100351 169800 61323 108477 182560 65931 116629 195670 70665 125005 208800 75407 133393 222300 80283 142017 236000 85230 150770 249900 90250 159650 264000 95343 168657 278300 100507 177793 292800 105744 187056 307750 111143 196607 322660 116527 206133 338040 122082 215958 353360 127615 225745 369170 133324 235846

Cryst. Temp. (°C)

F factor

Aw

-0.5 -1.0 -1.5 -2.0 -2.5 -3.0 -3.5 -4.0 -4.5 -5.5 -6.0 -7.0 -8.0 -9.0 -10.5 -11.5 -13.0 -14.5 -16.0 -18.0 -20.0 -22.0 -24.5 -27.0 -29.5 -32.0 -35.0 -39.0 -45.0

1.001 1.003 1.005 1.007 1.009 1.012 1.014 1.018 1.020 1.024 1.027 1.030 1.033 1.036 1.039 1.043 1.047 1.051 1.055 1.059 1.064 1.068 1.073 1.079 1.083 1.089 1.094 1.101 1.106

0.998 0.996 0.993 0.989 0.984 0.979 0.973 0.967 0.959 0.951 0.942 0.933 0.923 0.912 0.900 0.888 0.875 0.862 0.847 0.832 0.816 0.800 0.783 0.765 0.746 0.727 0.707 0.686 0.665 Completion Fluids

Page 41

%w

ppm

30 31 32 33 34 35 36 37 38 39 40

300000 310000 320000 330000 340000 350000 360000 370000 380000 390000 400000

International units CaCl2 Water SG kg/m3 Lt/m3 1.284 406.0 879 1.295 423.1 871 1.306 440.6 867 1.317 458.0 859 1.328 476.0 852 1.340 494.3 845 1.351 512.6 838 1.363 531.7 832 1.375 550.9 825 1.387 570.0 817 1.398 589.4 809

PPG 10.71 10.81 10.90 10.99 11.08 11.18 11.27 11.37 11.47 11.57 11.67

British units CaCl2 Water ppb gal/bbl 142.1 36.9 148.1 36.6 154.2 36.4 160.3 36.1 166.6 35.8 173.0 35.5 179.4 35.2 186.1 35.0 192.8 34.7 199.5 34.3 206.3 34.0

Ion composition mg/L mg/L mg/L CaCl2 Ca+2 Cl385200 139113 246087 401450 144982 256468 417920 150930 266990 434610 156958 277652 451520 163065 288455 469000 169378 299622 486360 175647 310713 504310 182130 322180 522500 188699 333801 540930 195355 345575 559200 201953 357247

Cryst. Temp. (°C)

F factor

Aw

-46.0 -36.0 -28.5 -21.5 -15.5 -10.0 -4.5 1.0 5.5 10.0 13.5

1.113 1.119 1.126 1.133 1.141 1.148 1.157 1.165 1.173 1.182 1.192

0.643 0.620 0.597 0.573 0.548 0.522 0.496 0.469 0.441 0.413 0.384

Properties based @ 20.0 °C and 95% purity.

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 42

B .

%w

ppm

1 3 7 9 11 14 16 19 21 23 26 28 30 32 34 36 38

10000 30000 70000 90000 110000 140000 160000 190000 210000 230000 260000 280000 300000 320000 340000 360000 380000

7 7 %

International units CaCl2 Water SG 3 kg/m Lt/m3 1.007 11.4 995 1.030 45.7 983 1.055 85.6 967 1.079 122.7 950 1.103 162.6 933 1.127 205.4 914 1.151 245.4 895 1.175 285.3 879 1.199 331.0 855 1.223 373.8 833 1.247 416.6 817 1.271 456.5 795 1.295 499.3 779 1.319 542.1 755 1.343 587.8 729 1.367 633.4 709 1.391 676.2 688

C a l c i u m

PPG 8.40 8.60 8.80 9.00 9.20 9.40 9.61 9.81 10.01 10.21 10.41 10.61 10.81 11.01 11.21 11.41 11.61

C h l o r i d e

British units CaCl2 ppb 4.0 16.0 30.0 42.9 56.9 71.9 85.9 99.9 115.8 130.8 145.8 159.8 174.8 189.7 205.7 221.7 236.7

Water gal/bbl 41.8 41.3 40.6 39.9 39.2 38.4 37.6 36.9 35.9 35.0 34.3 33.4 32.7 31.7 30.6 29.8 28.9

Ion composition mg/L mg/L mg/L +2 CaCl2 Ca Cl10070 3637 6433 30900 11159 19741 73850 26671 47179 97110 35071 62039 121330 43818 77512 157780 56982 100798 184160 66509 117651 223250 80626 142624 251790 90933 160857 281290 101587 179703 324220 117091 207129 355880 128525 227355 388500 140305 248195 422080 152433 269647 456620 164907 291713 492120 177727 314393 528580 190895 337685

F 1.003 1.001 1.019 1.018 1.019 1.032 1.034 1.051 1.056 1.062 1.084 1.093 1.103 1.115 1.128 1.143 1.160

Properties based @ 20.0 °C and 77% purity.

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Page 43

PROPERTIES OF CALCIUM BROMIDE SOLUTIONS (CaBr

SG 1.38 1.40 1.42 1.44 1.46 1.48 1.5 1.52 1.54 1.56 1.58 1.60 1.62 1.64 1.66 1.68 1.70 1.72 1.74 1.76 1.78 1.80 1.82

Issue 1: November 2004 Rev. 0

Composition for 1m3 Water CaBr2 3 m Kg 0.8668 511.8 0.8599 538.4 0.8531 656.2 0.8462 591.9 0.8393 618.7 0.8325 645.4 0.8256 672.2 0.8187 699.0 0.8119 725.8 0.8050 752.6 0.7973 780.2 0.7895 807.9 0.7818 835.6 0.7740 863.3 0.7662 890.9 0.7584 918.6 0.7507 946.3 0.7429 974.0 0.7352 1001.7 0.7274 1029.4 0.7196 1057.0 0.7119 1084.7 0.7026 1113.9

TCT °C -33.9 -37.0 -39.8 -45.4 -49.4 -55.0 -62.0 -67.9 -70.9 -61.1 -54.6 -47.2 -39.8 -34.5 -34.0 -33.0 -26.0 -21.0 -11.0 -3.0 +4 +13 +20

PPG 11.6 11.7 11.8 11.9 12.0 12.1 12.2 12.3 12.4 12.5 12.60 12.7 12.8 12.9 13.0 13.1 13.2 13.3 13.4 13.5 13.6 13.7 13.8 13.9

Composition for 1 bbl Water CaBr2 bbl lb 0.860 186.3 0.856 191.9 0.852 197.5 0.848 203.1 0.844 208.7 0.840 214.3 0.836 219.9 0.832 225.5 0.828 231.1 0.824 236.7 0.820 242.3 0.816 248.0 0.811 253.7 0.807 259.4 0.803 265.1 0.799 270.8 0.794 276.5 0.790 282.2 0.786 287.9 0.781 293.6 0.777 299.4 0.772 305.2 0.768 311.0 0.763 316.8

2

)

TCT °C -35.5 -37.6 -39.8 -42.6 -45.4 -48.1 -51.5 -54.9 -56.8 -62.0 -66.7 -68.8 -70.9 -66.0 -61.0 -56.5 -52.8 -47.2 -41.7 -39.8 -36.4 -32.7 -28.7 -25 Completion Fluids

Page 44

PROPERTIES OF CALCIUM BROMIDE SOLUTIONS (CaBr (Cont’d)

PPG 14.0 14.1 14.2 14.3 14.4 14.5 14.6 14.7 14.8 14.9 15.0

Composition for 1 bbl Water CaBr2 bbl lb 0.758 322.6 0.754 328.4 0.751 333.4 0.744 340.1 0.739 346.0 0.734 351.9 0.730 357.8 0.724 363.8 0.719 369.8 0.714 375.8 0.709 381.8

2

)

TCT °C -33 28 25 21 17 11 -5 +1 +4 +9 +13

Properties based @ 20.0°C and 95% purity.

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Completion Fluids

Page 45

PROPERTIES OF SODIUM / CALCIUM CHLORIDE BLENDS (NaCl/CaCl2)

SG 1.210 1.222 1.234 1.246 1.258 1.270 1.282 1.294 1.306 1.318 1.330

International units NaCl CaCl2 kg/m3 kg/m3 251.0 83.0 199.0 148.0 154.0 205.0 117.0 253.0 91.0 296.0 71.0 330.0 57.0 359.0 46.0 385.0 37.0 410.0 29.0 430.0 23.0 453.0

Water Lt/m3 887 875 875 876 871 868 866 864 862 859 854

PPG 10.10 10.20 10.30 10.40 10.50 10.60 10.70 10.80 10.90 11.00 11.10

British units NaCl CaCl2 ppb ppb 87.9 29.1 69.7 51.8 53.9 71.8 41.0 88.6 31.9 103.6 24.9 115.5 20.0 125.7 16.1 134.8 13.0 143.5 10.2 150.5 8.1 158.6

Water gal/bbl 37.3 36.8 36.8 36.8 36.6 36.5 36.4 36.3 36.2 36.1 35.9

Crystallization Point (°C) -20 -23 -26 -29 -32 -36 -39 -41 -31 -24 -18

Properties based @ 20.0 °C.

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Completion Fluids

Page 46

PROPERTIES OF CALCIUM CHLORIDE / CALCIUM BROMIDE BLENDS (CaCl2/CaBr2)

PPG 11.7 11.8 11.9 12.0 12.1 12.2 12.3 12.4 12.5 12.6 12.7 12.8 12.9 13.0 13.1 13.2 13.3 13.4

Composition for 1 bbl bbl of CaBr2 lb of CaCl2 (@ 14.2 ppg) (95%) 0.025 193.4 0.051 191.0 0.076 188.4 0.102 185.8 0.127 183.3 0.152 180.7 0.178 178.1 0.203 175.6 0.229 173.0 0.254 170.4 0.279 167.8 0.305 165.3 0.336 163.2 0.356 160.1 0.381 157.5 0.406 155.0 0.432 152.4 0.457 149.8

bbl of Water 0.816 0.792 0.768 0.744 0.720 0.696 0.672 0.648 0.624 0.600 0.576 0.552 0.532 0.504 0.480 0.456 0.432 0.408

PPG 13.5 13.6 13.7 13.8 13.9 14.0 14.1 14.2 14.3 14.4 14.5 14.6 14.7 14.8 14.9 15.0 15.1

Composition for 1 bbl bbl of CaBr2 lb of CaCl2 (@ 14.2 ppg) (95%) 0.483 147.3 0.508 144.7 0.533 142.1 0.559 139.5 0.584 137.0 0.607 134.4 0.635 131.8 0.660 129.3 0.686 126.7 0.711 124.1 0.737 121.5 0.762 119.0 0.787 116.4 0.813 113.8 0.838 111.2 0.864 108.7 0.889 106.1

bbl of Water 0.384 0.360 0.336 0.312 0.288 0.264 0.240 0.216 0.192 0.168 0.144 0.120 0.096 0.072 0.048 0.024 --

Properties based @ 20 °C.

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Page 47

PROPERTIES OF ZINC / CALCIUM BROMIDE BLENDS (ZnBr2/CaBr2) PPG

% of CaBr2 (@ 14.2 ppg)

15.0 15.1 15.2 15.3 15.4 15.5 15.6 15.7 15.8 15.9 16.0 16.1 16.2 16.3 16.4 16.5 16.6 16.7 16.8 16.9 17.0

0.840 0.820 0.800 0.780 0.760 0.740 0.720 0.700 0.680 0.660 0.640 0.620 0.600 0.580 0.560 0.540 0.520 0.500 0.480 0.460 0.440

% of ZnBr2/CaBr2 (@ 19.2 ppg) 0.160 0.180 0.200 0.220 0.240 0.260 0.280 0.300 0.320 0.340 0.360 0.380 0.400 0.420 0.440 0.460 0.480 0.500 0.520 0.540 0.560

LCTD °F -22 -25 -27 -29 -32 -34 -35 -38 -40 -37 -33 -30 -26 -23 -20 -16 -11 -8 -6 -4 -4

PPG

% of CaBr2 (@ 14.2 ppg)

17.1 17.2 17.3 17.4 17.5 17.6 17.7 17.8 17.9 18.0 18.1 18.2 18.3 18.4 18.5 18.6 18.7 18.8 18.9 19.0 19.1 19.2

0.420 0.400 0.380 0.360 0.340 0.320 0.300 0.280 0.260 0.240 0.220 0.200 0.180 0.160 0.140 0.120 0.100 0.080 0.060 0.040 0.020 0.000

% of ZnBr2/CaBr2 (@ 19.2 ppg) 0580 0.600 0.620 0.640 0.660 0.680 0.700 0.720 0.740 0.760 0.780 0.800 0.820 0.840 0.860 0.880 0.900 0.920 0.940 0.960 0.980 1.000

LCTD °F -2 0 2 4 5 5 6 7 7 9 10 11 13 15 17 19 21 23 20 21 18 16

Properties based @ 20 °C.

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Completion Fluids

Page 48

PROPERTIES OF ZINC / CALCIUM BROMIDE. CALCIUM CHLORIDE BLENDS (ZnBr2/CaBr2/CaCl2) PPG 15.0 15.1 15.2 15.3 15.4 15.5 15.6 15.7 15.8 15.9 16.0 16.1 16.2 16.3 16.4 16.5 16.6 16.7 16.8 16.9 17.0

% CaBr2 (@ 14.2 ppg) 0.8891 0.8678 0.8464 0.8260 0.8046 0.7833 0.7620 0.7406 0.7202 0.6988 0.6775 0.6562 0.6348 0.6135 0.5930 0.5717 0.5504 0.5263 0.5077 0.4872 0.4859

% ZnBr2/CaBr2 (@ 19.2 ppg) 0.000 0.024 0.048 0.071 0.095 0.119 0.143 0.167 0.190 0.214 0.238 0.262 0286 0.310 0.333 0.357 0.381 0.405 0.429 0.452 0.476

lb CaCl2 (94%) 106 103 101 98 96 93 91 88 86 83 81 78 76 73 71 68 66 63 61 58 56

LCTD °F +64 62 61 59 59 59 58 57 55 54 53 52 50 50 49 47 46 43 40 36 32

PPG 17.1 17.2 17.3 17.4 17.5 17.6 17.7 17.8 17.9 18.0 18.1 18.2 18.3 18.4 18.5 18.6 18.7 18.8 18.9 19.0 19.1 19.2

% CaBr2 (@ 14.2 ppg) 0.4446 0.4232 0.4019 0.3814 0.3601 0.3387 0.3174 0.2961 0.2756 0.2543 0.2329 0.2116 0.1903 0.1689 0.1485 0.1271 0.1058 0.0845 0.0631 0.0427 0.0213 0.0000

% ZnBr2/CaBr2 (@ 19.2 ppg) 0.500 0.524 0.548 0.571 0.592 0.619 0.643 0.667 0.690 0.714 0.738 0.762 0.786 0.810 0.833 0.857 0.881 0.905 0.929 0.952 0.976 1.000

lb CaCl2 (94%) 53 50 48 45 43 40 38 35 33 30 28 25 23 20 18 15 13 10 8 5 3 0

LCTD °F 28 31 35 37 41 45 44 44 43 43 42 41 37 35 32 28 25 23 18 18 17 16

Properties based @ 20°C.

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Page 49

PROPERTIES OF AMMONIUM CHLORIDE (NH %w

ppm

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 22 24

10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 220000 240000

International units NH4Cl Water SG kg/m3 Lt/m3 1.001 10.0 991 1.005 20.0 984 1.008 30.2 977 1.011 40.2 970 1.014 50.4 963 1.017 60.9 956 1.020 71.2 948 1.023 81.5 941 1.026 92.1 933 1.029 102.6 926 1.032 113.1 918 1.034 123.7 910 1.037 134.5 902 1.040 145.3 895 1.043 155.9 887 1.046 167.0 878 1.049 177.8 870 1.051 188.7 862 1.054 199.8 854 1.057 210.9 845 1.062 233.1 828 1.067 255.6 811

British units NH4Cl Water PPG ppb gal/bbl 8.35 3.5 41.6 8.39 7.0 41.3 8.41 10.6 41.0 8.44 14.1 40.8 8.46 17.6 40.5 8.49 21.3 40.2 8.51 24.9 39.8 8.54 28.5 39.5 8.56 32.2 39.2 8.59 35.9 38.9 8.61 39.6 38.6 8.63 43.3 38.2 8.65 47.1 37.9 8.68 50.9 37.6 8.70 54.6 37.3 8.73 58.5 36.9 8.75 62.2 36.6 8.77 66.0 36.2 8.80 69.9 35.9 8.82 73.8 35.5 8.86 81.6 34.8 8.90 89.5 34.1

4

Cl) SOLUTIONS

Ion composition Cryst. Temp. mg/L mg/L mg/L (°C) NH4Cl NH4+ Cl10010 3371 6635 -0.5 20100 6769 13324 -1.5 30240 10184 20045 -2.0 40440 13619 26806 -2.5 50700 17074 33607 -3.0 61020 20549 40448 -4.0 71400 24045 47328 -4.5 81840 27561 54249 -5.5 92340 31097 61209 -6.0 102900 34653 68209 -7.0 113520 38229 75248 -8.0 124080 41786 82248 -8.5 134810 45399 89360 -9.5 145600 49033 96513 N/D 156450 52687 103705 -11.5 167360 56361 110937 N/D 178330 60055 118208 N/D 189180 63709 125400 N/D 200260 67440 132745 N/D 211400 71192 140129 N/D 233640 78681 154871 N/D 256080 86238 169746 -0.5

Properties based @ 20°C and 99% purity.

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Page 50

PROPERTIES OF MAGNESIUM CHLORIDE (MgCl %w

ppm

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30

10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 210000 220000 230000 240000 250000 260000 270000 280000 290000 300000

International units KCl Water SG kg/m3 Lt/m3 1.008 21.4 993 1.016 43.4 988 1.024 65.4 974 1.033 88.0 959 1.041 110.9 945 1.050 134.3 931 1.058 157.7 914 1.067 181.7 900 1.076 206.0 886 1.085 231.1 869 1.094 256.3 862 1.103 281.7 852 1.112 308.0 836 1.121 334.0 819 1.130 361.1 802 1.139 388.0 786 1.148 415.7 750 1.157 443.7 712 1.167 472.3 693 1.176 500.9 674 1.186 530.6 655 1.196 560.0 633 1.206 590.9 614 1.216 621.4 593 1.227 653.1 571 1.237 684.6 550 1.248 717.1 529 1.258 749.7 505 1.269 783.1 483 1.279 816.6 460

PPG 8.41 8.48 8.55 8.62 8.69 8.76 8.83 8.90 8.98 9.05 9.13 9.20 9.28 9.35 9.43 9.50 9.58 9.66 9.74 9.81 9.90 9.98 10.06 10.15 10.24 10.32 10.41 10.50 10.59 10.67

British units NaCl Water ppb gal/bbl 7.5 41.7 15.2 41.5 22.9 40.9 30.8 40.3 38.8 39.7 47.0 39.1 55.2 38.4 63.6 37.8 72.1 37.2 80.9 36.5 89.7 36.2 98.6 35.8 107.8 35.1 116.9 34.4 126.4 33.7 135.8 33.0 145.5 31.5 155.3 29.9 165.3 29.1 175.3 28.3 185.7 27.5 196.0 26.6 206.8 25.8 217.5 24.9 228.6 24.0 239.6 23.1 251.0 22.2 262.4 21.2 274.1 20.3 285.8 19.3

Ion composition mg/L mg/L NaCl Cl10080 2574 20320 5188 30720 7844 41320 10550 52050 13290 63000 16086 74060 18910 85360 21795 96840 24726 108500 27703 120340 30726 132360 33796 144560 36911 156940 40072 169500 43278 182240 46531 195160 49830 208260 53175 221730 56614 235200 60054 249060 63593 263120 67183 277380 70824 291840 74516 306750 78323 321620 82119 336960 86036 352240 89938 368010 93964 383700 97970

2

) SOLUTIONS

Cryst. Temp. (°C)

F factor

Aw

-0.5 -1.1 -1.7 -2.3 -3.0 -4.3 -5.4 -5.8 -6.8 -7.7 N/D -9.7 N/D -14.5 N/D -18.8 N/D -25.0 N/D -33.2 N/D -28.1 N/D -24.3 N/D -20.5 N/D -17.1 N/D -16.4

1.007 1.013 1.028 1.043 1.058 1.075 1.093 1.111 1.130 1.151 1.161 1.172 1.195 1.220 1.245 1.272 1.334 1.403 1.442 1.484 1.529 1.577 1.630 1.686 1.750 1.818 1.894 1.976 2.070 2.174

0.985 0.981 0.978 0.974 0.970 0.964 0.958 0.952 0.943 0.934 0.924 0.913 0.901 0.888 0.875 0.862 0.846 0.830 0.813 0.795 0.778 0.760 0.737 0.713 0.691 0.669 0.647 0.625 0.604 0.582

Properties based @ 20°C and MgCl2⋅6H2O 99%. Issue 1: November 2004 Rev. 0

Completion Fluids

Page 51

PROPERTIES OF POTASSIUM ACETATE (CH SOLUTIONS %w

ppm

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 210000 220000 230000 240000 250000

International units CH3COOK Water SG kg/m3 Lt/m3 1.004 10.0 994 1.009 20.0 989 1.014 29.9 984 1.019 40.0 979 1.024 49.9 974 1.029 62.7 966 1.034 74.1 960 1.040 85.5 954 1.045 99.8 945 1.050 111.1 938 1.055 122.5 932 1.060 136.8 923 1.065 148.2 917 1.070 162.4 907 1.076 176.7 898 1.081 191.1 889 1.086 205.2 880 1.091 219.4 871 1.097 233.7 863 1.102 250.8 851 1.086 265.0 820 1.113 282.1 830 1.119 299.2 819 1.124 316.3 807 1.129 333.4 795

PPG 8.38 8.42 8.46 8.50 8.55 8.59 8.63 8.68 8.72 8.76 8.80 8.85 8.89 8.93 8.98 9.02 9.06 9.10 9.15 9.20 9.06 9.29 9.34 9.38 9.42

British units CH3COOK Water ppb gal/bbl 3.5 41.7 7.0 41.5 10.5 41.3 14.0 41.1 17.5 40.9 21.9 40.6 25.9 40.3 29.9 40.1 34.9 39.7 38.9 39.4 42.9 39.1 47.9 38.8 51.9 38.5 56.8 38.1 61.8 37.7 66.9 37.3 71.8 37.0 76.8 36.6 81.8 36.2 87.8 35.7 92.8 34.4 98.7 34.9 104.7 34.4 110.7 33.9 116.7 33.4

3

COOK)

Ion composition mg/L mg/L K+ CH3COO10040 4002 20180 8043 30420 12125 40760 16246 51200 20407 61740 24608 72380 28849 83200 33161 94050 37486 105000 41850 116050 46254 127200 50698 138450 55182 149800 59706 161400 64330 172960 68937 184620 73585 196380 78272 208430 83075 220400 87845 228060 90899 244860 97595 257370 102581 269760 107519 282250 112497

Aw 0.99 0.98 0.97 0.96 0.95 0.94 0.93 0.92 0.91 0.90 0.89 0.88 0.87 0.86 0.85 0.84 0.83 0.82 0.81 0.80 0.79 0.78 0.77 0.76 0.75

Properties based @ 20°C and 99% purity. Issue 1: November 2004 Rev. 0

Completion Fluids

Page 52

PROPERTIES OF SODIUM FORMATE SOLUTIONS (HCOONa) %w

ppm

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30

10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 210000 220000 230000 240000 250000 260000 270000 280000 290000 300000

Issue 1: November 2004 Rev. 0

International units HCOONa Water SG kg/m3 Lt/m3 1.005 10.0 997 1.010 20.2 992 1.016 30.5 987 1.022 40.9 982 1.027 51.4 978 1.034 62.0 973 1.040 72.8 969 1.046 83.7 964 1.053 94.7 959 1.059 105.8 956 1.067 117.2 950 1.072 128.7 945 1.079 140.3 940 1.085 152.0 935 1.092 163.8 930 1.099 175.8 924 1.105 187.9 919 1.112 200.2 913 1.119 212.6 907 1.125 226.1 902 1.132 237.7 896 1.139 250.6 890 1.146 253.6 883 1.153 276.7 878 1.160 290.0 871 1.167 303.5 865 1.174 317.1 859 1.182 330.9 852 1.189 344.9 846 1.197 359.1 839

PPG 8.39 8.43 8.48 8.53 8.57 8.63 8.68 8.73 8.79 8.84 8.90 8.95 9.00 9.05 9.11 9.17 9.22 9.28 9.34 9.39 9.45 9.50 9.56 9.62 9.68 9.74 9.80 9.86 9.92 9.99

British units HCOONa Water ppb gal/bbl 3.5 41.9 7.1 41.7 10.7 41.5 14.3 41.2 18.0 41.1 21.7 40.9 25.5 40.7 29.3 40.5 33.1 40.3 37.0 40.2 41.0 39.9 45.0 39.7 49.1 39.5 53.2 39.3 57.3 39.1 61.5 38.8 65.8 38.6 70.1 38.3 74.4 38.1 79.1 37.9 83.2 37.6 87.7 37.4 88.8 37.1 96.8 36.9 101.5 36.6 106.2 36.3 111.0 36.1 115.8 35.8 120.7 35.5 125.7 35.2

Ion composition mg/L mg/L HCOONa Na+ 10050 3396 20200 6826 30480 10300 40880 13815 51350 17353 62040 20966 72800 24602 83680 28279 94770 32027 105900 35788 117370 39664 128640 43473 140270 47403 151900 51333 163800 55355 175840 59424 187850 63482 200160 67642 212610 71850 225000 76037 237720 80335 250580 84681 263580 89075 276720 93515 290000 98003 303420 102538 316980 107121 330960 111845 344810 116525 359100 121355

mg/L HCOO6651 13368 20171 27053 33982 41056 48176 55376 62715 70081 77671 85129 92826 100522 108397 116365 124313 132459 140698 148897 157315 165825 174428 183124 191912 200793 209766 219018 228183 237640 Completion Fluids

Page 53

PROPERTIES OF SODIUM FORMATE SOLUTIONS (HCOONa) (Cont’d) %w

ppm

31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 43 44 45 46 47 48 49

310000 320000 330000 340000 350000 360000 370000 380000 390000 400000 410000 420000 430000 440000 450000 460000 470000 480000 490000 430000 440000 450000 460000 470000 480000 490000

International units HCOONa Water SG kg/m3 Lt/m3 1.205 373.4 833 1.212 388.0 827 1.220 402.7 819 1.228 417.6 812 1.236 432.7 806 1.244 447.9 798 1.252 463.3 790 1.260 478.8 783 1.268 494.5 775 1.276 510.3 767 1.283 526.1 758 1.291 542.0 750 1.297 557.9 741 1.304 573.8 732 1.310 589.6 722 1.316 605.2 712 1.320 620.6 701 1.324 635.7 690 1.327 650.5 678 1.297 557.9 741 1.304 573.8 732 1.310 589.6 722 1.316 605.2 712 1.320 620.6 701 1.324 635.7 690 1.327 650.5 678

PPG 10.06 10.11 10.18 10.25 10.31 10.38 10.45 10.51 10.58 10.65 10.71 10.77 10.82 10.88 10.93 10.98 11.02 11.05 11.07 10.82 10.88 10.93 10.98 11.02 11.05 11.07

British units HCOONa Water ppb gal/bbl 130.7 35.0 135.8 34.7 141.0 34.4 146.2 34.1 151.5 33.9 156.8 33.5 162.2 33.2 167.6 32.9 173.1 32.6 178.6 32.2 184.1 31.8 189.7 31.5 195.3 31.1 200.8 30.7 206.4 30.3 211.8 29.9 217.2 29.4 222.5 29.0 227.7 28.5 195.3 31.1 200.8 30.7 206.4 30.3 211.8 29.9 217.2 29.4 222.5 29.0 227.7 28.5

Ion composition mg/L mg/L HCOONa Na+ 373550 126238 387840 131067 402600 136055 417520 141097 432600 146193 447840 151344 463240 156548 478800 161806 494520 167119 510400 172485 526030 177767 542220 183238 557710 188473 573760 193897 589500 199216 605360 204576 620400 209659 635520 214768 650230 219739 557710 188473 573760 193897 589500 199216 605360 204576 620400 209659 635520 214768 650230 219739

mg/L HCOO247202 256659 266426 276300 286279 296365 306556 316853 327256 337765 348108 358822 369073 379694 390110 400606 410559 420565 430299 369073 379694 390110 400606 410559 420565 430299

Properties based @ 20°C and 99% purity. Issue 1: November 2004 Rev. 0

Completion Fluids

Page 54

PROPERTIES OF POTASSIUM FORMATE SOLUTIONS (HCOOK) %w

ppm

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31

10000 20000 30000 40000 50000 60000 70000 80000 90000 100000 110000 120000 130000 140000 150000 160000 170000 180000 190000 200000 210000 220000 230000 240000 250000 260000 270000 280000 290000 300000 310000

Issue 1: November 2004 Rev. 0

International units HCOOK Water SG kg/m3 Lt/m3 1.006 10.0 998 1.012 20.2 994 1.016 30.5 990 1.024 41.0 985 1.030 51.5 980 1.036 62.2 975 1.042 72.9 970 1.047 83.8 966 1.053 94.8 960 1.059 105.9 954 1.065 117.1 949 1.070 128.5 944 1.076 139.9 938 1.082 151.5 932 1.088 163.2 928 1.094 175.0 921 1.100 187.0 919 1.106 199.1 909 1.113 211.4 903 1.119 223.8 897 1.125 236.3 891 1.132 249.0 884 1.139 261.9 878 1.145 274.9 872 1.152 288.0 866 1.159 301.3 859 1.166 314.8 853 1.173 328.5 846 1.180 342.3 840 1.187 356.3 833 1.195 370.4 826

PPG 8.40 8.45 8.48 8.55 8.60 8.65 8.70 8.74 8.79 8.84 8.89 8.93 8.98 9.03 9.08 9.13 9.18 9.23 9.29 9.34 9.39 9.45 9.50 9.56 9.61 9.67 9.73 9.79 9.85 9.91 9.97

British units HCOOK Water ppb gal/bbl 3.5 41.9 7.1 41.7 10.7 41.6 14.4 41.4 18.0 41.2 21.8 41.0 25.5 40.7 29.3 40.6 33.2 40.3 37.1 40.1 41.0 39.9 45.0 39.6 49.0 39.4 53.0 39.1 57.1 39.0 61.3 38.7 65.5 38.6 69.7 38.2 74.0 37.9 78.3 37.7 82.7 37.4 87.2 37.1 91.7 36.9 96.2 36.6 100.8 36.4 105.5 36.1 110.2 35.8 115.0 35.5 119.8 35.3 124.7 35.0 129.6 34.7

Ion composition mg/L mg/L HCOOK K+ 10060 4677 20240 9410 30480 14171 40960 19043 51500 23944 62160 28900 72940 33911 83760 38942 94770 44061 105900 49235 117150 54466 128400 59696 139880 65033 151480 70426 163200 75875 175040 81380 187000 86941 199080 92557 211470 98317 223800 104050 236250 109838 249040 115784 261970 121796 274800 127761 288000 133898 301340 140100 314820 146367 328440 152699 342200 159097 356100 165559 370450 172231

mg/L HCOO5383 10830 16309 21917 27556 33260 39029 44818 50709 56665 62684 68704 74847 81054 87325 93660 100059 106523 113153 119750 126412 133256 140174 147039 154102 161240 168453 175741 183103 190541 198219 Completion Fluids

Page 55

PROPERTIES OF POTASSIUM FORMATE SOLUTIONS (HCOOK) (Cont’d) %w

ppm

32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59

320000 330000 340000 350000 360000 370000 380000 390000 400000 410000 420000 430000 440000 450000 460000 470000 480000 490000 500000 510000 520000 530000 540000 550000 560000 570000 580000 590000

Issue 1: November 2004 Rev. 0

International units HCOOK Water SG kg/m3 Lt/m3 1.202 384.8 819 1.210 399.2 812 1.217 413.9 805 1.225 428.8 798 1.233 443.8 790 1.240 459.0 783 1.248 474.3 775 1.256 489.8 768 1.264 505.6 760 1.272 521.4 752 1.280 537.5 744 1.288 553.7 735 1.296 570.1 727 1.304 586.7 718 1.312 603.5 710 1.320 620.4 701 1.328 637.5 692 1.336 654.8 683 1.344 672.2 673 1.353 689.8 664 1.361 707.6 654 1.369 725.6 645 1.377 743.8 635 1.386 762.2 625 1.394 780.8 615 1.403 799.5 604 1.411 818.5 594 1.42 837.7 583

PPG 10.03 10.10 10.16 10.22 10.29 10.35 10.41 10.48 10.55 10.61 10.68 10.75 10.82 10.88 10.95 11.02 11.08 11.15 11.2 11.3 11.4 11.4 11.5 11.6 11.6 11.7 11.8 11.8

British units HCOOK Water ppb gal/bbl 134.7 34.4 139.7 34.1 144.9 33.8 150.1 33.5 155.3 33.2 160.7 32.9 166.0 32.6 171.4 32.3 177.0 31.9 182.5 31.6 188.1 31.2 193.8 30.9 199.5 30.5 205.4 30.2 211.2 29.8 217.2 29.4 223.1 29.1 229.2 28.7 235.3 28.3 241.4 27.9 247.7 27.5 254.0 27.1 260.3 26.7 266.8 26.3 273.3 25.8 279.8 25.4 286.5 24.9 293.2 24.5

Ion composition mg/L mg/L HCOOK K+ 384640 178828 399300 185644 413780 192376 428750 199336 443880 206370 458800 213307 474240 220485 489840 227738 505600 235065 521520 242466 537600 249942 553840 257493 570240 265118 586800 272817 603520 280590 620400 288438 637440 296360 654640 304357 672000 312428 690030 320811 707720 329035 725570 337334 743580 345707 762300 354411 780640 362937 799710 371803 818380 380483 837800 389512

mg/L HCOO205812 213656 221404 229414 237510 245493 253755 262102 270535 279054 287658 296347 305122 313983 322930 331962 341080 350283 359572 369219 378685 388236 397873 407889 417703 427907 437897 448288 Completion Fluids

Page 56

PROPERTIES OF POTASSIUM FORMATE SOLUTIONS (HCOOK) (Cont’d) %w

ppm

60 61 62 63 64

600000 610000 620000 630000 640000

International units HCOOK Water SG kg/m3 Lt/m3 1.429 587.1 572 1.437 876.8 562 1.446 896.7 551 1.456 916.9 539 1.465 937.3 528

PPG 11.9 12.0 12.1 12.2 12.2

British units HCOOK Water ppb gal/bbl 205.5 24.0 306.9 23.6 313.9 23.1 320.9 22.6 328.1 22.2

Ion composition mg/L mg/L HCOOK K+ 857400 398625 876570 407537 896520 416813 917280 426464 937600 435912

mg/L HCOO458775 469033 479707 490816 501688

Properties based @ 20°C and 99% purity.

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 57

NOTES:

Issue 1: November 2004 Rev. 0

Completion Fluids

Page 58

MUD PUMPS 1. Theoretical Flow Rate a. Duplex pumps  d2 Qt = 0.0515⋅n⋅L⋅  D 2 − 2 

  

b. Triplex pumps Qt = 0.0386⋅n⋅L⋅D2 Qt = theoretical flow rate (L/m) D = liner diameter (in)

n = strokes per minute (strokes/min) d = piston rod diameter (in)

L = length of stroke (in)

2. Volumetric Efficiency (ηv) ηv =

Qr Qt

Qr = true measured flow rate (L/m)

Issue 1: November 2004 Rev. 0

Mud Pumps

Page 59

DUPLEX PUMP OUTPUT Liters/Stroke @ 90% Efficiency (2” Rod Diameter) Liner diameter (mm) Stroke Length (mm) 203 254 305 356 381 406 457 508 559 610

101

108

114

121

127

133

140

146

152

159

165

170

178

184

190

197

203

209

216

5.40 6.67 7.78

6.19 7.62 9.90

6.99 8.58 10.1

7.78 6.69 11.4

8.73 10.8 12.9 14.6 15.6 16.7 18.4 20.3

6.69 12.0 14.3 16.4 17.3 18.6 20.7 22.7

10.6 13.3 15.9 18.0 19.2 20.5 22.7 25.1

11.5 14.6 17.3 19.9 21.1 22.6 25.3 28.0

12.7 15.9 19.1 21.8 23.2 24.8 27.8 30.5

13.8 17.3 20.7 23.8 25.3 27.0 30.2 33.4

15.0 18.7 22.6 25.9 27.5 29.4 32.7 36.4

16.2 20.0 24.3 28.0 29.7 32.3 35.6 39.4

17.4 21.9 26.2 30.2 32.3 34.5 38.5 46.2 49.8

18.9 23.6 28.3 32.4 34.7 37.0 41.3 45.9 53.5

30.4 35.0 37.4 39.7 44.5 49.4 57.3

37.4 39.9 42.8 47.7 53.1 61.1

39.9 42.8 45.6 51.1 56.8 65.1 71.1

48.6 54.4 60.4 69.2 75.6

73.5 80.2

Note: For pump output in m3/stroke, move the decimal point 3 places to the left.

DUPLEX MUD PUMPS: The pistons on a duplex mud pump work in both directions, so that the rear cylinder has the pump rod moving through its swept volume and occupying some volume. The difference in calculations for a duplex vs. a triplex pump is that the displacement volume of this pump rod must be subtracted from the volume in one of the cylinders, plus the difference in number of pumping cylinders; 4 for a duplex and 3 for a triplex. Duplex pumps generally have longer strokes (in the 10 to 18 in. range) and operate at lower rate; in the 40 to 80 stroke/min range. The general equation to calculate output of a duplex pump is: Pump output (liters/stroke) =

2 ⋅ ID 2 (mm) − OD 2 (mm) ⋅ L(mm) ⋅ Eff (decimal) 636500

Where: ID = OD =

ID of the liner OD of the rod

Issue 1: November 2004 Rev. 0

L= Eff =

Length of the pump stroke Pump efficiency (decimal) Mud Pumps

Page 60

TRIPLEX PUMP OUTPUT Liters/Stroke @ 100% Efficiency Liner diameter (mm) Stroke Length (mm) 102 114 127 140 152 165 178 190 203 216 229 241 254 267 279 292 305

102

108

114

121

127

133

140

146

152

159

165

170

178

184

190

197

203

2.5 2.8 3.0 3.4 3.7 4.0 4.3 4.6 4.9 5.2 5.6 5.9 6.2 6.5 6.8 7.1 7.4

2.8 3.1 3.5 3.8 4.2 4.5 4.9 5.2 5.6 5.9 6.3 6.6 7.0 7.3 7.7 8.0 8.4

3.1 3.5 3.9 4.3 4.7 5.1 5.5 5.9 6.2 6.6 7.0 7.4 7.8 8.2 8.6 9.0 9.4

3.5 3.9 4.4 4.8 5.2 5.7 6.1 6.5 6.9 7.4 7.8 8.3 8.7 9.1 9.6 10.0 10.4

3.9 4.3 4.8 5.3 5.8 6.3 6.8 7.2 7.7 8.2 8.7 9.2 9.6 10.1 10.6 11.1 11.6

4.3 4.8 5.3 5.8 6.4 6.9 7.4 8.0 8.5 9.0 9.6 10.1 10.6 11.2 11.7 12.2 12.8

5.3 5.8 6.5 7.0 7.6 8.2 8.8 9.3 9.9 10.5 11.1 11.7 12.3 12.8 13.4 13.8

5.7 6.4 7.0 7.7 8.3 8.9 9.6 10.2 10.8 11.5 12.1 12.8 13.4 14.0 14.7 15.3

6.3 6.9 7.6 8.3 9.0 9.7 10.4 11.1 11.8 12.5 13.2 13.9 14.6 15.3 16.0 16.7

7.5 8.3 9.0 9.8 10.6 11.3 12.0 12.8 13.6 14.3 15.1 15.8 16.6 17.3 18.1

9.7 10.6 11.4 12.2 13.0 13.8 14.7 15.5 16.3 17.2 17.9 18.7 19.6

12.3 13.1 14.0 14.9 15.8 16.7 17.6 18.5 19.3 20.2 21.1

13.2 14.2 15.1 16.3 17.0 18.0 18.9 19.9 20.8 21.8 22.2

15.2 16.2 17.2 18.3 19.3 20.3 21.3 22.3 23.3 24.3

16.1 17.3 18.5 19.5 20.6 21.7 22.8 23.9 25.0 26.0

18.5 19.7 20.9 22.0 23.2 24.3 25.5 26.7 27.8

19.7 21.0 22.2 23.3 24.7 25.9 27.2 28.4 29.6

Note: For pump output in m3/stroke, move the decimal point 3 places to the left.

TRIPLEX MUD PUMPS The pistons on a triplex mud pump work only on the forward stroke, and generally have short strokes (in the 6-12 inch range) and operate at rates in the 60-120 stroke/min range. The general equation to calculate output of a triplex pump is: Pump output (liters/stroke) = Where:

ID =

Issue 1: November 2004 Rev. 0

ID of the liner

L=

Length of the pump stroke

Eff =

ID 2 (mm) ⋅ L(mm) ⋅ Eff (decimal) 424333 Pump efficiency (decimal) Mud Pumps

Page 61

NOTES:

Issue 1: November 2004 Rev. 0

Mud Pumps

Page 62

CAPACITY OF HOLE VOLUMES Diameter (in) 1 1 1/8 1 1/4 1 3/8 1 1/2 1 5/8 1 3/4 1 7/8 2 2 1/8 2 1/4 2 3/8 2 1/2 2 5/8 2 3/4 2 7/8 3 3 1/8 3 1/4 3 3/8 3 1/2 3 5/8 3 3/4 3 7/8 4 4 1/8 4 1/4 4 3/8 4 1/2 4 5/8 4 3/4 4 7/8

Capacity (L/m) 0.507 0.641 0.792 0.958 1.140 1.338 1.552 1.781 2.027 2.288 2.565 2.858 3.167 3.491 3.832 4.188 4.560 4.948 5.352 5.772 6.207 6.658 7.125 7.608 8.107 8.622 9.152 9.699 10.26 10.84 11.43 12.04

Issue 1: November 2004 Rev. 0

Diameter (in) 5 5 1/8 5 1/4 5 3/8 5 1/2 5 5/8 5 3/4 5 7/8 6 6 1/8 6 1/4 6 3/8 6 1/2 6 5/8 6 3/4 6 7/8 7 7 1/8 7 1/4 7 3/8 7 1/2 7 5/8 7 3/4 7 7/8 8 8 1/8 8 1/4 8 3/8 8 1/2 8 5/8 8 3/4 8 7/8

Capacity (L/m) 12.67 13.31 13.97 14.64 15.33 16.03 16.75 17.49 18.24 19.01 19.79 20.59 21.41 22.24 23.09 23.95 24.83 25.72 26.63 27.56 28.50 29.46 30.43 31.42 32.43 33.45 34.49 35.54 36.61 37.69 38.79 39.91

Diameter (in) 9 9 1/8 9 1/4 9 3/8 9 1/2 9 5/8 9 3/4 9 7/8 10 10 1/8 10 1/4 10 3/8 10 1/2 10 5/8 10 3/4 10 7/8 11 11 1/8 11 1/4 11 3/8 11 1/2 11 5/8 11 3/4 11 7/8 12 12 1/8 12 1/4 12 3/8 12 1/2 12 5/8 12 3/4 12 7/8

Capacity (L/m) 41.04 42.19 43.35 44.53 45.73 46.94 48.17 49.41 50.67 51.94 53.24 54.54 55.86 57.20 58.56 59.93 61.31 62.71 64.13 65.56 67.01 68.48 69.96 71.45 72.96 74.49 76.04 77.60 79.17 80.76 82.37 83.99

Diameter (in) 13 13 1/8 13 1/4 13 3/8 13 1/2 13 5/8 13 3/4 13 7/8 14 14 1/8 14 1/4 14 3/8 14 1/2 14 5/8 14 3/4 14 7/8 15 15 1/8 15 1/4 15 3/8 15 1/2 15 5/8 15 3/4 15 7/8 16 16 1/8 16 1/4 16 3/8 16 1/2 16 5/8 16 3/4 16 7/8

Capacity (L/m) 85.63 87.29 88.96 90.64 92.35 94.06 95.80 97.55 99.31 101.1 102.9 104.7 106.5 108.4 110.2 112.1 114.0 115.9 117.8 119.8 121.7 123.7 125.7 127.7 129.7 131.7 133.8 135.9 137.9 140.0 142.2 144.3

Diameter (in) 17 17 1/8 17 1/4 17 3/8 17 1/2 17 5/8 17 3/4 17 7/8 18 18 1/8 18 1/4 18 3/8 18 1/2 18 5/8 18 3/4 18 7/8 19 19 1/8 19 1/4 19 3/8 19 1/2 19 5/8 19 3/4 19 7/8 20 20 1/8 20 1/4 20 3/8 20 1/2 20 5/8 20 3/4 20 7/8

Capacity (L/m) 146.4 148.6 150.8 153.0 155.2 157.4 159.6 161.9 164.2 166.5 168.8 171.1 173.4 175.8 178.1 180.5 182.9 185.3 187.8 190.2 192.7 195.2 197.6 200.2 202.7 205.2 207.8 210.4 212.9 215.5 218.2 220.8

Capacities & Volumes

Page 63

CAPACITY OF HOLE VOLUMES (continued) Diameter (in) 21 21 1/8 21 1/4 21 3/8 21 1/2 21 5/8 21 3/4 21 7/8 22 22 1/8 22 1/4 22 3/8 22 1/2 22 5/8 22 3/4 22 7/8 23 23 1/8 23 1/4 23 3/8 23 1/2 23 5/8 23 3/4 23 7/8 24 24 1/8 24 1/4 24 3/8 24 1/2 24 5/8 24 3/4 24 7/8 Issue 1: November 2004 Rev. 0

Capacity (L/m) 223.5 226.1 228.8 231.5 234.2 237.0 239.7 242.5 245.2 248.0 250.8 253.7 256.5 259.4 262.2 265.1 268.0 271.0 273.9 276.9 279.8 282.8 285.8 288.8 291.9 294.9 298.0 301.1 304.1 307.3 310.4 313.5

Diameter (in) 25 25 1/8 25 1/4 25 3/8 25 1/2 25 5/8 25 3/4 25 7/8 26 26 1/8 26 1/4 26 3/8 26 1/2 26 5/8 26 3/4 26 7/8 27 27 1/8 27 1/4 27 3/8 27 1/2 27 5/8 27 3/4 27 7/8 28 28 1/8 28 1/4 28 3/8 28 1/2 28 5/8 28 3/4 28 7/8

Capacity (L/m) 316.7 319.9 323.1 326.3 329.5 332.7 336.0 339.2 342.5 345.8 349.1 352.5 355.8 359.2 362.6 366.0 369.4 372.8 376.3 379.7 383.2 386.7 390.2 393.7 397.3 400.8 404.4 408.0 411.6 415.2 418.8 422.5

Diameter (in) 29 29 1/8 29 1/4 29 3/8 29 1/2 29 5/8 29 3/4 29 7/8 30 30 1/8 30 1/4 30 3/8 30 1/2 30 5/8 30 3/4 30 7/8 31 31 1/8 31 1/4 31 3/8 31 1/2 31 5/8 31 3/4 31 7/8 32 32 1/8 32 1/4 32 3/8 32 1/2 32 5/8 32 3/4 32 7/8

Capacity (L/m) 426.1 429.8 433.5 437.2 441.0 444.7 448.5 452.2 456.0 459.8 463.7 467.5 471.4 475.2 479.1 483.0 486.9 490.9 494.8 498.8 502.8 506.8 510.8 514.8 518.9 522.9 527.0 531.1 535.2 539.3 543.5 547.6

Diameter (in) 33 33 1/8 33 1/4 33 3/8 33 1/2 33 5/8 33 3/4 33 7/8 34 34 1/8 34 1/4 34 3/8 34 1/2 34 5/8 34 3/4 34 7/8 35 35 1/8 35 1/4 35 3/8 35 1/2 35 5/8 35 3/4 35 7/8 36 36 1/8 36 1/4 36 3/8 36 1/2 36 5/8 36 3/4 36 7/8

Capacity (L/m) 551.8 556.0 560.2 564.4 568.6 572.9 577.2 581.4 585.7 590.1 594.4 598.7 603.1 607.5 611.9 616.3 620.7 625.1 629.6 634.1 638.6 643.1 647.6 652.1 656.7 661.3 665.8 670.4 675.1 679.7 684.3 689.0 Capacities & Volumes

Page 64

CAPACITY & DISPLACEMENT OF DRILL COLLARS OD (in) 3 1/8 3 1/4 3 1/2 3 3/4 4 1/8 4 1/4 4 1/2 4 3/4 5 5 1/4 5 1/2 5 3/4 6 6 1/4 6 1/2 6 3/4 7 7 1/4 7 1/2 7 3/4 8 8 1/4 8 1/2 8 3/4 9 9 1/4 9 1/2 9 3/4 10 11 11 1/4 Issue 1: November 2004 Rev. 0

Total displacement (L/m) 4.95 5.35 6.21 7.13 8.62 9.15 10.26 11.43 12.67 13.97 15.33 16.75 18.24 19.79 21.41 23.09 24.83 26.63 28.50 30.43 32.43 34.49 36.61 38.79 41.04 43.35 45.73 48.17 50.67 61.31 64.13

ID (in) 1 1/4 1 1/2 1 1/2 1 1/2 2 2 2 2 2 1/4 2 1/4 2 1/4 2 1/4 2 1/4 2 1/4 2 1/4 2 1/4 2 1/4 2 13/16 2 13/16 2 13/16 2 13/16 2 13/16 2 13/16 2 13/16 2 13/16 3 3 3 3 3 3

Capacity (L/m) 0.79 1.14 1.14 1.14 2.03 2.03 2.03 2.03 2.57 2.57 2.57 2.57 2.57 2.57 2.57 2.57 2.57 4.01 4.01 4.01 4.01 4.01 4.01 4.01 4.01 4.56 4.56 4.56 4.56 4.56 4.56 Capacities & Volumes

Page 65

CAPACITY AND DISPLACEMENT OF CASING O.D. (mm) 114.3 (4 ½”)

127.0 (5”)

139.7 (5 ½”)

168.3 (6 ? ”)

177.8 (7”)

MASS (kg/m) 14.14 15.62 17.26 20.09 17.11 19.34 22.32 26.78 20.83 23.06 25.30 29.76 34.22 29.76 35.71 41.66 47.62 25.30 29.76 34.22 38.69 43.15 47.62 52.08 56.54

I.D. (mm) 103.89 102.92 101.60 99.57 115.82 114.15 111.96 108.61 127.31 125.73 124.26 121.36 118.62 153.65 150.39 147.09 144.15 166.07 163.98 161.70 159.41 157.07 154.79 152.50 150.37

CAPACITY (m3/metre) 0.0085 0.0083 0.0081 0.0078 0.0105 0.0102 0.0098 0.0093 0.0129 0.0124 0.0121 0.0116 0.0111 0.0185 0.0178 0.0170 0.0163 0.0217 0.0211 0.0205 0.0200 0.0194 0.0188 0.0183 0.0178

DISPLACEMENT (m3/metre) 0.0018 0.0019 0.0022 0.0025 0.0021 0.0024 0.0028 0.0034 0.0026 0.0029 0.0032 0.0038 0.0043 0.0037 0.0045 0.0053 0.0059 0.0032 0.0037 0.0043 0.0049 0.0054 0.0060 0.0066 0.0071

O.D. (mm

MASS (kg/m) 35.71 39.28 44.19 50.15 58.03 35.71 41.66 47.62 53.57 59.52 65.47 72.91 48.06 53.57 59.52 64.73 69.94 79.61

I.D. (mm) 178.44 177.01 174.63 171.83 168.28 205.66 203.63 201.19 198.76 196.22 193.68 190.78 228.63 226.59 224.41 222.38 220.50 216.79

CAPACITY (m3/meter) 0.0250 0.0246 0.0239 0.0232 0.0222 0.0332 0.0326 0.0318 0.0310 0.0302 0.0295 0.0286 0.0411 0.0403 0.0396 0.0388 0.0382 0.0369

DISPLACEMENT (m3/meter) 0.0045 0.0049 0.0055 0.0063 0.0072 0.0045 0.0051 0.0059 0.0068 0.0075 0.0082 0.0091 0.0059 0.0066 0.0074 0.0081 0.0088 0.0100

250.8 (9 7/8”)

93.46

219.04

0.0377

0.0117

273.0 (10 ¾”)

48.73 60.26 67.70 75.89 82.58

258.88 255.27 252.73 250.19 247.90

0.0526 0.0512 0.0502 0.0492 0.0483

0.0059 0.0074 0.0084 0.0092 0.0103

193.7 (7 ? ”)

219.1 (8 ? ”)

244.5 (9 ? ”)

(continued) Issue 1: November 2004 Rev. 0

Capacities & Volumes

Page 66

CAPACITY AND DISPLACEMENT OF CASING (Continued) O.D. (mm)

MASS (kg/m) 62.50 69.94 80.35 89.28 71.42 81.10 90.77 101.18 107.14

I.D. (mm) 281.53 279.40 276.35 273.61 322.96 320.42 317.88 315.34 313.61

CAPACITY (m3/metre) 0.0623 0.0613 0.0600 0.0588 0.0819 0.0802 0.0794 0.0781 0.0772

DISPLACEMENT (m3/metre) 0.0077 0.0086 0.0099 0.0111 0.0087 0.0100 0.0113 0.0125 0.0134

346.1 (13 ? ”)

131.25

314.34

0.0776

0.0165

508.0 (20”)

355.6 (14”)

141.08 147.33

322.28 320.64

0.0816 0.0807

0.0177 0.0186

762 (30”)

298.4 (11 ¾”)

339.7 (13 ? ”)

O.D. (mm)

MASS (kg/m)

I.D. (mm)

CAPACITY (m3/metre)

DISPLACEMENT (m3/metre)

406.4 (16”)

96.72 111.60 124.99

387.35 384.18 381.25

0.1178 0.1159 0.1142

0.0119 0.0138 0.0156

473.1 (18 ? ”)

130.21

450.98

0.1597

0.0160

140.19 158.83 198.35 234.64 349.41 462.29

485.75 482.60 475.74 736.60 723.90 711.20

0.1854 0.1830 0.1778 0.4263 0.4117 0.3972

0.0178 0.0202 0.0253 0.0299 0.0445 0.0589

• The formula for calculating the capacity of a hole or a pipe is: Capacity (liters/meter) = (ID. mm) 2 x 0.0007854 • The annular or displacement volume can be calculated using a similar formula: Capacity (liters/meter) = (OD. mm)2 – (ID. mm)2 x 0.0007854

Issue 1: November 2004 Rev. 0

Capacities & Volumes

Page 67

CAPACITY AND DISPLACEMENT OF DRILL PIPE O.D. (mm) 60.3 (2 ? ”)

MASS (kg/m) 7.2 9.9 9.6 10.2 12.4 15.5

I.D. (mm) 50.7 46.1 62.7 62.0 59.0 54.6

CAPACITY (m3/metre) 0.0020 0.0017 0.0031 0.0030 0.0027 0.0023

DISPLACEMENT (m3/metre) 0.00092 0.00126 0.00122 0.00130 0.00159 0.00197

31.8

29.8

0.008

0.0042

12.7 14.1 16.7 19.8 23.1 38.1 17.6 20.8 23.4

77.8 76.0 73.7 70.2 66.1 40.2 88.3 84.8 82.3

0.0048 0.0045 0.0043 0.0039 0.0034 0.0011 0.0061 0.0057 0.0053

0.00161 0.00180 0.00213 0.00252 0.00294 0.0051 0.00225 0.00266 0.00298

104.8 (4 ? ”)

50.8

52.1

0.0020

0.0066

114.3 (4 ½”)

19.0 20.5 24.7 29.8

101.6 100.5 97.2 92.5

0.0081 0.0079 0.0074 0.0067

0.00242 0.00261 0.00315 0.00380

120.7 (4 ¾”)

57.2

78.9

0.0026

0.0101

127 (5”)

24.2 29.0 30.5

112.0 108.6 107.0

0.0098 0.0093 0.0090

0.00309 0.00370 0.00389

73.0 (2 ? ”) 79.4 (3 ? ”)

88.9 (3 ½”)

101.6 (4”)

Issue 1: November 2004 Rev. 0

139.7 (5 ½”) 152.4 (6”) 158.8 (6 ¼”) 165.1 (6 ½”) 171.5 (6 ¾”) 177.8 (7”) 184.2 (7 ¼”) 196.9 (7 ¾”) 203.2 (8”) 209.6 (8 ¼”) 228.6 (9”) 241.3 (9 ½”) 247.7 (9 ¾”) 254.0 (10”) 279.4 (11”)

32.6 36.8 57.2 71.4 57.2 71.4 57.2 71.4

121.4 11.6 123.5 111.6 135.4 123.5 147.3 135.4

0.0116 0.0111 0.0026 0.0040 0.0026 0.0040 0.0026 0.0040

0.00416 0.00469 0.0157 0.0142 0.0172 0.0158 0.0188 0.0174

57.2

160.7

0.0026

0.0205

57.2 71.4

174.1 163.7

0.0026 0.0040

0.0223 0.0208

71.4

177.1

0.0040

0.0226

71.4

206.9

0.0040

0.0264

71.4

223.2

0.0040

0.0284

71.4

238.1

0.0040

0.0305

71.4

290.2

0.0040

0.0370

76.2

327.4

0.0046

0.0411

76.2

345.3

0.0046

0.0436

76.2

366.1

0.0046

0.0461

76.2

449.4

0.0046

0.0567

Capacities & Volumes

Page 68

CAPACITY AND DISPLACEMENT OF TUBING O.D. (in) 1.050 1.315 1.660

1.900 2.063 2 3/8

MASS (lb/ft) 1.17 1.51 1.75 2.21 2.10 2.35 3.05 2.83 3.70 4.42 3.25 4.50 5.10 5.85 6.60

Issue 1: November 2004 Rev. 0

Thickness (mm) 2.87 3.91 3.38 4.55 3.18 3.56 4.85 3.68 5.08 6.35 3.96 5.72 5.54 6.45 7.49

Capacity (L/metre) 0.34 0.28 0.56 0.46 1.01 0.96 0.83 1.31 1.14 0.99 1.55 1.32 1.90 1.77 1.61

Displacement (L/m) 0.56

2 7/8

3 1/2

0.88 1.40

1.83

4

4 1/2

8.65 9.40 9.80 12.80 13.70 14.30 13.20 14.80 16.10 16.50 17.00 18.90 21.50

7.82 8.64 9.19 9.53 10.49 10.92 8.38 9.65 10.54 10.92 9.65 10.92 12.70

2.59 2.44 2.35 3.83 3.62 3.53 5.65 5.32 5.09 5.00 7.1 6.7 6.2

4.19

6.21

8.11

10.26

2.16 2.86

Capacities & Volumes

Page 69

ANNULAR VOLUME BETWEEN DRILL PIPE AND OPEN HOLE OR CASING DRILL PIPE O.D. (mm) 60 (2 ? ”)

73 (2 ? ”)

89 (3 ½”)

102 (4”)

HOLE or CASING SIZE (mm) 89 95 102 105 114 105 114 117 121 127 140 149 127 140 146 152 159 165 175 178 200 140 146 149 159 165 175 178 187 200 203 222

Issue 1: November 2004 Rev. 0

ANNULAR VOLUME (m3/metre) 0.0033 0.0042 0.0052 0.0057 0.0074 0.0044 0.0060 0.0066 0.0072 0.0085 0.0112 0.0133 0.0064 0.0091 0.0105 0.0120 0.0136 0.0152 0.0177 0.0186 0.0252 0.0071 0.0086 0.0093 0.0117 0.0113 0.0159 0.0167 0.0195 0.0233 0.0243 0.0252

114 (4 ½”)

127 (5”)

140 (5 ½”)

200 210 213 216 219 222 235 241 244 248 267 311 375 381 200 210 213 216 219 222 235 241 244 248 267 311 375 381 222 235 248 267 311 375

0.0212 0.0243 0.0253 0.0261 0.0274 0.0285 0.0319 0.0355 0.0367 0.0379 0.0456 0.0658 0.1000 0.1038 0.0188 0.0218 0.0229 0.0239 0.0250 0.0261 0.0307 0.0331 0.0343 0.0355 0.0432 0.0634 0.0976 0.1014 0.0235 0.0280 0.0329 0.0405 0.0607 0.094 Capacities & Volumes

Page 70

ANNULAR VOLUME BETWEEN DRILL COLLARS AND OPEN HOLE OR CASING DRILL COLLAR O.D. (mm) 114 (4 ½”)

121 (4 ¾”)

127 (5”)

140 (5 ½”)

Issue 1: November 2004 Rev. 0

HOLE or CASING SIZE (mm) 127 140 149 152 165 140 149 152 159 165 175 178 149 152 156 159 165 171 194 200 165 171 194 200 213 216 222 241 251

ANNULAR VOLUME (m3/metre) 0.0024 0.0050 0.0072 0.0079 0.0112 0.0039 0.0060 0.0068 0.0083 0.0099 0.0125 0.0134 0.0048 0.0055 0.0063 0.0071 0.0087 0.0104 0.0168 0.0188 0.0061 0.0077 0.0141 0.0161 0.0202 0.0213 0.0235 0.0304 0.0341

DRILL COLLAR O.D. (mm)

146 (5 ¾”)

152 (6”)

171 (6 ¾”)

178 (7”)

HOLE or CASING SIZE (mm) 165 171 194 200 213 216 222 241 171 194 200 213 216 222 241 251 200 216 222 311 200 213 216 222 241 251 270 279 311 375 381

ANNULAR VOLUME (m3/metre) 0.0046 0.0063 0.0127 0.0147 0.0188 0.0199 0.0221 0.0290 0.0327 0.0048 0.0112 0.0132 0.0173 0.0184 0.0206 0.0275 0.0312 0.0083 0.0135 0.0230 0.0529 0.0065 0.0107 0.0118 0.0140 0.0209 0.0246 0.0324 0.0365 0.0512 0.0854 0.0892 Capacities & Volumes

Page 71

DRILL COLLAR O.D. (mm)

197 (7 ¾”)

229 (9”)

Issue 1: November 2004 Rev. 0

HOLE or CASING SIZE (mm) 222 241 251 270 279 311 368 322 438

ANNULAR VOLUME (m3/metre) 0.0083 0.0153 0.0190 0.0268 0.0309 0.0456 0.0761 0.0350 0.1097

Capacities & Volumes

Page 72

DIMENSION AND STRENGTH OF DRILL PIPE O.D. (in) 2?

2?

3½

4

4½

5

5½

6?

Weight (lb/ft) 6.65 4.85 6.65 10.40 6.85 10.40 13.30 15.50 9.50 13.30 15.50 14.00 11.85 14.00 16.60 20.00 13.75 16.60 20.00 19.50 16.25 19.50 21.90 24.70 21.90 24.70 25.20 25.20

Issue 1: November 2004 Rev. 0

O.D. (mm) 60.3

73.0

88.9

101.6

114.3

127.0

139.7

168.3

Mass (kg/m) 9.90 7.72 9.90 15.48 10.19 15.48 19.79 23.07 14.14 19.79 23.07 20.83 17.83 20.83 24.70 29.76 20.46 24.70 29.76 29.02 24.18 29.02 32.59 36.76 32.59 36.76 37.50 37.50

Grade D E E D E E D D E E E D E E D D E E E D E E D D E E D E

Wall Thickness (mm) 7.1 4.8 7.1 9.2 5.5 9.2 9.3 11.4 6.5 9.3 11.4 8.4 6.7 8.4 8.6 10.9 6.9 8.6 10.9 9.2 7.5 9.2 9.2 10.5 9.2 10.5 8.4 8.4

I.D. (mm) 46.1 50.7 46.1 54.6 62.0 54.6 70.2 66.1 76.0 70.2 66.1 84.8 88.3 84.8 97.2 92.5 100.5 97.2 92.5 108.6 112.0 108.6 121.4 118.6 121.4 118.6 151.5 151.5

Collapse Resistance (mPa) 78.880 76.120 107.560 83.500 72.190 113.970 71.360 84.810 60.220 97.290 115.630 57.430 57.980 78.260 52.540 65.570 46.640 71.640 89.360 50.950 48.060 68.950 45.570 52.880 58.190 72.120 27.650 33.160

Internal Yield Pressure (mPa) 78.260 72.400 106.660 83.560 68.330 113.970 69.770 85.150 65.640 95.150 116.110 54.740 59.290 74.670 49.710 63.430 54.470 67.780 86.460 48.060 53.570 65.500 43.570 50.080 59.360 68.260 33.030 45.090

Pipe Body Yield Strength (mPa) 698.850 674.450 952.990 1063.720 937.000 1477.820 1373.090 1631.990 1339.380 1872.410 2225.490 1442.800 1590.970 1967.490 1671.360 2084.970 1861.860 2279.130 2843.120 2000.170 2261.960 2727.570 2310.110 2514.040 3013.840 3428.210 2474.800 3374.710 Capacities & Volumes

Page 73

HOLE VOLUME (With Pipe in Hole) Cubic Meters per 100 Meters (m3/100m) HOLE DIAMETER (mm) Pipe Size (mm) 0 89 102 114 127

143

152

156

159

171

194

200

219

222

229

251

279

311

349

381

1.61 1.36 1.35 1.30 1.24

1.81 1.56 1.53 1.50 1.44

1.91 1.66 1.61 1.60 1.54

1.99 1.74 1.69 1.68 1.62

2.30 2.05 2.02 1.99 1.93

2.94 2.71 2.66 2.65 2.59

3.14 2.89 2.85 2.83 2.77

3.77 3.52 3.48 3.46 3.40

3.87 3.62 3.59 3.56 3.50

4.12 3.87 3.82 3.81 3.75

4.95 4.70 4.65 4.60 4.58

6.11 5.85 5.83 5.80 5.74

7.60 7.35 7.31 7.29 7.23

9.57 9.32 9.30 9.26 9.20

11.40 11.15 11.11 11.09 11.03

Issue 1: November 2004 Rev. 0

Capacities & Volumes

Page 74

ANNULAR VELOCITY MULTIPLIERS BIT SIZE (mm) Pipe Size (mm) 73 76 89 102 114 127 140 152 165

136

143

152

156

159

171

194

200

219

222

229

251

279

311

349

381

445

84.7 87.0 120.4 157.3

77.9 82.0 101.6 125.7

71.1 73.4 83.9 99.6

67.5 68.6 77.6 90.9

64.2 65.3 73.3 85.1 103.6

52.5 54.3 59.7 67.3 78.4

39.7 40.0 42.8 46.5 51.7

36.8 37.2 39.7 42.9 47.2

29.9 30.2 31.8 33.8 36.4 39.9

29.0 29.3 30.8 32.7 35.1 38.4 42.8 48.5 57.7

27.2 27.4 28.6 30.2 32.3 35.1 38.9 43.4 50.5

22.3 23.1 24.2 25.5 27.2 29.3 31.9 35.6

18.2 18.9 19.6 20.6 21.9 23.3 25.2

14.3 14.7 15.2 15.8 16.5 17.3 18.3

11.4 11.7 12.0 12.5 12.9 13.5

9.4 9.6 9.6 10.2 10.4 10.8

6.8 6.9 7.0 7.1 7.3 7.2

To obtain the annular velocity in meters per min (m/min), multiply the appropriate number from the bit and pipe size combination by the pump output in cubic meters per min (m3/min). Formula: Annular Velocity (m/min) =

PumpOutput(m 3 / min) ⋅ 1.273 ⋅ 10 6 Dh 2 − Dp 2

Where: Dh = Hole Diameter (mm) Dp = Pipe Diameter (mm)

Issue 1: November 2004 Rev. 0

Capacities & Volumes

Page 75

STORAGE TANK VOLUMES Tank Volume, m3/metre (Rectangular Tanks Only)

LENGTH (m) Width (m) 1.83 2.13 2.44 2.74 3.05

3.05

3.66

4.27

4.88

5.49

6.10

7.62

9.15

10.67

12.19

13.72

15.24

16.76

18.29

19.81

21.23

5.58 6.50 7.44 8.36 9.30

6.70 7.81 8.93 10.05 7.80 9.10 10.39 11.69 8.93 10.42 11.91 13.40 10.03 11.70 13.37 15.04 11.16 13.05 14.88 17.74

11.16 12.99 14.88 16.71 18.61

13.94 16.23 18.59 20.88 23.24

16.73 19.47 22.30 25.04 27.88

19.53 22.73 26.03 29.24 32.54

22.31 25.96 29.74 33.40 37.18

25.11 29.22 33.48 37.59 41.85

27.89 32.46 37.19 41.76 46.48

30.67 35.70 40.89 45.92 51.12

33.47 38.96 44.63 50.11 55.78

36.25 42.2 48.34 54.28 60.42

38.85 45.22 51.80 58.17 64.75

Tank Volume Formulas: Capacity, volume and displacement calculations use simple volumetric relationships for rectangles, cylinders, concentric cylinders and other shapes with the appropriate unit conversion factors. Tanks on rigs can be a variety of shapes, but most are either rectangular or cylindrical. Three shapes of tanks are covered here: 1. Rectangular 2. Cylindrical, vertical 3. Cylindrical, horizontal 4. Miscellaneous shapes Issue 1: November 2004 Rev. 0

Capacities & Volumes

Page 76

1. Volume Rectangular Tank: Mud tanks are usually rectangular with parallel sides and ends that are perpendicular to the bottom. For a typical rectangular tank, the capacity can be calculated from the height, width and length. Where: Vtank = L = W = H =

Tank Capacity Tank Length Tank Width Tank Height

L

Formula: The general equation to calculate the capacity of a rectangular vessel is: Volume = Length x Width x Height

H

This formula is valid for both English and Metric (SI) units. Therefore, the capacity of a rectangular pit, using meters, is calculated by: Vtank (m3) = L (m) x W (m) x H (m)

Issue 1: November 2004 Rev. 0

W

Capacities & Volumes

Page 77

2. Volume Vertical Cylindrical Tank: Cylindrical tanks mounted in a vertical position are normally used for liquid mud and/or dry bulk Barite, Calcium Carbonate or Bentonite storage. Where: VCyl = D = H = M = π =

D

Capacity of the Cylindrical Tank Diameter of Cylinder Height of Cylinder Material Level Height 3.1416

If the diameter is not known, measure the tank circumference and divide by π. D=

H

Circonference π

M

Formula: The general formula to calculate the capacity for a vertical cylinder tank is: VCyl (m3) =

π ⋅ D 2 (m) ⋅ H (m) D 2 (m) ⋅ H (m) = 4 1.273

The actual mud volume (Vmud) of a vertical cylinder tank is calculated using the mud/material level height (M) by: Vmud (m3) =

Issue 1: November 2004 Rev. 0

π ⋅ D 2 (m) ⋅ M (m) D 2 (m) ⋅ M (m) = 4 1.273

Capacities & Volumes

Page 78

3. Volume Horizontal Cylindrical Tank: Cylindrical tanks mounted in a horizontal position are normally used primarily for storage of diesel fuel, other liquids and/or bulk Barite or Calcium Carbonate. The vertical capacity and volume of a horizontal cylindrical tank varies with the horizontal cross-section area, and is not a linear function of height. Charts and tabular methods are available to calculate the capacity and volume of horizontal cylindrical tanks. Where: VCyl = D = L = M = π =

L Capacity of the Cylindrical Tank Diameter of Cylinder Length of Cylinder Mud or Material Height 3.1416

D Formula: The general formula to calculate the capacity for a horizontal cylinder tank is: Vcyl =

2 L  D2  2M  π ⋅D  ⋅ (2M − D) ⋅ M ⋅ D − M 2 + ⋅ sen −1  − 1 +  2  2 4   D 

M

•

The result from sin-1 must be in radians before being added to the other parts of the equation (2π radians = 360°).

•

To convert from degrees, divide by 57.3 (= 180 degrees/p radians) to obtain radians.

Volume can be also calculated in a simpler way: Vliq =

M D

⋅Vcyl

Where: Vcyl = pr2L Issue 1: November 2004 Rev. 0

r = D/2 Capacities & Volumes

Page 79

4. Miscellaneous shapes: A. Hollow cylinder: Hollow cylinders can be the annular volume between casing and drill pipe. V = p⋅(R2 – r2)⋅H = p⋅(R + r)⋅e⋅H B. Truncated cone: V=

π ⋅H 3

C. Truncated pyramid:

⋅(R2 + r2 + Rr)

R

r

V=

H 3

⋅(B + b +

Bb )

e

b

r

H

H

B

R

A Issue 1: November 2004 Rev. 0

H

B

C Capacities & Volumes

Page 80

BUOYANCY FACTORS DENSITY (kg/m3) 1000 1020 1040 1060 1080 1100 1120 1140 1160 1180 1200 1220 1240 1260 1280 1300 1320 1340 1360 1380 1400 1420 1440 1460

GRADIENT (kPa/m) 9.81 10.00 10.20 10.40 10.60 10.80 10.99 11.18 11.38 11.58 11.77 11.97 12.16 12.36 12.55 12.75 12.94 13.14 13.34 13.53 13.73 13.93 14.12 14.32

BUOYANCY FACTOR 0.873 0.869 0.867 0.864 0.862 0.859 0.857 0.854 0.852 0.849 0.847 0.844 0.842 0.839 0.837 0.834 0.832 0.829 0.827 0.824 0.822 0.819 0.817 0.814

1480 1500 1520 1540 1560 1580 1600 1620 1640 1660 1680 1700 1720 1740 1760 1780 1800 1820 1840 1860 1880 1900 1920 1940 1960 1980

14.51 14.71 14.91 15.10 15.30 15.50 15.69 15.89 16.08 16.28 16.48 16.67 16.87 17.06 17.26 17.46 17.65 17.85 18.04 18.24 18.44 18.63 18.83 19.03 19.22 19.42

0.811 0.809 0.806 0.804 0.801 0.799 0.796 0.794 0.791 0.789 0.786 0.783 0.781 0.778 0.776 0.773 0.771 0.768 0.766 0.763 0.761 0.758 0.755 0.753 0.750 0.748

Actual Hook Load (daN) = Pipe Mass (kg) x Buoyancy Factor Issue 1: November 2004 Rev. 0

Capacities & Volumes

Page 81

NOTES:

Issue 1: November 2004 Rev. 0

Capacities & Volumes

Page 82

RECOMMENDED SOLIDS CONTENT OF WATER BASE MUD

Approximate range of field mud in good condition Issue 1: November 2004 Rev. 0

Mud Properties

Page 83

SUGGESTED RANGES OF PLASTIC VISCOSITY (PV, cP)

Issue 1: November 2004 Rev. 0

SUGGESTED RANGES OF YIELD POINT (YP, lb/100ft2)

Mud Properties

Page 84

INFLUENCE OF CAUSTIC SODA (NaOH) ON CALCIUM SOLUBILITY @ 20°C

Issue 1: November 2004 Rev. 0

INFLUENCE OF SALT (NaCl) ON CALCIUM SOLUBILITY @ 20°C

Mud Properties

Page 85

NOTES:

Issue 1: November 2004 Rev. 0

Mud Properties

Page 86

MOHS’ HARDNESS SCALE Substance Talc Gypsum Calcite Fluorite Apatite Orthoclase Feldspar Quartz Topaz Corundum Diamond

Issue 1: November 2004 Rev. 0

Hardness 1 (softest) 2 3 4 5 6 7 8 9 10 (hardest)

HARDNESS OF COMMON OIL FIELD MATERIALS Material Barite Bentonite Calcite Dolomite Galena Graphite Halite (Salt) Hematite Illite Ilmenite Magnesite Montmorillonite Pyrite Quartz Siderite Smithsonite Sylvite

Chemical Formula BaSO4 CaCO3 CaMg(CO3)2 PbS C NaCl Fe2O3 FeTiO3 MgCO3 FeS SiO2 FeCO3 ZnCO3 KCl

Mohs’ Hardness 3.0-3.5 1.0-2.0 3.0 3.5-4.0 2.5-2.75 1.0-2.0 2.5 5.0-6.0 1.0-2.0 5.0-6.0 3.5-4.5 1.0-2.0 6.0-6.5 7.0 4.0-4.5 4.0-4.5 2.0

Chemical & Physical Data

Page 87

pH RANGES OF COMMON ACID/BASE INDICATORS Name Cresol red* Thymol blue Metacresol purple* Bromophenol blue Congo red Methyl orange Bromocresol green Ethyl red Methyl red Bromocresol purple Bromothymol blue Phenol red Neutral red * (Cresol red) * (Metacresol purple) Phenolphthalein Thymolphthalein Alizarin yellow R 2.4.6 Trinitrotoluene 1.3.5 Trinitrobenzene

Issue 1: November 2004 Rev. 0

pH range 0.4 – 1.8 1.2 – 2.8 1.2 – 2.8 3.0 – 4.6 3.0 – 5.0 3.2 – 4.4 3.8 – 5.4 4.0 – 5.8 4.8 – 6.0 5.2 – 6.8 6.0 – 7.6 6.6 – 8.0 6.8 – 8.0 7.0 – 8.8 7.4 – 9.0 8.2 – 10.0 9.4 – 10.6 10.1 – 12.0 11.5 – 13.0 12.0 – 14.0

Color Red Red Red Yellow Blue Red Yellow Colorless Red Yellow Yellow Yellow Red Yellow Yellow Colorless Colorless Yellow Colorless Colorless

To To To To To To To To To To To To To To To To To To To To To

Change Yellow Yellow Yellow Blue Red Yellow Blue Red Yellow Purple Blue Red Amber Red Purple Pink Blue Red Orange Orange

Chemical & Physical Data

Page 88

APPROXIMATE pH OF ACIDS, BASES, AND OIL FIELD CHEMICALS Acids Acetic. 1N Acetic. 0.1N Acetic. 0.01N Alum. 0.1N Boric. 0.1N Carbonic (saturated) Citric. 0.1N Formic. 0.1N Hydrochloric. 1N Hydrochloric. 0.1N Hydrochloric. 0.01N Hydrogen sulfide. 0.1N Orthophosphoric. 0.1N Oxalic. 0.1N SAPP Sulfuric. 1N Sulfuric. 0.1N Sulfuric. 0.01N Sulfurous. 0.1N

Issue 1: November 2004 Rev. 0

pH 2.4 2.9 3.4 3.2 5.2 3.8 2.2 2.3 0 1.0 2.0 4.1 1.5 1.6 4.2 0.3 1.2 2.1 1.5

Bases Ammonia. 1N Ammonia. 0.1N Ammonia. 0.01N Borax (buffer solution) Calcium carbonate (saturated) Calcium hydroxide (saturated) Ferrous hydroxide (saturated) Lime (saturated) Magnesia (saturated) Potassium hydroxide. 1N Potassium hydroxide. 0.1N Potassium hydroxide. 0.01N Sodium bicarbonate. 0.1N Sodium carbonate. 0.1N Sodium hydroxide. 1N Sodium hydroxide. 0.1N Sodium hydroxide. 0.01N

pH 11.6 11.1 10.6 9.2 9.4 12.4 9.5 12.4 10.5 14.0 13.0 12.0 8.4 11.6 14 13.0 12.0

Chemical & Physical Data

Page 89

CALCULATED EQUILIBRIUM GEOMETRY MODEL

Molecular Mechanics, MMFF ION Li+ Zn++ Fe++ Ti++ Na+ Mg++ Ag+ Zr++ Ca++ Cu++ K+ ClNH4+ S--2 B+++ HCO3Al+++ CO3-NO3N(Me)4+

VOLUME (Å3) 7.70 11.06 12.93 13.65 13.91 14.42 16.33 19.61 20.54 22.33 29.00 32.22 34.30 34.37 35.67 47.64 47.71 56.10 56.89 118.03

Surface AREA (Å2) 18.86 24.00 26.64 16.74 27.97 28.65 31.13 35.17 36.27 38.35 45.65 48.97 53.72 51.12 52.40 68.76 63.62 76.25 78.04 141.35

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SIEVE MESH-MICRON CORRELATION CHART MESH ASTM (sieve no.) 5 6 7 8 10 12 14 16 18 20 25 30 35 40

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Micron 4000 3350 2800 2360 2000 1700 1400 1180 1000 850 710 600 500 425

MESH ASTM (sieve no.) 45 50 60 70 80 100 120 140 170 200 230 270 325 400

Micron 355 300 250 212 180 150 125 106 90 75 63 53 45 38

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COMMON CHEMICAL FORMULAS AND NAMES COMMON NAME Aluminum Stearate Ammonium Bisulfite Anhydrite Barite Barium Carbonate Bicarbonate (Baking Soda) Borax Calcium Carbonate Calcium Chloride Caustic Potash Caustic Soda DAP Dolomite Galena Gypsum H2S Hematite Hot or Quick Lime Ironite Sponge Lime Limestone Potash Potassium Sulfate Salt SAPP Silica Soda Ash Sodium Sulfite Zinc Carbonate Issue 1: November 2004 Rev. 0

CHEMICAL NAME Aluminum Stearate Ammonium Bisulfite Calcium Sulfate Barium Sulfate Barium Carbonate Sodium Bicarbonate Sodium Borate Pentahydrate Calcium Carbonate Calcium Chloride Potassium Hydroxide Sodium Hydroxide Diammonium Phosphate Calcium Magnesium Carbonate Lead Sulfide Calcium Sulfate Hydrogen Sulfide Ferric Oxide Calcium Oxide Iron Oxide Calcium Hydroxide Calcium Carbonate Potassium Chloride Potassium Sulfate Sodium Chloride Sodium Acid Pyrophosphate Silicon Dioxide Sodium Carbonate Sodium Sulfite Zinc Carbonate

CHEMICAL FORMULA Al(C18H3O2)3 (NH4)HSO3 CaSO4 BaSO4 BaCO3 NaHCO3 Na2B4O7⋅5H2O CaCO3 CaCl2 KOH NaOH (NH4)2HPO4 CaMg(CO3)2 PbS CaSO4⋅2H20 H2S Fe2O3 CaO Fe2O4 Ca(OH)2 CaCO3 KCl K2SO4 NaCl Na2H2P2O7 SiO2 Na2CO3 Na2SO3 ZnCO3 Chemical & Physical Data

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COMMON DRILLING MUD CATIONS (+ ions) ION NAME Aluminum Ammonium Barium Calcium Carbon Cesium Chromium (Chromate) Chromium (Chromic) Chromium (Chromus) Copper (Cuprium) Hydrogen Iron (Ferric) Iron (Ferrous) Lead (Plumbic) Lead (Plumbus) Magnesium Manganese Nickel Phosphorus Potassium Silicon Silver Sodium Zinc

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SYMBOL Al NH4 Ba Ca C Cs Cr Cr Cr Cu H Fe Fe Pb Pb Mg Mn Ni P K Si Ag Na Zn

OXIDATION STATE +3 +1 +2 +2 +4 +1 +6 +3 +2 +2 +1 +3 +2 +4 +2 +2 +2 +2 +5 +1 +4 +1 +1 +2

COMMON DRILLING MUD ANIONS (- ions) ION NAME Bicarbonate Bisulfate Bisulfide Bisulfite Bromate Bromide Carbonate Chloride Chromate Dichromate Fluoride Hydroxide Hypochlorite Nitrate Nitrite Perchlorate Phosphate Sulfate Sulfide Sulfite

SYMBOL HCO3 HSO4 HS HSO3 BrO3 Br CO3 Cl CrO4 Cr2O7 F OH ClO NO3 NO2 ClO4 PO4 SO4 S SO3

OXIDATION STATE -1 -1 -1 -1 -1 -1 -2 -1 -2 -2 -1 -1 -1 -1 -1 -1 -3 -2 -2 -2

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SPECIFIC GRAVITY OF COMMON MATERIALS MATERIAL Barite Bentonite Blacknight Calcium Carbonate Calcium Chloride (94%) Calcium Chloride (Flake) Calcium Lignosulfonate Calcium Oxide (Hot Lime) Calcium Sulfate Caustic Potash Cement Citric Acid Clays (Drilled Solids) CMC Diesel Fuel Dolomite Feldspar Fresh Water Galena Gypsum HEC Hematite Iron

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SPECIFIC GRAVITY 4.2-4.3 2.3-2.4 1.08 2.7 2.2 1.85 1.53 3.4 2.96 2.044 3.0-3.3 1.665 2.5-2.7 1.59 0.84 2.8-3.0 2.4-2.7 1.0 6.5-6.7 2.3-2.4 1.38-1.40 5.26 7.8

MATERIAL Ironite Sponge Lead Lignite Lime (Hydrated) Lime (Hot or Quick Lime) Limestone Marble Potassium Chloride Pyrite Quartz Salt Salt Gel Sand SAPP Sea Water Soda Ash Sodium Bicarbonate Sodium Sulfite Starch Steel Walnut shells Zinc Carbonate

SPECIFIC GRAVITY 4.9-5.3 11.3 1.5 2.34 3.2-3.4 2.4-2.7 2.5-2.9 1.99 5.02 2.65 2.165 2.55 2.4-2.8 1.862 1.05 2.53 2.16 2.63 1.5 7.8 1.3 4.4

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CEMENT 1. Cement data Specific gravity of cement: 3.15 g/cm3 Bulk (apparent) density: 1.5 g/cm3 Volume occupied by 1 kg of cement: 0.3175 litres 2. Cement classes See also API 10 specifications. Class A B C D E F G H

Application Use from 0 to 1830 m (6000 ft) when no special properties are required Use from 0 to 1830 m (6000 ft) when moderate to high sulfate-resistance is required Use from 0 to 1830 m (6000 ft) when high strength is required Use from 1830 m (6000 ft) to 3050 m (10000 ft) when moderate to high temperatures and pressure are encountered Use from 3050 m (10000 ft) to 4270 m (14000 ft) when high temperatures and pressure are encountered Use from 3050 m (10000 ft) to 4880 m (16000 ft) when extremely high temperatures and pressure are encountered Use from 0 to 2440 m (8000 ft) as basic cement or in conjunctions with accelerators or retarders to cover a wide range of depths and temperatures Use from 0 to 2440 m (8000 ft) as basic cement or in conjunctions with accelerators or retarders to cover a wide range of depths and temperatures

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FRESH-WATER CEMENT SLURRIES Slurry density = (cement mass + water mass) / (cement volume + water volume) Cement class A B C D E F G H

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Water volume (liters) for 100 kg of cement 46 46 56 38 38 38 44 38

Specific gravity 1.88 1.88 1.78 1.98 1.98 1.98 1.90 1.98

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SALT-WATER CEMENT SLURRIES Slurry density = (cement mass + brine mass) / (cement volume + brine volume) Brine and final slurry volumes for 100 kg of cement Specific gravity 1.80 1.81 1.82 1.83 1.84 1.85 1.86 1.87 1.88 1.89 1.90 1.91 1.92 1.93 1.94 1.95 1.96 1.97 1.98

Brine volume (liters) 71.4 69.7 68.1 66.5 65.0 63.5 62.0 60.6 59.3 58.0 56.7 55.4 54.2 53.1 51.9 50.8 49.7 48.6 47.6

Slurry volume (liters) 103.2 101.5 99.8 98.3 96.7 95.2 93.8 92.4 91.0 89.7 88.4 87.2 86.0 84.8 83.7 82.5 81.5 80.4 79.4

Specific gravity 1.99 2.00 2.01 2.02 2.03 2.04 2.05 2.06 2.07 2.08 2.09 2.10 2.11 2.12 2.13 2.14 2.15 2.16

Brine volume (liters) 46.6 45.6 44.7 43.7 42.8 42.0 41.1 40.2 39.4 38.6 37.8 37.0 36.3 35.5 34.8 34.1 33.4 32.7

Slurry volumes (liters) 78.4 77.4 76.4 75.5 74.6 73.7 72.8 72.0 71.2 70.3 69.6 68.8 68.0 67.3 66.6 65.0 65.2 64.5

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Quantities for preparation of 1 m3 of saturated salt-water cement slurry. Specific gravity 1.75 1.76 1.77 1.78 1.79 1.80 1.81 1.82 1.83 1.84 1.85 1.86 1.87 1.88 1.89 1.90 1.91 1.92 1.93 1.94 1.95

Cement (kg) 888 905 921 937 953 969 985 1002 1018 1034 1050 1066 1082 1098 1115 1131 1147 1163 1179 1195 1212

Brine volume (liters) 718 713 708 703 697 692 687 682 677 672 667 662 656 651 646 641 636 631 626 621 615

Specific gravity 1.96 1.97 1.98 1.99 2.00 2.01 2.02 2.03 2.04 2.05 2.06 2.07 2.08 2.09 2.10 2.11 2.12 2.13 2.14 2.15 2.16

Cement (kg) 1228 1244 1260 1276 1292 1308 1325 1341 1357 1373 1389 1405 1422 1438 1454 1470 1486 1502 1518 1535 1551

Brine volume (liters) 610 605 600 595 590 585 579 574 569 564 559 554 549 544 538 533 528 523 518 513 508

Based on a saturated NaCl brine (315 g/L @ d = 1.20 sg)

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BENTONITE CEMENT SLURRIES 1. Preparation Bentonite cement slurry can be prepared adding: a) Dry bentonite to cement in proportions ranging between 1 and 20% to have final density between 1.42 and 1.85 s.g b) Prehydrated bentonite to cement in proportions ranging between 0.25 and 5% to have final density between 1.39 and 1.84 s.g Slurry density = (cement mass + water mass + bentonite mass) / (cement volume + water volume + bentonite volume) Composition of Prehydrated Bentonite slurries using Class G cement Specific gravity 1.901 1.843 1.792 1.748 1.708 1.672 1.640 1.611 1.585 1.560 1.538 1.518 1.499 1.482 1.466 1.451 1.437 Issue 1: November 2004 Rev. 0

Bentonite (%) 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00

Water volume (litres) 44.0 49.3 54.6 59.9 65.2 70.5 75.8 81.1 86.4 91.7 97.0 102.3 107.6 112.9 118.2 123.5 128.8 Cement Data

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Composition of Dry Bentonite slurries using Class G cement Specific gravity 1.901 1.846 1.798 1.756 1.719 1.685 1.656 1.629 1.604 1.582 1.562 1.543 1.526 1.511 1.496 1.482 1.470 1.458 1.447 1.436 1.426

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Bentonite (%) 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20

Water volume (liters) 44.0 49.3 54.6 59.9 65.2 70.5 75.8 81.1 86.4 91.7 97.0 102.3 107.6 112.9 118.2 123.5 128.8 134.1 139.4 144.7 150.0

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Quantities for preparation of 1 m3 of bentonite cement slurry (with Class G cement and prehydrated bentonite) Specific gravity 1.901 1.843 1.792 1.748 1.708 1.672 1.640 1.611 1.585 1.560 1.538 1.518 1.499 1.482 1.466 1.451 1.437

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Bentonite (%) 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00

Cement (kg) 1320 1232 1156 1088 1028 974 925 881 841 805 771 740 712 686 661 638 617

Bentonite (kg) 0.00 3.08 5.78 8.16 10.28 12.17 13.87 15.42 16.82 18.10 19.28 20.36 21.36 22.28 23.14 23.94 24.68

Water volume (liters) 581 608 631 652 670 686 701 714 727 738 748 757 766 774 781 788 795

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Quantities for preparation of 1 m3 of bentonite cement slurry (with Class G cement and dry bentonite) Specific gravity 1.901 1.846 1.798 1.756 1.719 1.685 1.656 1.629 1.604 1.582 1.562 1.543 1.526 1.511 1.496 1.482 1.470 1.458 1.447 1.436 1.426

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Bentonite (%) 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20

Cement (kg) 1320 1228 1148 1078 1016 960 911 866 825 788 755 724 695 669 644 621 600 581 562 545 528

Bentonite (kg) 0.00 12.28 22.96 32.34 40.63 48.02 54.64 60.61 66.03 70.95 75.46 79.60 83.41 86.93 90.19 93.22 96.05 98.69 101.16 103.48 105.66

Water volume (liters) 581 605 627 646 662 677 690 702 713 723 732 740 748 755 761 768 773 778 783 788 792

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CMHEC

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Pozzolan

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Bentonite

EFFECTS OF SOME ADDITIVES ON CEMENT PROPERTIES

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